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Home My WebLink About197-052 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW)ULGD\-XQH30 7R1LFN)UD]LHU& &F5HJJ-DPHV%2*& 6XEMHFW5(+LOFRUS7KXQGHUELUG $WWDFKPHQWV+LOFRUS7KXQGHUELUG5HYLVHG[OV[ )ROORZ8S)ODJ)ROORZXS )ODJ6WDWXV&RPSOHWHG EŝĐŬ͕ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĐŚĂŶŐŝŶŐƚŚĞŚŽŬĞ>Ŷ͘sĂůǀĞƐƚŽ͞W͟ďĂƐĞĚŽŶƚŚĞEƵŵďĞƌŽĨ&ĂŝůƵƌĞƐĂŶĚZĞŵĂƌŬƐ͘WůĞĂƐĞ ƵƉĚĂƚĞǇŽƵƌĐŽƉǇŽƌůĞƚŵĞŬŶŽǁŝĨǇŽƵĚŝƐĂŐƌĞĞ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗EŝĐŬ&ƌĂǌŝĞƌͲ;ͿфŶĨƌĂǌŝĞƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕:ƵŶĞϭϲ͕ϮϬϮϮϰ͗ϬϬWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗,ŝůĐŽƌƉdŚƵŶĚĞƌďŝƌĚϭϲͲϭϱͲϮϬϮϮ WůĞĂƐĞĨŝŶĚĂƚƚĂĐŚĞĚƚŚĞKWdĞƐƚ&ŽƌŵĨŽƌ,ŝůĐŽƌƉdŚƵŶĚĞƌďŝƌĚϭĨŽƌϲͲϭϱͲϮϬϮϮ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇ ƋƵĞƐƚŝŽŶƐ͘ dŚĂŶŬƐ͕ EŝĐŬ&ƌĂǌŝĞƌ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:Thunderbird 1 DATE: 6/15/22 Rig Rep.: Rig Phone: 307-321-6563 Operator: Op. Phone:907-444-7218 Rep.: E-Mail Well Name: PTD #11970520 Sundry #322-247 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2720 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5" VBR P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1700 p Quantity Test Result 200 psi Attained (sec)18 p No. Valves 11 FP Full Pressure Attained (sec)92 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 3@2050 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:2.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6-14-22 1:30 pm Waived By Test Start Date/Time:6/15/2022 10:00 (date) (time)Witness Test Finish Date/Time:6/15/2022 12:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Hilcorp C3 leaked. Functioned valve and passed after funtioning. Tested with fresh water. 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The report is due within 15 days after the cleanup is completed, or if no cleanup occurs, within 15 days after the discharge. Forward the report to the nearest DEC office of the department. The report must contain, as applicable: 1. Date and time of the discharge: 2. Location of the discharge: 3. Name of the site, facility or operation: 4. Name, mailing address, and telephone number of: A. Person or persons causing or responsible for the discharge: B. Owner and operator of the site, facility or operation: 5. Type and amount of each oil or hazardous substance discharged: 6. Cause of the discharge: 7. Description of any environmental damage caused by the discharge or containment, to the extent the damage can be identified: 9 9 06-18-2022 18:30 Hilcorp, Alaska, Prudhoe Bay Unit - West, S- Pad by Well 42A Lat. 70.354779 Long. -149.037674 Hilcorp - North Slope,LLC, Prudhoe Bay, Alaska Gathering Center #2, S-Pad by Well 42A Hilcorp North Slope, LLC 3800 Centerpoint Drive Anchorage, AK 99503 East Environmental Specialist (907)659-5999 Same Hydraulic Oil - 76 gallons to gravel pad and inside of Koomy Accumulator Skid Unit. Initially reported as an estimated 55 gallons. We measured the amount that remained in the hydraulic oil reservoir tank and we determined that the tank lost approx 20% in the tank, which equals to 76 gallons. When the Koomy Accumulator Skid Unit was tail rolled for transport, hydraulic oil was released from the hydraulic oil tank reservoir located in the skid unit. A cap was off of the reservoir tank and when the skid was lifted, the hydraulic oil was released inside of the skid unit and to the gravel pad. None G:\SPAR\Spar-Prevention and Emergency Response\camille\Final Report Form.doc Page 2 of 2 Revised: September 19, 2000 Oil & Hazardous Materials Incident Final Report -- continued 8. Description of cleanup actions taken: 9. Estimated amount of: (A) oil or hazardous substance cleaned up: (B) oily or hazardous waste generated: 10. Date, location, and method of ultimate disposal of the oil, hazardous substance and any contaminated materials, including cleanup materials: 11. Description of actions being taken to prevent recurrence of the discharge: 12. Other information the department requires to fully assess the cause and impact of the discharge (receipts for disposal if available): Signature Printed name Date Title MAIL OR FAX TO the Closest A.D.E.C. Office below Anchorage Phone: 269-3063 Fax: 269-7648 555 Cordova Street Anchorage, AK 99501 Fairbanks Phone: 451-2121 Fax: 451-2362 610 University Ave. Fairbanks, AK 99709-3643 Juneau Phone: 465-5340 Fax: 465-2237 410 Willoughby Ave., Suite 309 Juneau, AK 99801-1795 DEC USE ONLY ADEC Project Manager: ADEC Spill #: 9 ACS responded that night to initiate the cleanup. ACS used a skid steer, a dump box and hand tools to recover the impacted gravel and used absorbents to clean the skid unit. They recovered 10 cy of gravel and 40 bags of oily absorbent waste. 76 gallons The contaminated gravel was sent to the G&I Facility for class I disposal on 6/19/2022. The oily waste was disposed of in the oily waste bin. An investigation is underway to determine "why" the cap was not on the hydraulic oil tank. Corrective action will follow after the investigation is complete. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer S-43 (PTD#1970520) TxIA communication economic evaluation Date:Friday, March 18, 2022 10:38:18 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Friday, March 18, 2022 10:38 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: UNDER EVALUATION: Producer S-43 (PTD#1970520) TxIA communication economic evaluation This has been forwarded to Mel Rixse. On 2/24/2022 he granted the initial approval for 30 day flow period. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 17, 2022 6:04 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer S-43 (PTD#1970520) TxIA communication economic evaluation Mr. Regg, Producer S-43 (PTD# 1970520) has known TxIA communication but passed CMIT-TxOA on 02/17/22 verifying the secondary well barrier. AOGCC has approved temporary flow back initially for 30 days to evaluate well tests. The AOGCC may extend this period for an additional 30 days. The well is now classified as UNDER EVALUATION and can be put on production for 30 days once the tubing plug is pulled. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, July 31, 2017 3:24 PM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Shriver, Tyson <Tyson.Shriver@bp.com>; Wellman, Julie <Julie.Wellman@bp.com>; Youngmun, Alex <younak@BP.com>; Zoesch, Eric <zoese0@BP.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) <jim.regg@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>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@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>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'chris.wallace@alaska.gov' (chris.wallace@alaska.gov) <chris.wallace@alaska.gov> Subject: NOT OPERABLE: Producer S-43 (PTD#1970520) TIFL Failed Post GLV Change out All, Producer S-43 (PTD# 1970520) was made under evaluation on 6/20/17 for failing a diagnostic TIFL. Slickline performed a gas lift valve change out on 07/19/17 and the well failed a subsequent warm TIFL on 7/21/17. A tubing caliper ran on 7/28/17 indicated areas of significant wall loss below the tubing patch at 8498’. The 28 day evaluation period has expired and the well is now reclassified as Not Operable and will remain shut in. An inflatable bridge plug will be set below to packer to secure the well while the engineering team develops a plan forward. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: AK, GWO SUPT Well Integrity Sent: Monday, July 17, 2017 3:57 PM To: AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Shriver, Tyson; Wellman, Julie; Youngmun, Alex; Zoesch, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@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; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Worthington, Aras J; 'chris.wallace@alaska.gov' (chris.wallace@alaska.gov) Subject: UPDATE 07/17/17: UNDER EVALUATION: Producer S-43 (PTD#1970520) Inner Annulus over NOL - Failed TIFL All, Online diagnostics on Producer S-43 (PTD# 1970520) were delayed due to a pad shut-down. Slickline is scheduled to change out the orifice gas lift valve within the next week. The Under Evaluation clock is reset for an additional 14 days. Work Completed/Plan Forward: 1. Downhole Diagnostics: Cold TIFL – Failed 06/20/17 2. Operations: POP well – Completed 07/09/17 3. DHD: Warm TIFL – Failed 07/10/17 4. Slickline: Change out orifice gas lift valve 5. DHD: Warm TIFL 6. Well Integrity Engineer: Additional Diagnostics as needed Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) O: (907) 659-5102 C: (907) 943-0296 H: 2376 From: AK, GWO Well Integrity Engineer Sent: Tuesday, June 20, 2017 12:42 PM To: AK, GWO Well Integrity Engineer; 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; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bergene, Matthew; Regg, James B (DOA) (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer S-43 (PTD#1970520) Inner Annulus over NOL - Failed TIFL All, Gas lifted Producer S-43 (PTD# 1970520) exceeded NOL on the inner annulus and failing a subsequent TIFL on 06/19/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The current estimate for S pad to come back online is 06/30/17. At this time the well is classified as Under Evaluation, and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations- POP well 2. Down Hole Diagnostics: Perform Warm TIFL 3. Well Integrity Engineer: Additional Diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Rixse, Melvin G (OGC) To:Oliver Sternicki Cc:AOGCC Records (CED sponsored) Subject:20220224 1748 APPROVAL TO FLOW UNDER EVAL W GAS LIFT PBU S-43(PTD# 197052) Date:Thursday, February 24, 2022 5:30:53 PM Attachments:image001.png Oliver, Hilcorp is approved to flow test well PBU S-43 (PTD 197-052) for 30 days with gas lift. After 30 days AOGCC will consider a request for an additional 30 day ‘flow under evaluation’ period. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, February 22, 2022 3:10 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: S-43(PTD# 197052) Request to flow under evaluation for up to 60 days Mel, Gas lifted producer S-43 (PTD# 197052) was made not operable on 7/31/2017 after multiple failed TIFLs and a caliper showing a high concentrations of tubing corrosion damage. Diagnostic work in late 2017 showed that the tubing passed an MIT-T to 2417 psi with a plug set at 8020’ SLM, but failed an MIT-T with a plug set at 8867’MD, LLR was 5 bpm @ ~1200 psi. On 2/17/2022 a non-witnessed CMIT-TxIA passed to 2482 psi against the plug set at 8867’ MD. This passing CMIT-TxIA proves the integrity of the secondary barrier. The last well test from 2017 showed the well producing ~3000 BFPD, 94% WC and 1MMSCF formation gas. Due to the poor overall tubing condition a RWO is required to replace the tubing to reestablish the primary well barrier. Hilcorp request permission to flow S-43 under evaluation for up to 60 days to confirm production rates and evaluate economics for a RWO tubing swap. Gas lift will be needed to flow the well during the under evaluation period. Let me know if you have any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 youhave received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments willnot adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU S-43 Permit to Drill Number: 197-052 Sundry Number: 320-060 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. o l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Q Vi— re M. rice C a] DATED this S day of February, 2020. RBDMSL FEB 0 5 ZOZO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 D n z /44.(2 a ') n nnnn --- u LVLU 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 - Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program -❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other 1❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: - Exploratory ❑ Development 0 5. Permit to Drill Number. 197-052 Box 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-22754-00-00 - 995. 12 Strstigrephic ❑ Service ❑ 7, If perforating: S. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a sparing exception? Yes ❑ No 0 PBU S43 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028257 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13889 ' 9018 8867 8465 2520 8867 8498,9070,9077,9774 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 3087 9-5/8" 34-3121 34-3066 5750 3090 Intermediate 1 10165 7" 1 31-10196 1 31 -8991 7240 5410 Production Liner 3748 4-1/2" 10059 - 13807 1 8978-9013 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (R): 10600- 13805 1 - 9012 4-1/2" 12.6# L-80 28 - 9089 / 9774 - 9808 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9032/8559 4-1/2" Baker ML Packer 9774 / 8875 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: March 1, 2020 15, Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: McLaughlin, Sean be deviated from without prior written approval. Contact Email: Sean.McLaughlin@bp.00m Authorized Name: MUaughlin, Sean M Contact Phone: +1 907 223-6784 Authorized Title: Engi enng Team Lean - CTD Authorized Signature: Date. G(130 7,0 -C) COMMISSION USE ONLY Conditions of approval: Notify Commission so that arepresentative may witness Sundry Number: D Plug Integrity 11 BOP Test W/Mechanical Integrity Test/D Location Clearance [1 Other K© PLS C S 7 �d �'�QQ� S ��/ RBDMS-4rA-/,E, 0 5 2010 Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Y No (9 Subsequent Form Required: ,D sl� tl APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: vv � 2-114 91" /�r.b�ltlf`orm�"�' �� and Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin `0"'I. RWO/CTD Engineer 2 p Date: January 29, 2020 ryNs N Re: S-43 Sundry Approval Well Tvpe: Producer J Current Status: The well is currently not operable due to corrosion and multiple tubing leaks. Request: Sundry approval is requested for plans to restore tubing integrity. History and current status: Well S-41 was drilled as a multi lateral completion in 1997 with L-80 liner and tubing. The original tubing is still in the well. The well has a history of failing TIFLs. The well has had two tubing leaks since the well was originally completed. The first tubing leak was at station 1, and was squeezed in 2009. The well was operable from that point until 2014, when it failed another MIT -IA. The second leak was identified at station 2 and was patched. In 2017 The well was found to have IA pressure over normal operating limits, due to failed SO check valves. Slickline performed a caliper which indicated multiple areas of corrosion, with most severe penetration at 4645' MD. A plug was set at 8867' MD, and a CMIT-TxIA was performed in December of 2017 to 2395 psi. An attempt was made to set a dummy valve in station 3, with no success. A second plug was set above station 3, and the tubing was tested to 2417 psi. The source of TAA is believed to be in stations 3 and 2. Proposed Plan: / The CDR2 rig will swap the tubing to restore tubing integrity. MASP = 2520 psi. CDR2 BOPE will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer • Mud cross with outlets for choke and kill lines One VBR preventer. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to replace tubing to restore tubing integrity. Pre -Ria Prep Work: 1. V: PPPOT-T, PPPOT-IC. Cycle LDS. 2. F: CMIT- TAA to 3000 psi, OA Integrity test. 3. E: Cut Tubing at -8800' MD 4. F: CMIT-TxIA to 1000 psi. Circulate out well. 5. V: Install BPV. Install dry hole tree 6. O: Bleed WHP(s) to zero. Remove the well house and flow line. Install wellhead valves as needed. Install dry hole tree. Level the pad as needed. Proposed RWO Procedure: 1. MIRU. ND tree. NU and test BOPE to 3500 psi 2. Pull 4-1/2" tubing from pre -rig cut at -8800' 3. Run new 4-1/2" 13 -CR Stacker Packer Completion. 4. Freeze protect well. Set TWC. ND BOPE. NU and test tree. Rumu. Post rig Work: 1. V: Post RWO, install production tree 2. S: Drop B&R. LRS to set packer. Pull B&R. Se GLVs. Pull RHC. Pull W P. 3. F A/SL: Circ Fluid. Set Packer. U -Tube FP. /V %--Z:AA SPS r 4. V: Tree work as necessary. Surface Reconnect Sean McLaughlin CC: Well File RWO/CTD Engineer Joe Lastufka 223-6784 TREE= 4-1/16'CAN W8-LHEAD= FRC ACTUATOR= _ BAKER OUB. B..EN = _—W.f BF. ELEV = 37.2' KOP= 1800' Men Angie = 98' @ 12809' Duwm ku= 976T Datum TVD= _ 0800—SS ,� D = 8.835' H 3121' DEPTH UNKNOWN (12!05/17) CBABJT SHEATH, D= 3.70'(0123/09) H 8886'$990' Minimum 1D = 2.45" @ 8498' 45 FLO-GUARD PATCH 14-12' TBG,12.6#, L-80, .0152 bpf, D = 3.958' FISH - 1 45KB FKR ELBNB1f LOST (12/01/17) 9774' = 3.613' 9792' 1/7 HES XN NP, D = 3.725' 1--1 9798' 4-12' WLEG, D = 3.958' 9808' PERFORATION SLA"RY REF LOG: PDS JEW9..RY LOG OF 09115/99 ANGLE AT T0P TER!". 68' Q 9807' SEE PG 2 FOR PERFORAT0N DATA S-43 L1 SAFETY NOTES: WELL ANGLE> 70 DEG @ 9820'. RESTRICTION 2' BELOW STA#1' (ID -3.25')"• FISH- MISC PARTS FROM STA #6 (3121106)"' -1rr Htti ru0 ssSVN, D= GAS LFT MANDRELS ST NO 1TVDIDEVI 06422/97 ORIGINAL COMPLETON TYPE VLV LATCH PORT DOTE 7 3028 2977 18 KBG-2LS DAN M 0 07/29/17 6 5306 5144 19 KBG-2LS DW M 0 0729/17 5 6508 6279 18 KBG-2LS DMI M 0 04/30/07 4 7205 6941 18 KBG-21-S OW M 0 0729/17 3 8063 7756 20 KBG-2LS '**D& M 0 12(06/17 2 8507 8172 21 KBG-2LS "DMI M 0 03113/14 1 8952 8518 56 KBG-2LS 'DMI M 0 0123/09 - STA #1 - OMY w OUB41)® HCG (BEH6D CMT SHEATH) -STA #2 - DMY w ID(TBNDED PKG -*STA #3 - MDDFT1) DM, 1/2 LONGER w IFRLUE BERG PKG 9021' 4-12' HE4 X NP, D = 3.813' x 9055' —14-12' HES X NP, D= �9p8W_j-l4-12-V%LEG,D=3.958' I ELMDTTL0GGED09/15/99 7' CSG MLLOUT WMD0VV(S43 LI) 9749'-9761' I 9784' BKR SEf11VG SLV, D = 5.250- ---------------------- --------------------- S-43 .250'-5-43 L1 IS AN OH SLID LNR w/OUT LTP / HGR WELL NOT WL ACCESSIBLE 4-12'SLTD LM3,12.6#,L-80, 13 .0152bpf, D= 3.958' 1006W 1-17" TIEBACK SLV, D= 5.374" 1 10066' 7-X 4-12' TNV S-6 PKR D = 3.868' 12872' D=3.958' 13807' DATE REV REV BY CONFAENTS DATE REV BY C0AT434T5 06422/97 ORIGINAL COMPLETON 07131117 ZV/JAD GLV C/O (0729117) 12/15111 PJC VVVLL NAMECORRECTION 12/18/17 BSP AD PILL®HATCWSETWRPS FISH 04/15114 PJC MN[)CORRECTDN 12/18/17 ZV/.MD GLVaO(12106117) 04/17114 VNO'! GIV CIO (04/14/14) 11/03/15 DISUAD GLV CIO (11/01115) 0724117 JPKIJAD GLV C40 (07/19/17) P18AHOE BAY UNIT WELL: 5-431 L1 PEFMT Nb: 197052011970530 AH No: 50-029-22754.00 (60) SEC 35, T72N, T12F 1068' FNL 8 T7T FVVL BP Uploratfon (Alaska) S-43 L1 ) qft� P87FORATIONSUA ON09 � —---------------- --� FEF LM LFDS JE1haF'Y ON 09!15199 — — — — — — — _ _ ANGLE AT TOP PERF: 68`Qi 980T — Note: Refer to Production DB for historical perf data 5-43 Lt IS AN OH SLT'D LNR w LOUT LTP I HGR SIZE SPFINTERVAL Opn/Sqz SHOT SOZ S-43 L1 WELL NOT WL ACCESSIBLE 4-12' I SLTDI 9807 - 13912 I O I a6MM7I S-43 Y 4 10600 - 10620 O 05/17102 2' 4 10645 - 10670 O 05/17/02 2' 4 10710-10726 O 05117M2 2' 4 11840 - 11890 O 05/17102 2' 4 11915 - 11940 O 05/17M 2' 4 12010 - 12065 O 05/172 2' 4 12100 - 12250 0 09/16" 2' 4 12310-12490 O 09/16199 4-12' SLID 12913 - 13805 O 0622/97 R3IDHOE BAY LINT WELL: S-43 / L1 FERIAT No: 1970520 /1970530 AR No: 50-029-22754-00 (60) SEC 35, T12K TM 1068' FN- 877T FWL BP EcploraWn (Alaska) DATE FAV BY COMMENTS DOTE REV BY C0M4B4T5 0622A7 �EGINAL COMPLETION 07/31117 ZV/VMO GLV M (0729117) 12/15111 PJC WH1 P14ME C0I�ECf10N 12/18/17 BS&JhD FU1®PATGi1'SEf WTiP8 Fl5fi 04115114 PJC MN DODPoY�.'TK)N 12/18717 ZVIJkD GI.V CJO (12/0fV17) 04/17/14 WI�lJ GLV dO (04114114) 11!031 15 DJS/JAO GLV C!0(11101115) 07124117 JFKIJMD GLV dO (01119/17) TREE = 4-111 S' CMV WELLHEAD = FMC ACTUATOR= BAKER OKB. ELEV = 68.1' BF. ELEV = 37.2' KOP= 1800' Max Angle = 98" @ 12809' Datum MD = 9762' Datum TVD= 8800'SS 9-5/6" CONDUC -an in - n TOP OF W CEIVIENT(01/23/09) 8817' 4-1/2'SGWRP(12/04/17) 8867' S-43SAFETY RESTRICTION2'SOWSTA#: WELL E'(ID=3.25 70 DEG@ -)—FISH-r Propose: Li MISC PARTS FROM STA #6 (3/24106)"` 2197' 9-5/8' ES MANTB2 CEMENT SHEATH, ID=3.70"(01/23/09) 8885'$990' 4-1/2" HES X NIP, ID = 3.813" 4-1/2'x7" HES 'TNT' PKR, ID=3.88" 4-1/2' HES X NIP, ID = 3.813" 4-1/2" UMI Overshot —1 9021' I-j4-1/2'HESXNP,ID=3.813" 9032' 7" x 4-1/2" BKR S-3 PI(R F73.8775 3.875" 9055' 4-1/2" HES X NP, D = 3.813" 9077' 4-1/2" HES X NIP. ID = 3.813' PPTAG I1 9578' r7 I I 7- CSG MLLOUT WNDOW (S-43 L1) 974W-9761- =3.875^ 9774' ----------------I 3.813" 9792' S-43 L1 IS AN OH SLT'D LNR w/OUT LTP / HGR -3.725" 9799' WELL NOT WL ACCESSIBLE 4-1/2" WLEG, D=3.958" 9808' PERFORATION SLA MRY REF LOG: PDS JEWELRY LOG OF 09/15/99 ANGLEATTOPPERF:68^@ 9807' Note: Refer to Production DB for historical oelf data SEE PG 2 FOR PERFORATION DATA 100059, 10065' 10070' 12872' LNR, 12.6#, L-80,.0152 bpf, D = 3.958" DATE REV BY COMvENTS DATE REV BY COMv164TS 06/22/97 ORIGINAL COMPLETION 07/31/17 ZV/JM7 GLV C/O(07/29/17) 12/15/11 PJC WELL NAM£ CORRECTION 12/18/17 BSE/JMO PILLED PATCH/SET WRP & FISH 04/15/14 PJC MN 1)CORRECTION 12/18/17 ZV/JMO GLVCIO(12/06/17) 04/17/14 WKRJMD GLV GO (04/14/14) 11/03/15 DIS/JM) GLV CIO (111101/15) 07/24/17 JPK/JMO GLV UO (07/19/17) I.0152bpf, D = 3.958- TIEBACK .958"TI BACK SLV, D = 5.374" X41/2"TM/S-6 PKR D=3.868" I X 4-1/2" TNV DTHS HGR D = 3.925" 4-1/2" ES CI3uS"fTHR _ 12884' CTC EXT CSG PKR D = 3.885' 13807' — — — - PRUDHOE BAY UN T WELL: S-43 / Lt PERMT No: 197052011970530 AR No: 50-029-22754-00(60) SEC 35. T12N. T12E 1068' FNL & 777' FWL BP Exploration (Alaska) 12' HYDRIL 13-5/8" 5K PSI GK ANNULAR BOP LATCHED HEAD 5K FLANGE CONNECTION 3-1/8" 5,OOO1 WP CAMERON TYPE "F" GATE VALVE HYDRIL 13-5/8" 5k PSI MPL SINGLE GATE 3-1/8" 5,0001 WP FLANGED CONNECTION CAMERON HCR VALVE DRILLING SPOOL 1/16" KILL LINE 13-5/8"-5K PSI FLANGED 3"-5K PSI FLANGED OUTLETS HYDRIL 13-5/8° 5k PSI MPL SINGLE GATE FLANGED CONNECTION THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean M. McLaughlin Engineering Team Lead — CTD & RWO BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU S-43 Permit to Drill Number: 197-052 Sundry Number: 319-076 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogc c.a lasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner d n DATED this 2Z day of February, 2019. �� ,i11419 �goMs STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 CSE 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ® Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 197-052 ' 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-2275400-00 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU S-43 - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028257 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD). Junk (MD): 13889 9018 BBfi7 8465 2520 8867 8498,9070,9077,9774 Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 3087 9-5/8" 34-3121 34-3066 5750 3090 Intermediate 9718 7" 31-9749 31 -8963 7240 5410 Production Liner 3748 4-1/2" 10059 - 13807 8978-9013 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MO (ft): 10600 - 13805 1 90-9012 4-1/2" 12.6# L-80 28 - 9089 / 9774 - 9808 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9032/8559 4-1/2" Baker ML Packer 9774/8875 12. Attachments: Proposal Summary ® Wellbore Schematic m 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ® Exploratory ❑ Stratigraphic ❑ Development m Service ❑ 14. Estimated Date for Commencing Operations: May 1, 2019 15. Well Status after proposed work: Oil 61 . WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hartley, Josephine be deviated from without prior written approval. Contact Email: Josephine.Hartley(Mbp.com Authorized Name: Mdaughlin, Sean M Contact Phone: +1 9075644570 Authorized Title: Enineenng Team Lean - CTD & RWO Authorized Signature:,Date: 7 I COMMISSION USE ONLY Conditions of approval: Notify Commission so— that a representative may witness Sundry Number: 4 101 I _ IWiI 5' `/'A' Plug Integrity ❑ BOP Test IWtaMechanical Integrity Test ❑ Location Clearance ❑ 1 A��. Other: UL9ne1^G� ,l. (nspy e t o `I—C2 X19©�5 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑/ Spacing Exception Rqlquired? Yes No fd Subsequent Form Required. Ll6 y' APPROVED BYTHE 7(2— Z�/9 Approved by: COMMISSIONER COMMISSION Date G CP Form 10403 Revised D4/2017 ORIGINAL RBDMg`�VE@2`T251 t�RLz I Submit Form and Approved application is valid for 12 months from the date of approval. Attachmen m Duplicate `ii�C01 Z zi-/ 7o: Alaska Oil & Gas Conservation Commission From: Josi Hartley RWO/CTD Engineer Date: February 18, 2019 bp Re: S-43 Sundry Approval Well Type: Producer Current Status: The well is currently not operable due to corrosion and multiple tubing leaks. Request: Sundry approval is requested for plans to restore tubing integrity. History and current status: Well S-41 was drilled as a multi lateral completion in 1997 with L-80 liner and tubing. The original tubing is still in the well. The well has a history of failing TIFLs. The well has had two tubing leaks since the well was originally completed. The first tubing leak was at station 1, and was squeezed in 2009. The well was operable from that point until 2014, when it failed another MIT -IA. The second leak was identified at station 2 and was patched. In 2017 The well was found to have IA pressure over normal operating limits, due to failed SO check valves. Slickline performed a caliper which indicated multiple areas of corrosion, with most severe penetration at 4645' MD. A plug was set at 8867' MD, and a CMIT-TxIA was performed in December of 2017 to 2395 psi. An attempt was made to set a dummy valve in station 3, with no success. A second plug was set above station 3, and the tubing was tested to 2417 psi. The source of TAA is believed to be in stations 3 and 2. Proposed plan: The All American Oilfield 111 pulling unit will swap the tubing to restore tubing integrity. MASP = 2520 psi. AAO 111 BOPE will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer • Mud cross with outlets for choke and kill lines • One Ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to replace tubing to restore tubing integrity. Pre -Rig Prep Work: 1. V: PPPOT-T, PPPOT-IC. Cycle LDS. 2. F: CMIT- TxIA, OA Integrity test. 3. E: Cut Tubing at -8800' MD 4. F: CMIT-TxIA. Circulate out well.�' 4 5. V: Install BPV. Tree Work 6. O: Bleed WHP(s) to zero. Remove the well house and flow line. Install wellhead valves as needed. Install dry hole tree. Level the pad as needed for the pulling unit. Proposed RWO Procedure: 1. MIRU. NO tree. NU and test BOPS. y�I,,,c- 2. Pull Tubing. 3. Run new 4-1/2" 13 -CR Stacker Packer Completion. 4. Freeze protect well. Set TWC. ND BOPE. NU and test tree. RDMO. Postria Work: 1. V: Post RWO Tree Work 2. S: Drop B&R. LRS to set packer. Pull B&R. Set GLVs. Pull RHC. Pull WRP. 3. F A/SL: Circ Fluid. Set Packer. U -Tube FP. 4. V: Tree work as necessary. Surface Reconnect Jos! Hartley CC: Well File RWO/CTD Engineer Joe Lastufka 564-4570 4-1/16' aW WELLHEAD= FMC -L 907W ACR ATOR= BA1032 OKB. ELEV = 68.1' TYPE BE EFEV = 37.56, TBG,12.6#, L-80, .0152 bpf, D = 3.958' KOP= - - 18W Max Angle = 98' Q 12809' 7 Datum MD= 9767 : _ -CONOIX;TOR, #• Datum N BOW Ss,S. D ' 9-5/8' CSG, 40#, L-80, D = 8835- 1/2 OF A DSD TOP OF W CEMENT 4-12' Sr-WRP ( EATH_ D=370'(01 Minimtmn ID = 2.45" @ 8498' 45 FLO-GUARD PATCH 1 45K PI02EFB1E'fT LOST(12/01/17) -L 907W FLSH-BPB-BrE4TS (01/14/09) H 9077' TYPE VLV TBG,12.6#, L-80, .0152 bpf, D = 3.958' 9088' 2 RA PPTAG 1--1 9578' BKR ML PKR, D = 3.875' 9774- 7 HES X NP, D = 3.813' 9792' 14-12' HES XN NP, D = 3.725' 1 IRA PP TAG I 7' CSG, 26#, L-80, .0383 bpf, D = PERFORATION SLANVARY REF LOG: POS JBAE RY LOG OF 09/15/99 ANGLEATTOPPEW:68'@ 9807' Note: Refer to Production DB for historical pert data SIZE I SPF I M82VAL I OprJSgz I DATE SEE PG 2 FOR PEF FORATION DATA S 4'3Ll 0152 SAFETY NOTES: WELL ANGLE> 70 DEG @ 982(r.' RESTRICTION 2' BELOW STA#V (ID=3.26')"' FiSH- MISC PARTS FROM STA #6 (324106)"' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3028 2977 18 K13G2LS DMY r4T 0 0729/17 6 5308 5144 19 K3G-2LS DMY M 0 0729/17 5 6508 6279 18 KBG-2LS DMY NY 0 04/30/07 4 7205 6941 18 KBG-2LS DMY M 0 0729/17 3 8063 7756 20 K3G2LS M 0 12!06/17 2 8507 8172 21 KBG-2LS -DMY M 0 03/13/14 1 8952 8518 56 KBG-2LS *DMY M 0 0123109 'STA #1 - DOM w /EXTEND® PKG (BEHIND CMT SHEATH) -STA #2 - DMY w1EXT80ED PKG —STA #3 - MODFID DMY, 112 LOWER w /FRLUBBERG PKG 9n'11'44-1M'HFSXNP D=3813' 9032' 1 17' z 4-12' BKR S-3 PKR D = 9055' 1-j4-1/2' HES X NP, D=3.813' 9077' I-14-12' HES X NP, D = 3.813- --L 9089 -_J -j4-12' WLEG D=3.958' 9088' EFMD TT LOGGED 09/15199 4-12-SLTD LNR,12.6#,L-80, I 13945' .0152br 10069- 1-17- SLV, D=5.374' 10066' 7- X 4-12' TIW S-6 R<R D = 3.868' 1 nn7fr 7- X 4-12' TW MT4-S HOR D=39 12872' 4-12'Es cEMENTat 12884' CTC EXT CSG PKR. _ D= 3.885' 7- CSG MLLOUr WINDOW (S-43 L1) 9749' - 9761' I 97$4' BKR SETTING SLV, D= 5.250' DATE REV BY GOAT EJTS -------------------- ---------------------T 06/22/97 ORIGINAL COMPLETION S-43 L1 IS AN OH SLT'D LNR w/OUT LTP I HGR 12/15/11 PJC WELL NAME -CORRECTION 12/18/17 BSBJMD PILLED PATtiYSET WFF B FISH WELL NOT WL ACCESSIBLE 12/18/17 ZV/JMD GLVCIO(IV=17) I 4-12-SLTD LNR,12.6#,L-80, I 13945' .0152br 10069- 1-17- SLV, D=5.374' 10066' 7- X 4-12' TIW S-6 R<R D = 3.868' 1 nn7fr 7- X 4-12' TW MT4-S HOR D=39 12872' 4-12'Es cEMENTat 12884' CTC EXT CSG PKR. _ D= 3.885' PR JDHOE BAY LUT WILL: S -43/L7 PERMT No 1970520/1970530 AR No: 50-029-22754-00(60) SEC 35, T12K T12E, 1068' FOL 677T FWL DATE REV BY GOAT EJTS DATE REV BY COMMENTS 06/22/97 ORIGINAL COMPLETION 07/31/17 ZV/JMD GLV CIO(0729117) 12/15/11 PJC WELL NAME -CORRECTION 12/18/17 BSBJMD PILLED PATtiYSET WFF B FISH 04/15/14 PJC MN DCORFECT10N 12/18/17 ZV/JMD GLVCIO(IV=17) 04/17/14 1/4101' GLV C/O (04/14114) 02/19/19 JNVJMD ADDE7 DATES TO FEW®IT BE EFEV 11/03/15 DJSI,MD GLV C/O(11/01/15) BP Exploration (Alaska) 0724/17 JFWJMD GLV C/O (07/19/17) PERFORATION SUMMARY -. RE= LOG PDS JEWELRY ON 09/15/99 ANGLE AT TOP PERF: 68` @ 9807' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sgz I SHOT I SOZ DATE RBI BY CORNAENTS S43 Lt 12/15/11 PJC WELL NAME CORRECTION 12/18/17 BSE/JM7 PULLEDPATCHSET WRP & RSH 4-1/2-1 SLTD 1 9807 - 13912 I O 106/22/971 S-43 0724117 JPKIJMD GLV CIO (07/19/17) 2" 4 10600 - 10620 O 05/17102 2- 4 10645 - 10670 O 05M 7102 2" 4 10710 - 10726 O 05/17/02 2" 4 11840 - 11890 O 05/17/02 2" 4 11915 - 11940 O 05/17/02 2" 4 12010 - 12085 O 05/17/02 2" 4 12100 - 12250 O 09/16199 2" 4 12310 - 12490 O 09/16/99 4-12" SLTD 12913 - 13805 O 0622/97 S-43 L1 Of ---------------------- �► �'---------------------� S-43 L1 IS AN OH SLT-D LNR w/OUT LTP / HGR WELL NOT WL ACCESSIBLE I PRUDHOE BAY LUT WELL_ S -43I L1 PERMIT No: 1970520 11970530 AR No: 50-029-22754-00 (60) SEC 35, T12N, T12E, 1068' FNL & 777' FW - DATE REV BY CONNA34TS DATE RBI BY CORNAENTS o622197 ORIGINAL COMPLETION 07/31117 ZV/JMD GLV GO (0729117) 12/15/11 PJC WELL NAME CORRECTION 12/18/17 BSE/JM7 PULLEDPATCHSET WRP & RSH 04/15114 PJC MN D CORRECTION 12/18/17 ZV/JhD GLV GO (12106117) 04/17114 WOM GLV GO (04/14114) 02119/19 JNL/JhD ADDED DATES TO FISW®IT BF E LB/ 1V03115 DISIJMD GLV GO(11/01/15) BP 6g,loration (Alaska) 0724117 JPKIJMD GLV CIO (07/19/17) TRff = 4-1/16" CNV WELLHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 68.1' BF. ELEV = 372 KOP= 1800' Max Angle = 98" @ 12809' Datum MD = 9762' Datum TV D= 8M, ss 1 9-5/8" CSG. 40#. L-80. D = 8.835" 1 F7 S-43 Proposed L1 TOPOFACBVE�IT(Ot/23/09) 8817' 4-1/2"SC-WRP(12/04117) 8867 14-112" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" I RA PP TAG 7" X 4-1/2' BKR ML PKR, D = 3.875" 9774' 4-1/2" FES X NP, D = 3.813" 9792' — 4-1/2" HES XN NP, D = 3.725" 9799' 4-112" WLE G, D = 3.958° 9808' IRAPIPTA�14 9824' 1 10059' 1 7" CSG, 26#, L-80_0383 PERFORATION SLANMRY REF LOG: PDS JEWELRY LOG OF 09/15/99 ANGLEATTOPPERIF 68°@ 9807' Note: Refer to Production DB for historical pert data 2 FOR P3FORATION DATA SAFETY NOTES: WELL ANGLE> 70 DEG @ 9820'. RESTRICTION T BELOW STA#1' (ID=3.25")""" FISH - M ISC PARTS FROM STA #6 (3124/06)""' 2197' s s/e" Es cEvTER 4-1/2" HES X NIP, ID = 3.813" 4-1/2" HES X NIP, ID = 3.813' F----14-112"X7"HES'TNT'PKR,D=3_88" 4-1/2' HES X NIP, ID= 3.813" 4-1/2' UMI Overs hot !D=18113" 9032' 7" x 4-1/2" BKR S-3 PKR. D = 3.875" 9055' I COMMENTS 4-1/2" FTS X NP, D = 3.813" 9�— I 4-1 /2 --HE SX NP. —ID—= -3-8-1 —3 " 9089' 4-1/2" WLEG, D=3.958" ELM TT LOGGED 09/15/99 7" CSG MLLOUT WINDOW (S-43 LI) 9749'-9761- --------------------- D 749'-9761' D LNR w10UT LTP / HGR WELL NOT WL ACCESSIBLE 10070' — 1287r 4-1/2-SLTD LNR,12.6#,L-80, .0152bpf, D= 3.958' X SLV, D=5.374" 1 " TNV S-6 PKR, D = 3.868" _ D = 3.885" /z4— _ _ L-80, .0152 bpf, D = 3.958" 13807' ' _ DATE REV BY I COMVE-NT'S DATE I REV BY I COMMENTS 06122197 ORIGINAL COMPLETION 071311171 ZV/JND GLV C/O (07129/17) 12/15/11 PJC WELL NAME CORRECTION 12/16117 13SEIJNU PULLED PATCWSETWRP&FISH 04/15/14 PJC MN DCORRECTION 12/18/17 ZV/JMD GLVCVO(12/06/17) 04117114 WKP/JNU GLV GO (04/14/14) 11/03/15 DUS/JMD GLV CIO(11/Ot115) 07/24/17 JPKIJMD GLV 00 (07119117) PRUDHOE BAY UNrr WELL: S-43 / L1 PERMrr No: 1970520/1970530 AR No: 50-029-22754-00(60) 15, T12N, T1 2F, 1068' FNL & 77T FWL 13P Exploration (Alaska) 1 2 3 4 4'-2" ° ° — e A A 3._81 s�B SHENKAI SL 13-5M ANNULAR 6''103/16 3'-1., Z:[o SHENKAISL 13-5M DOUBLE RAM B B 8._5n 4,-611/6" 3'-2$/s' 5='/z" ilk C C 1'-93/4" ° 10'-4" 0 1x_41/2,. ° ° eio 5'-31/z" ZMINPEN CLOSING,' OPEN1141 VOLUME GAL ITEMS CLOSING VOL OPENNING VOL 30" ANNULAR 23.59 17.41 RAM 4.39 3.91 D D HCR 0.40 0.40 TIE CENTEN50F eoP 13-5M BOP STACK �= TRLNOTE$: gREiXEPROPERTYOvAER NO NFORMATIONINTMS ENERGY SERNCESCOA-0Oo-15-0D2 RE%10DUCTION aF npREFERENCE :7— PER x18&p1 OF ME5T`'M°"^T` ONLY vRAVPNC INTTHCUl rn°� TV a t6IFeb120Te N.T.S.OqND I$I'KIT FOR Tr Mm 01/M.r2ot! �g�rCWi$TRI.CTION 0 IMTIPL RELEASE ENERGY SHiNCESCOAFGAOVE° MTEwEv Er APPo ;T siwcnrPRonrertsoMJP D1IMetl201$ A 1 OF 1 °ESCR'VIICN 2 3 4 1 • • Pgct S-43 ('t 1 o-o Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, November 28, 2017 3:43 PM i s /1(7,.` 1 To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA); AK, GWO Well Integrity Well Information;AK, GWO SUPT Well Integrity Subject: RE: Producer S-43 (PTD# 1970520) inner annulus over NOL Mr. Regg, S-43 secure program was submitted to the well work backlog on 8/15/17. It was originally scheduled to be executed on 9/28/17, but was pushed due to subsidence work that was being conducted on the pad. The completion of the subsidence work corresponded to the start of rig activities and the well secure was further pushed out. Once the rig started work on S-200A the site was walked down to see if a slickline unit could safely rig up on S-43, but there were work until thepad. made to delayrig was off the concerns around SIMOPS so the decision was the secure The bottom line is an opportunity was missed between 8/15-9/28 where the work could have been executed had the priority been effectivity communicated to all parties. Our internal KPIs dictate that wells under evaluation be repaired or secured within the 28 day window, but occasionally (as with S-43) complications arise that preclude setting a downhole plug. Once a well goes not operable,the well priority falls in line with normal well work and gets scheduled/executed with adherence to our activity planning requirements (3 weeks out). We have identified this as a gap and are currently in the process of implementing a new work code that will give high priority to securing not operable wells. We expect that this new heightened priority and visibility will eliminate the delays we experienced with S-43. I would be more than happy to elaborate further if you have any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, November 27, 2017 2:40 PM To: AK, GWO Well Integrity Engineer Cc: Wallace, Chris D (DOA); AK, GWO Well Integrity Well Information Subject: RE: Producer S-43 (PTD# 1970520) inner annulus over NOL Parker 272 mobilized to PBU S-pad the last week of October. Why did it take 3 months to develop a secure plan for this well? Jim Regg Supervisor, Inspections AOGCC 1 • • 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:AK, GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent:Sunday, November 26, 2017 9:07 AM To: Regg,James B (DOA) <jim.reggCa@alaska.gov> Cc:Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; AK, GWO Well Integrity Well Information <a kgwowel lintegritywe@ bp.com> Subject: Producer S-43 (PTD# 1970520) inner annulus over NOL Mr. Regg, S-43 (PTD# 1970520) is a not operable producer that has known TxIA communication. The well was made not operable on 7/31/17, but was not immediately secured due to restrictions in the tubing blocking access to the x nipples in the tail pipe. A secure plan was developed for this well, but has not been executed due to SIMOPs issues with Parker 272 drilling rig . On 11/24/17 the IA pressure exceeded NOL and was found at 2,090psi. The confirmed T/I/Os were 2090/2090/100psi. Attempts to bleed the well were not made due to the IA being open to the formation. The current plan forward is to execute the secure program as soon as the drilling rig moves off the pad; current ETA is 11/28/17. Please let me know if you have any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 2 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,July 31, 2017 3:24 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S;AK, OPS Well Pad SW;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie; Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK,OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer S-43 (PTD#1970520)TIFL Failed Post GLV Change out All, Producer S-43 (PTD#1970520)was made under evaluation on 6/20/17 for failing a diagnostic TIFL. Slickline performed a gas lift valve change out on 07/19/17 and the well failed a subsequent warm TIFL on 7/21/17. A tubing caliper ran on 7/28/17 indicated areas of significant wall loss below the tubing patch at 8498'. The 28 day evaluation period has expired and the well is now reclassified as Not Operable and will remain shut in. An inflatable bridge plug will be set below to packer to secure the well while the engineering team develops a plan forward. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO %AWED From: AK, ' . - '1 ell Integrity Sent: Monday, July 17, 201 • To: AK, OPS GC2 Facility OTL; AK, OPS 'eld O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS W • . P S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Be •;•- Matthew; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson; Wellman, Julie; Youngmun, Alex; Zoesch, Eric, • -aa, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Comple •• Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, • . e Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'conno , . •therine; 1 • S Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday,July 17, 2017 3:57 PM To: AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK,OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S; AK, OPS Well Pad SW;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Comi letions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UPDATE 07/17/17: UNDER EVALUATION: Producer S-43 (PTD#1970520) Inner Annulus over NOL - Failed TIFL ' All, Online diagnostics on Producer S-43 (PTD#1970520)were delayed due to a pad shut-down.Slickline is scheduled to change out the orifice gas lift valve within the next week.The Under Evaluation clock is reset for an additional 14 days. Work Completed/Plan Forward: 1. Downhole Diagnostics: Cold TIFL Failed 06/20/17 2. Operations: POP well—Completed 07/09/17 3. DHD: Warm TIFL—Failed 07/10/17 4. Slickline: Change out orifice gas lift valve 5. DHD: Warm TIFL 6. Well Integrity Engineer:Additional Diagnostics as needed Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska r (Alternate:Jack Lau) SCANNED .h U`� 0 7 ?.(11 0:(907)659-5102 C:(907)943-0296 H:2376 From: AK, ': A ell Integrity Engineer Sent: Tuesday, June s, • 7 12:42 PM To: AK, GWO Well Integrity Engi - • 'K, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops L- • ;K, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt = • AK, OPS WELL PAD S; Bergene, Matthew; Regg, James B (DOA) (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; A I ;•• User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk,Corey; Obrigewitch, Beau; St- i Oliver R; Worthington, Aras J; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer S-43 (PTD#1970520) Inner Annulus over NOL- -• TIFL 1 • . Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,June 20, 2017 12:42 PM To: AK, GWO Well Integrity Engineer;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;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer S-43 (PTD#1970520) Inner Annulus over NOL- Failed TIFL All, Gas lifted Producer S-43 (PTD# 1970520) exceeded NOL on the inner annulus and failing a subsequent TIFL on 06/19/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The current estimate for S pad to come back online is 06/30/17. At this time the well is classified as Under Evaluation,and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations- POP well 2. Down Hole Diagnostics: Perform Warm TIFL 3. Well Integrity Engineer: Additional Diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 SCANNED JUN 2 3 2017, • Cell 907-980-0552 Harmony 4530 1 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,June 14, 2017 7:05 AM To: AK, GWO Well Integrity Engineer; Regg,James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity Subject: Producer S-43 (PTD# 1970520) and S-109 (PTD#2022450) High Inner Annulus Pressure Over NOL after pad shutdown. Attachments: S-43.pdf; S-109.pdf Mr. Regg, Gas lifted producers S-43 (PTD# 1970520),and S-109 (PTD#2022450)were reported over NOL on 6/13/17. The pressures were reported to be T/I/O=220/2018/50psi for S-109, and 220/2011/100psi for S-43. The high pressure event was discovered shortly after a pad shut down and appears to be caused by a spike in the gas lift supply header pressure. The plan forward is to bleed the IA and perform follow up monitors to ensure this is not an integrity issue; if we see any repressurization the well will be made under evaluation at that time. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 ►W�►4wNs` .;11,1 2 Cell: 907-341-9068 WO Ilia!reit,arvimai1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 177- oCx File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: [] Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type -OVERSIZED [] .Logs of vadous kinds n Other Complete COMMENTS: Scanned by: ~r~ Mildred-D~relfla ~ Low~i TO RE-SCAN Date: Notes: Re-Scanned by: ~verb, Mildred Daretha Nathan Lowell Date: /s/ STATE OF ALASKA RECEIVED • A ,KA OIL AND GAS CONSERVATION COMM. :ION MAY 1 2 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L... Performed: Alter Casing Pull Tubing0 Stimulate-Frac 2 Waiver 2 Time Extension Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 2. Exploratory ❑ 197-052-0' 3.Address: P.O.Box 196612 Stratigraphic0 Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22754-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028257 PBU S-43 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 13888.8 feet Plugs measured None feet true vertical 9017.56 feet Junk measured See Attachment feet Effective Depth measured 13807 feet Packer measured See Attachment feet true vertical 9012.5 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 31-111 31-111 1490 470 Surface 3091 9-5/8"40#L-80 30-3121 30-3065.55 5750 3090 Intermediate 10169 7"26#L-80 27-10196 27-8991.35 7240 5410 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10600-10620 feet 10645-10670 feet 10710-10726 feet 11840-11890 feet 11915-11940 feet 12010-12085 feet 12100-12250 feet 12310-12490 feet 12913-13805 feet True Vertical depth 8989.98-8992.08 feet 8994.81-8997.68 feet 9002.44-9004.2 feet 9025.03-9022.11 feet 9021.72-9021.48 feet 9020.21-9018.06 feet 9017.57-9012.79 feet 9011.16-9011.69 feet 8985.61 -9012.38 feet 1 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-9089 25-8584.48 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED WIAY P .A ?IN IN 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 226 1090 1854 1675 232 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development 2' Service U Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q. Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGG 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 Garry Catron Email Garry.Catron( BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 5/9/2014 Vi_ F _1-/z / 14' RBCMS MAY 14 20141 Fnrm 1n-4n4 Revised 10/7017 Submit Oriainal Only S-43 197-052-0 Junk Attachment SW Name MD Date Description S-43 9077 1/14/2009 IBP Element&Stiffiner Ring S-43 9774 9/26/2009 2 Stem Rollers Packers and SSV's Attachment ADL0028257 SW Name Type MD TVD Depscription S-43 PACKER 9032 8558.59 4-1/2" Baker S-3 Perm Packer S-43 PACKER 9774 8874.81 4-1/2" Baker ML Packer mo000000 � N — 000rno Ln Ln in o Ln O LO N- N- M M N- V e• 00000 NrMMOLoco • N ' Ln 1� x- I,- CO 00 M Ln CO Ln CO N- Ln CO COLLn '- Ln NOL() O) (3) 0 0) CO CO 0) 00 F O LO CO 00 O 00'M 00 CI 00 00 CO N CO ;CN r- �'co,M N CO 100000 CO 0 000 LM F CO a CO00 M , EIIIIIII CUtft < In M N D p N M N CO csi _ 0o 0 (0 Q O 000 000 a 0 co 1 O J J j ' 4* 0 4t _= d 4 CO 30( o o LO A N N N y N _ oF F L9 F NI I m O) 4 (V O) coO O co • 0 0 M M M() O) W ca c° o U W LU 0 0 O c t W V LL Z Z W W W m O < : 0 9 5 - -N - / / / / & 1 \ \ \ cD -< # # a CO m _ ] 2 ` G = : : T g caw D 0 0 0 2 E O > G@ 2 2 : 2 / g � \ / \ � , / � / zk13;01—'0 / / � \ EQ � / / 7U) II CD ,- mOr5Q01? ® ® ? gym ® M@f \ 5 \ ri a = % 2 r \ I a a �i 0 0 2 0 a -1 _ r- r _ s ) e 0 / 2 -, B / -0;$ G 5 % / G E o $ / 2 $ w m -' /co ^ 2 u �„® / q 0 q mi- 000 .<\ 0 \ w u + a a O 2 $ �'� I) ® / / \ II II II / / _ 00-20 > m (02 k / \ / > /�17 / \ - O = \ / / % \ / e e@ f - / m f \ / 2 P -1 \ \ / 0 m m m \ / 2 \ H 11) a 0 m e ( 2 m _< oI� I R r > Z G a < < m -• / J $ - / $ / , ,.., • 0 -I ƒ H �� \ / ii / 7 C m * / * / CD \ / 1 - �� 0 O m' i-n -, / , Q 11 m \ o_ - ,� p m = e R e o = - $ 0 2 = 2 @ , o - 2 0 a - w r T $ H / 2 - 2 \ \ / / 2 \ A / X / r Z \ O 0 P• _ > 2 m o \ ® ® � � � 6 �� / � � ® � � / co / k m \ f 5 2 / A m i r \ 0 _ co \ 5 0 2 m / c \ / \ \ T_ \ , r --I 0 / 0 E v = �-0 / - f 0 � \ -I z $ J ƒ Z 'AO / \ f C 0 0 H 0 > H / < > m ® _ - 0- / A O m > ? 0 m Q - g / / \ \ > / > �� f q / / / 0 g a w 2 & $ 0 / o / 0 \ §. = a 2 Q g m - O a ° ° 0 2 ® \ \ 0 To 0 m 2 co 3 = E » 0 0 ; - co / = 2 in g 0 > H > ® 2 0 > = G > % op \ p / m % i 0 II - \ f \ \ 3 / / ° » Z 2 $ e \ -0 / m 0 H _. 0 55 / / I - / © * 0 ® (0 r- \ / % p $ M m TRS 4-1/16"CNV SA NOTES: WELL ANGLE>70 DEG @ 9820'.' LI-EAD= FMC S 4 3 RES'rdCTION 2'BELOW STA#1'(f)'3.25")"'FISH- ACTUATOR= BAKER �� MISC PARTS FROM STA#6(3/24/06)"' OKE.ELEV= 68.1' BF.BEV= 37.2' 2197' H9-518. ES CHu�lfER KOP= 1800' Max Angle= 98°@ 12809' —"COM)UCTO H ? 2209' 4-112'HES WOSSSVN,D=3.813' 1 Datum MD= 9762' —#. Datum TVD= 8800 SS D= ® GAS LIFT MANDFRB_S ST MD TVD DEV TYPE VLV LATCH FORT DATE 9-5/8'CSG,40#,L-80,D=8.835" --1 3121' k 7 3028 2977 18 KBG-2LS DOME NT ► 16 04/14/14 6 5308 5144 19 KBG-2LS DONE NT ' 16 04/14/14 Minimum D = 2.46" c 8498' 5 6508 6279 18 KBG-2LS DM' NT ' 0 04/30/07 46 FLO-GUARD PATCH 4 7205 6941 18 KBG-2LS DOME NT ' 16 04/14/14 45 BOT FLO-GUARD PATCH, -I 8498'-8535' •• 3 8063 7756 20 KBG-2LS SO NT ' 24 04/14/14 D=2.45" (04/10/14) �' �•�� 2 8507 8172 21 KBG-2LS "DMY NT , 0 03/13/14 •,•• r►,••• 1 8952 8518 56 KBG-2LS 'JMY NT 0 01/23/09 TOP OF IA CEMENT(01/23/09)H 8817' !-•jr ;r•-• 'STA#1-DMY w/EXTENDED F KG(BEHIND CM T SHEATH) ••••4A 0►•••• CEMENT SFIEATH,D=3.70' 01/23/09 ••A ►►•• "STA#2-DMY w/DCTHNDED FKG(BEHIND PATCH) ( ) H 8885'4990' ••i• •'►••• ••••� ►�� 9021' H4-1/2'HES X NP,D=3.813" ► • •••• ►•••• •••• ►•••• ��• 9032' _I7"x 4-1/2"BKR S-3 PKR,D=3.875" ' 9055' -14-1/2"HES X NP,D=3.813" I I--1 9077' -14-1/2"FES X NP,D=3.813" 4-1/7 TBG,12.6#,L-80,.0152 bpf,D=3.958' - 9088' I-- / \— J 9089' -14-1/2"WLEG,D=3.958' FISH-BP ELEMENTS (01/14/09) -1 ? 9086' H E-MD TT LOGGED 09/15/99 7'CSG MLLOUT VVIPDOW(S-43 L1) 9749'-9761 RA PP TAG 9578' • FISH- 2 RLR STEM ROLLERS(09/26/09) -1 ? yl H he 9784' BKR SETTING SLV,D=5.250' im- 7"X4-1/2"BKRMLPKR,0=3.875" -{ 9774' a --------------- liii I 4-12"FEES X NP,D=3.813' -1 9792' ��, S-43 L1 IS AN OH SLID LNR w/OUT LTP/HGR WELL NOT WI ACCESSIBLE 4-1l2"HES XN NP,D=3.725" -f 9799' h----;ll 4-12"SLID LNR12.6#,L-80, 13945' 4-12"VVLEG,D=3.958' -1 9808' / .0152bpf,D=3.958' ■ J RA PP TAG - I 9824' r 10059' H 7'TIEBACK SLV,D=5.374' TOP OF 4-12'LNR H 10059' �� 10065' -i 7"X 4-12"TNN S-6 PKR,D=3.868' 7'CSG,26#,L-80,.0383 bpf,D=6.276' -{ 10196' lia I 10070' -{7'X 4-1/2'TNN DTH-S HGR,D=3.925" PERFORATION SUMMARY 12872' H4-1/2"ES CEPANTER FRF LOG:PDS JEVVELRY LOG OF 09/15/99I - 12884' -1 CTC EXT CSG PKR, ANGLE AT TOP PERF:68'@ 9807' • it D=3.885' Note:Refer to Production DB for historical pert data ---- __ SIZE SPF NTERVAL Opn/Sgz DATE -___C SEE P3 2 FOR PERFORATION DATA -- I I I I 4-12"LAR,12.6#,L-80,.0152 bpf,D=3.958" -1 13807' DATE REV BY COtAU1TS DATE REV BY COMuUNITS PRUDHOE BAY UNIT 06/22/97 ORIGINAL COMPLETION 04/11/14 FYPJC SET PATCH(04/10/14) WELL: S-43/L1 04/27/11 A WPJC GLV GO(04/24/11) 04/15/14 PJC MIN D CORRECTION PBRMT ND: 1970520/1970530 08/16/11 MOM PJC GLV CO-SET WRP(8/15-16/11) 04/17/14 WCP/JMD GLV GO(04/14/14) AR No: 50-029-22754-00(60) 11/28/11 MSS/JMD GLV C/O(11/19/11) SFC 35,T12N,T12E, 1068'FTI.&777'FWL 12/15/11 JLJ/JMD PULL VVRP(11/17/11) 12/15/11 PJC WELL NAPE CORRECTION BP Exploration(Alaska) S-43 L1 I -.., .. ••• ..• o•; ►..,. ►.•.;. i. •.• ..• .•. ••.; ..,. .. .. ..• .. _z ■ PERFO OG:PDi , IONSUMNN09 _____—___ REF LOG:PDS JEWELRY ON 09/15/99 —————_ 11:11/ ANGLE AT TOP PERF: 68'@ 9807' S 1110=-41 ———— Note:Refer to Production DB for historical perf data S-43 L1 IS AN OH SIT'D LNR w/OUT LTP I HGR SQE SPF NITBI1/AL Opn/Sgz SHOT 1 SOZ WELL NOT WL ACCESSIBLE S-43 LI 4-12"I SLID 1 9807-13912 I 0 106/22/971 S-43 2" 4 10600-10620 0 05/17/02 ■ 2" 4 10645-10670 0 05/17/02 2" 4 10710-10726 0 05/17/02 T 4 11840-11890 0 05/17/02 ►=R 2" 4 11915-11940 0 05/17/02 2" 4 12010-12085 0 05/17/02 A 2" 4 12100-12250 0 09/16/99 T 4 12310-12490 0 09/16/99 4-12" SLID 12913-13805 0 06/22/97 DATE REV BY COP U'ITS DATE REV BY COMvUJTS PIRDHOEBAY UNIT 06/22/97 ORIGINAL COMPLETION 04/11/14 RRLY PJC SET PATCH(04/10/14) WELL: S-43/L1 0427/11 AWPJC GLV C/O(04/24/11) 04/15/14 PJC MND CORRECTION FERMI No: 1970520/1970530 08/16/11 WM'PJC GLV C/O-SET WRP(8/15-16/11) 04/17/14 WKFRJMD GLV C/0(04/14/14) API No: 50-029-22754-00(60) 11/28/11 MSS/JMD GLV C/O(11/19/11) SEC 35,T12N,T12E,1068'FNL&777'PAL 12/15/11 JLJ/JMD PULL WRP(11/17/11) 12/15/11 PJC WELL NAME CORRECTION BP Exploration(Alaska) • • ei3u s--a 3 PIZ I g 170Sz0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] �� c6 /eh Sent: Saturday, August 04, 2012 4:16 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Black, Brittany; AK, OPS Well Pad SW Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Producer S -43 (PTD #1970520) Tubing Integrity Confirmed All, Producer S -43 (PTD # 1970520) passed a TIFL performed on 08/03/2012 after bringing the well online to flow. The passing test confirms the presence of two competent barriers in the well. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator SEWED MAY 0 7 2D13 Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator (cr�BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, July 31, 2012 8:13 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; Cismoski, Doug A; Daniel, Rya • AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 0. ; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW; Black, Brittany Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NO; HERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer S -43 (PTD #1970520) Eval : e for TxIA Communication All, Producer S -43 (PTD # 1970520) is being reclassified . Under Evaluation to evaluate for TxIA communication after having sustained casing pressure on the IA d . ring pro- ration. The well may be placed online while work is conducted to attempt to restore integrity. T plan forward is to TIFL with a warm well, then evaluate for gas lift valve change out, pending the results •f the TIFL. Please call if you have questions or conce ns. 1 ( 8705 " Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, July 31, 2012 8:13 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW; Black, Brittany Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer S -43 (PTD #1970520) Evaluate for TxIA Communication All, Producer S -43 (PTD # 1970520) is being reclassified as Under Evaluation to evaluate for TxIA communication after having sustained casing pressure on the IA during pro- ration. The well may be placed online while work is conducted to attempt to restore integrity. The plan forward is to TIFL with a warm well, then evaluate for gas lift valve change out, pending the results of the TIFL. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) SCANNED MAY 0 2 2013 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIlntegrityCoordinator (a7BP.com From: Walker, Greg (D &C) Sent: Tuesday, June 26, 2012 6:49 AM To: 'Regg, James B (D0A)'; 'Schwartz, Guy L (DOA)'; Cismoski, Doug A; Daniel, Ryan • K, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; A OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OS , AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW; Black, Brittany Cc: AK, D &C Well Integrity Coordinator; AK, D &C Well Integrity Coordinator AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer Subject: Not Operable: S -43 (PTD #1970520) All, Producer (S -43 PTD #1970520) was found to have sustained 'asing pressure on the IA during the shutdown for turnaround activity. The wellhead pressures were tubing /I •. sA equal to SSV/2170/90 on 06/25/2012. The immediate action is to perform a TIFL on the well to evaluate for IA • essurization. If the well fails the TIFL, a follow up email will be sent to the AOGCC with a plan forward. The well is reclassified as Not Operable until start p operations commence and are stable. After start-up, the well will be reclassified as Under Evaluation with POP para' eters to prevent any over - pressure incidents. 1 76 i Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] 6/51. Sent: Tuesday, June 05, 2012 11:19 AM / To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW; Black, Brittany Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J; King, Whitney Subject: OPERABLE: Producer S -43 (PTD #1970520) Tubing Integrity Restored All, Producer S -43 (PTD #1970520) passed a TIFL on 6/4/2012 after changing out the orifice gas lift valve in the well. The passing test confirms the presence of two competent barriers in the wellbore. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWellIntegrityCoordinator (BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, May 29, 2012 2:35 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, •'5 GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; , RES GPB West Wells Opt Engr; AK, OPS Well Pad SW; Black, Brittany Cc: Walker, Greg (D &C); Olson, Andrew; AK, D &C DHD Well Integrity Engl. -er; Murphy, Gerald L Subject: UNDER EVALUATION: Producer 5 -43 (PTD #1970520) Sustai d Casing Pressure on IA Above MOASP All, Producer S -43 (PTD #1970520) was found with sustaine• asing pressure on the IA above MOASP. The tubing /IA/OA pressures were equal to 2150/2170/70 psi on 05/26/20 2. A TIFL was performed and failed indicating a lack of two competent barriers in the wellbore. The well is recl -- sified as Under Evaluation and may stay online while diagnostics are performed. The plan forward: 1. Slickline: Change out orifice g lift valve 2. Downhole Diagnostics: TIFL 1 PGa 5-43 Pm 67oszc Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] i7 • ' /�� / �� Sent: Tuesday, May 29, 2012 2:35 PM l To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW; Black, Brittany Cc: Walker, Greg (D &C); Olson, Andrew; AK, D &C DHD Well Integrity Engineer; Murphy, Gerald L Subject: UNDER EVALUATION: Producer S-43 (PTD #1970520) Sustained Casing Pressure on IA Above MOASP Attachments: S- 43.pdf; S -43 TIO Plot 05- 29- 12.doc All, Producer S -43 (PTD #1970520) was found with sustained casing pressure on the IA above MOASP. The tubing /IA/OA pressures were equal to 2150/2170/70 psi on 05/26/2012. A TIFL was performed and failed inaicating a lack of two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may stay online while diagnostics are performed. The plan forward: 1. Slickline: Change out orifice gas lift valve 2. Downhole Diagnostics: TIFL A TIO plot and wellbore schematic are attached for reference: «S- 43.pdf» «S -43 TIO Plot 05- 29- 12.doc ».i 04 _ S C E Sc = Z 70x7 Thank you, 71-x , Mehreen Vazir t,'�ltc;rncrle. ((Talc{ lllsrl;hti) �p r 2751 Well Integrity Coordinator 0K— BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com " JUL 1 al4 PBU S -43 PTD #1970520 5/29/2012 TIO Pressures Plot Well: S-43 4.000 - — • 3.000 - —#— Tbg —IF IA 2.000 - —A— OOA 000A On • 1,000 - i 1 03/03/12 03/10/12 03/17/12 03/24/12 03/31/12 04/07/12 04/14/12 04/21/12 04/28/12 05/05/12 05/12/12 05/19/12 05/26/12 i TREE = 4 CM/ 410 - A - F - AIDOTES: WELL ANGLE> 70 DEG t._i 9820' . ' • WaLHEAD = FMC, S .43 RESTRICTION 2' BELOW STA#1' (113=3.26")"" FISH- ACTUATOR - BAKER MISC PARTS FROM STA #6 (3/24/06)"`" KB. ELEV = - 6.8.1. Ll , BF. ELEV = 07.2' KOP L 1 800' ° Max Angle = 98 @ 12809' 9-5/8" ES civrrR . --1 2197' I - = - I 2209' -14-1/2" HES HXO SSSVN, ID = 3.813" Datwn MO = ' 9762' bii - - eaod SS GAS LIFT MANDRELS e r MO TVD DEV TYPE VLV LATCH FORT DATE 1 9-5/8" CSG, 40#, L-80, ID = 8,835" H 3121' I--A 7 3028 2977 18 KBG-2LS DOME) INT r 16 11/19/11 6 5308 5144 19 KBG-2LS DOME INT ' 16 11/19/11 5 6508 6279 18 KBG-2LS DMY INT ' 0 04/30/07 TEDTD OF CEMENT (01/23/09) - 8817' o, 4 7205 6941 18 KBG-2LS DOME INT r 16 11/19/11 •.7•7 'r*, 3 8063 7756 20 KBG-2LS DMY' INT ' 0 04/02/01 CEMENT SHEATH (01/23/095 885 . . .• ; ■ P ...; 2 8507 8172 21 KBG-2LS SO INT ' 24 11/19/11 Minimum ID = 3 70" @ 8885' *.I ■,4 ; k ■,*, •'• F •-•- 1 8952 8518 56 KM-2LS 'DMY INT ' 0 01/23/09 . ...., • , ..• -•-■ , --•-• • STA #1 - DMY w /EXTENDED PACKING (4'im ND CM T SHEAThl CEMENT SHEATH •• ... •• e 4 9021' - 4-1/2" HES X NIP, ID = 3.813" • • .4 • • 4 v • • • • • • 41 ,•„ -a. .110,11,. ........- I 9032' ___17" x 4-1/2" BKR S-3 PKR, ID = 3.875" I ■...... 110 3 .■ I I 9065 F -" HES X NIP, ID = 3.813" I I 9077' -14-12" HES X NIP, ID = 3.813" I 14-1/2" TBG,12.64t, L-80, .0152 bpf, ID = 3.958" H 9088' . / I 9089' - ' 14 - 1/2" WLEG, ID = 3.958" I FISH: 1BP ELEMENTS (01/14/09) ? I 9086' 1--I ELMO TT LOGGED 09/15/99 RA PIP TAG ' 9878' • 7" CSG MILLOUT WNDOW (S-43 L1) 9749 - 9761' !FISH: 2 RLR STEM ROLLERS (09(26/09) 1- ? . I 9784' - BKR SETTING SLV, ID = 5,250" as.--- \........ 9807' 1---12 OF 4-1/2" SLTD LNR 1 . -.. , Ir x 4 BKR ML PKR, ID = 3.875" '--1 9774' . 110-M_ -- ' .......-- .., 14-1/2" HES X NIP, ID = 3 1 .813" - 9792' 1 I . --- .. ..... "*---. 14-1/2" HES XN NIP, ID = 3 725 - 9799 1 .- -. -, , ... ,_. 14 WLEG, ID = 3.958" H 9808' / ' S-43 L1 IS AN OH SLTD -- , • LNR W70 LTP OR HGR. IRA RP TAG - 9824' I—a WELL NOT WL ACCESSIBLE TOP OF TIW TIEBACK SLV, ID = 5.374" H 10059' ---_ • 1BTM OF 4-1/2" SLTD LNR I 13912' 17" X 4-1/2" TM/ S-6 PKR, ID = 3.868" -1 10065' 17" X 4 TM/ DTH-S HGR, ID = 3.925" 1-1 10070' . . 3 I 4 LNR,12.6N,L ID = 3.958" I 13945' I 1 7" CSG, 26#, L .0383 bpf, ID = 6.276" -1 10196' 1 ----41 1 4-1:11 4 P : PERFORATION SUMMARY 72, , i , 12884' -I CTC EXT CSG PKR, ID = 3,;,: 5" I P5 -of REF LOG: PDS JEWELRY LOG OF 09/15/99 * ..,. 1 12913' HTOP OF 4-1/2" SLTD LNR I --, ANGLE AT TOP PEW: 68 , i 9807' . Note Refer to Production DB for historical perf data / .. .... SIZE SPF INTERVAL Opn/Sqz ., DATE ES CENTTENTER H 12872' 1 .. ... . . SEE PAGE 2 . . . . FOR FERF . BREAKDOWN BTM OF 4-1/2" SLTD LNR • 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" - 13807' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06122197 ORIGINAL COMPLETION WELL: S-43 L1 04/27/11 AH/PJC GLV C/0 (04/24/11) . PERMT No: 1970530 08/16/11 MGM/ PJC GLV C/0- SET VVRP (8/15 - 16/11) AP No: 50-029-22754-60 11/28/11 MSS/JMI) GLV C../0 (11/19/11) . SEC 35, T12N, T12E, 1068' FNL & 777' FWL 12/15/11 JLJ/JMO FULL WRP (11/17/11) 12/15/11 PJC WELL NAME CORRECTION .. BP Exploration (Alaska) e • S -4 3 Ll ... PERFORATION SUMMARY 0 REF LOG: PDS JEWELRY ON 09/15/99 ANGLE AT TOP PERF: 68 . 980T Note. Refer to Production D6 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE S L1 I I 4-1/7 SLTD 9807 - 13912 0 06/22/97 S-43 2" 4 10600 - 10620 0 05/17/02 2" 4 10645 - 10670 0 05/17/02 I I 2" 4 10710 - 10726 0 05/17/02 2" 4 11840 - 11890 0 05/17/02 2" 4 11915 - 11940 0 05/17/02 I I 2" 4 12010 - 12085 0 05/17/02 2" 4 12100 - 12250 0 09/16/99 / \ 7' 4 12310 - 12490 0 09/16/99 4-1/2" SLTD 12913 - 13805 0 1 06/22/97 i • I lk --- .... -.. 110 -...._____. -..., -..... -.. -- .,... ... -.... -... --. ... --. I ... --- .... -..... -.. --. -... ... ._ --- -.. .... -... -- ., -- .... • 2i la...4 g , • I '''''' '"......... ,...,,,,,,.... 0 . . . . . . . . . . . . . .. . .. DATE REV BY . COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNIT 06122/97 ORIGINAL COMPLETION WELL: S-43 L1 04/27/11 Ai-/PJC GLV C/0 (04/24/11) PERMIT No: 1970530 08/16/11 MCM/ PJC GLV C SET WRP (8/15 - 16/11) AR No: 50 11/28/11 MSS/JMD GLV C/0 (11/19/11) SEC 35, T12N, T12E, 1068' FNL & 777' FWL 12/15/11 JLJ/J1VID RAL VVRP (11117/11) 12/15/11 PJC WELL NAME CORRECTION BP Exploration (Alaska) OPERABLE: Producer S -43 (PTD #19.520) Tubing Integrity Restored • Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Wednesday, August 17, 2011 6:14 AM t? To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Reynolds, Charles (ALASKA); Longden, Kaity Subject: OPERABLE: Producer S -43 (PTD #1970520) Tubing Integrity Restored All, Producer S -43 (PTD #1970520) passed an MIT -IA on 08/16/2011 after dum y as lift valves were set. The passing test confirms two competent barriers and the well is reclassified as Operable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com Aw ) ; ` 2.(0 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, July 26, 2011 10:53 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OP. GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, D: • ell Integrity Coordinator Cc: Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Townsend, S. Eliot; King, Whitney Subject: UNDER EVALUATION: S -43 (PTD #1970520) Producers with sustained casing press e on IA during proration - Failed TIFL All, Producer S -43 (PTD # 1970520) was found to have sust.' ed casing pressure on the IA during shutdown activities. The WHP's were Tubing /IA /OA were equal . 2160/2080/70 on 0724/11 and the well failed a TIFL. This well has been reclassified as Under Ev. ation so that the well can be brought online to warm the well for further diagnostic work outlined belo 1. Operations: Bring well online Under , aluation 2. DHD: Re -TIFL 3. Slickline: Set Dummy GLV's, T -IA (dependent upon TIFL results) A TIO Plot and wellbore s' ematic have been included for reference. « File: S -43 TI O Plo . oc » « File: S-43. pdf » Please call with an • uestions. Thank you, 8/25/2011 UNDER EVALUATION: S -43 (PTD 4 70520) Producers with sustained casi,ressure on IA ... Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] r �� , / / �� Sent: Tuesday, July 26, 2011 10:53 AM I` 1 ll To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, D &C Well Integrity Coordinator Cc: Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Townsend, S. Eliot; King, Whitney Subject: UNDER EVALUATION: S -43 (PTD #1970520) Producers with sustained casing pressure on IA during proration - Failed TIFL Attachments: S -43 TIO Plot.doc; S- 43.pdf All, Producer S -43 (PTD # 1970520) was found to have sustained casing pressure on the IA during shutdown activities. The WHP's were Tubing /IA/OA were equal to 2160/2080/70 on 0724/11 and the well failed a TIFL. This well has been reclassified as Under Evaluation so that the well can be brought online to warm the well for further diagnostic work outlined below. 1. Operations: Bring well online Under Evaluation 2. DHD: Re -TIFL 5C Zy 7; 61.f `� 3. Slickline: Set Dummy GLV's, MIT -IA (dependent upon TIFL results) IIUh'cc e 1 pr�� A TIO Plot and wellbore schematic have been included for reference. !`i «S -43 TIO Plot.doc» «S- 43.pdf» Please call with any questions. Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy Office: 659 -5102 Pager: 659 -5100 x 1154 JUL 299 201 From: AK, D &C Well Integrity Coordinator 9 Sent: Saturday, July 23, 2011 9:03 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA); 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 OSS; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 OSS; AK, RES GPB West Wells Opt Engr; AK, D &C Well Integrity Coordinator Cc: Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Townsend, S. Eliot Subject: Producers with sustained casing pressure on IA during proration All, The following producers were reported to have sustained casing pressure on the IA during the proration and shutdown activity July 21 -23. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 7/28/2011 UNDER EVALUATION: S -43 (PTD 70520) Producers with sustained casi,ressure on IA ... Page 2 of 2 S-43 (PTD #1970520) W -21 (PTD #201110) A -37 (PTD #1930070) All the wells listed above will be re- classified as Not Operable until start -up operations are complete and stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy Office: 659 -5102 Pager: 659 -5100 x 1154 7/28/2011 PBU S-43 PTD 1970520 7/26/2011 TIO Pressures Plot Wel: S-43 4,000 -.... ...... .......,.... 3,000 - • 1 -9- Tbg 1 - IA --s- OA 2,000 - ‘ riL, . ..„........fl, 00A ". \ T"'"" 7/."'"nrAt imr4r..."""'.. rill •■.. On , 1 ' 1,000 - i II -4frit7-76447-r. .r ' “......041 allIMI ' . ', ...../ , . • ' O9/ 03 . 03103/10 10404/10 11, 12, 35/10 01435/11 02/05/11 3311001 1 04/00/11 05,'69/11 05/09111 07/10/11 • TREE= 4- 1/16" CIW WELLHEAD = FMC . S-431..1 SAFETY : WELL ANGLE> 70 DEG @ 9820' . ACTUATOR = — BAKER RESTRIC 2' BELOW STA #1' (ID= 3.25 ") * ** FISH - KB. ELEV = 68.1' MISC PARTS FROM STA #6 (3/24!06) * ** BF, ELEV = 37.2' KOP = 1800' Max Angle = 98 @ 12809' 19 -5/8" ES CMTR H 2197' 1 L Q 2209' H 4 -1/2" HES HXO SSSVN, ID = 3.813" Datum MD = 9762' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT! DATE 19 -5/8" CSG, 40 #, L -80, ID = 8.835" I—I 3121' 1-'4 7 3028 2977 18 KBG -2LS DOME INT ® 16 08/22/09 III 6 5308 5144 19 KBG -2LS DOME NT r 16 08/22/09 Minimum ID = 3.70" 8885' 5 6508 6279 18 KBG -2LS DMY INT r 0 04/30/07 4 7205 6941 18 KBG -2LS DOME INT ' 16 08/22/09 CEMENT SHEATH ►�� ► � � � 4 3 8063 7756 20 KBG -2LS DMY INT r 0 04/02/01 A t ■ •4 2 8507 8172 21 KBG -2LS SO NT ' 22 08/22/09 TOP OF IA CEMENT (01 /23/09) I--{ 8817' I � . 4 . ♦•1 ► • N 1 8952 8518 56 KBG -2LS *DMY NT 0 10/10/07 CEMENT SHEATH (01/23/09) H 8885' -8990' I I # 1,1 v 4 *EXTENDED PACKING; BEHIND CEMENT SHEATH 1 444 9021' —14-1/2" HES X NIP, ID = 3.813" I OM' ►��1 9032' 47" x 4 -1/2" BKR S -3 PKR, ID = 3,875" I I 9055' I- I4 -1/2" HES X NIP, ID = 3.813" I 9077' I -112" HES X NIP, ID = 3.813" I 4 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" I—J 9088' 9089' 14-1/2" WLEG, ID = 3.958" I FISH: IBP ELEMENTS (01/14/09) I ? [ 9086' I-I ELMD TT LOGGED 09/15/99 I 7" CSG MILLOUT WINDOW (S -43 1.1) 9749' - 9761' RA PIP TAG H 9578' I FISH: 2 RLR STEM ROLLERS (09/26/09) H ? / { J7$4' I-) BKR SEI I ING SLV, ID = 5.250" I mit-.....‘,....'�. I 9807' 1-1 TOP OF 4-1/2" SLID LNR I 17" X 4 -1/2" BKR ML PKR, ID = 3.875" I 9774' 411.„.....„..s. y . ` - 14-1/2" HES X NIP, ID = 3.813" H 9792' I ` ` 14-1/2" HES XN NIP, ID = 3.725" I-I 9799' * S-43 L1 IS AN OH SLID . `',..∎ I4 -1/2" WLEG, ID = 3.958" H 9808' LNR W/O LNR TOP PKR OR --. -.. , * IRA PIP TAG H 9824' HGR. WELL NOT WL ACCESSIBLE I TOP OF TM/ TIEBACK SLV, ID = 5.374" H 10059' I I BTM OF 4 -1/2" SLTD LNR I 13912' 17" X 4-1/2" TM/ S -6 PKR, ID = 3.868" I 10065' �� ICA 17" X 4 -1/2" TIW DTH -S HGR, ID = 3.925" H 10070' I1 I I4- 112 "SLTD LNR,12.6 #,L- 80 ,.0152bpf, ID = 3.958" I 13945' 17" CSG, 26 #, L -80, .0383 bpf, ID = 6.276" H 10196' ` tia=�� '7Z-5 'Psi �� 12884' --ICTC EXT CSG PKR, ID = 3.885" I PERFORATION SUMMARY �� ° ° I 12913' I-) TOP OF 4 -112" SLTD LNR REF LOG: PD5 JEWELRY LOG OF 09/15/99 ANGLE AT TOP PERF: 68 @ 9807' CG ° ° ° ° Note: Refer to Production DB for historical perf data E5 CEMTENTER 128' ° ° ° ° ° ° SIZE SPF INTERVAL Opn /Sqz DATE I (� I ° ° ° ° SEEPAGE2 °� ° ° FOR PERF ° � 41 BREAKDOWN !BTM OF 4-1/2" SLTD LNR I--{ 13805' I ° 4 -1/2" SLTD LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 13807' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/22/97 ORIGINAL COMPLETION 10/04/09 ? /SV FISH WELL: S -43 L1 10/17/08 RRD /PJC SET IBP (10/11/08) PERMIT No: 1970530 01/15/09 BSE/SV PULL IBP/ FISH (01/14/09) API No: 50- 029 - 22754 -60 02/05/09 RLM/SV IA CMT SQZ/SHEATH (01/23/09) SEC 35, T12N, T12E, 1068' FNL & 777' FWL 03/04/09 KJB /SV GLV C/O (02/21/09) 08/22/09 RPC /PJC GLV C/O BP Exploration (Alaska) • S-431.1 PERFS Ell PERFORATION SUMMARY REF LOG: PDS JEWELRY ON 09/15/99 ANGLE AT TOP PERF: 68 @ 980T Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE I I S-43 L1 4 -1/2" SLTD 9807 - 13912 0 06/22/97 S-43 I I 2" 4 10600 - 10620 0 05/17/02 2" 4 10645 - 10670 0 05/17/02 2" 4 10710 - 10726 0 05/17/02 2" 4 11840 - 11890 0 05/17/02 2" 4 11915 - 11940 0 05/17/02 / \ 2" 4 12010 - 12085 0 05/17/02 2" 4 12100 - 12250 0 09/16/99 2" 4 12310 - 12490 0 09/16/99 4 -1/2" SLID 12913 - 13805 0 06/22/97 411 11* `- r 1 v ` t I ■ 1 ` ~ 1 / \ \ --. -- i:: • ( A 1 ti 1 .... .. „.., 1 ` 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/22/97 ORIGINAL COMPLETION 10/04/09 — ? /SV — FISH WELL: S -43 L1 10/17/08 RRD /PJC SET IBP (10/11/08) PERMIT No: 1970530 01/15/09 BSEJSV i, PULL IBP/ FISH (01/14/09) API No: 50- 029 - 22754 -60 02/05/09 RLM/SV IA CMT SQZ /SHEATH (01/23/09) SEC 35, T12N, T12E, 1068' FNL & 777' FWL 03/04/09 KJB /SV GLV C/O (02/21/09) ,,,, 08/22/09 RPC /PJC GLV C/O BP Exploration (Alaska) Producers with sustained casing presson IA during proration • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Q�� ce 7_ .. _ Sent: Saturday, July 23, 2011 9:03 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 OSS; AK, RES GPB West Wells Opt Engr; AK, D &C Well Integrity Coordinator Cc: Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Townsend, S. Eliot Subject: Producers with sustained casing pressure on IA during proration All, The following producers were reported to have sustained casing pressure on the IA during the proration and shutdown activity July 21 -23. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. S-43 (PTD #1970520) f a ` (PTD #201110) A -37 (PTD #1930070) All the wells listed above will be re- classified as Not Operable until start -up operations are complete and stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy Office: 659 -5102 Pager: 659 -5100 x 1154 II 7/28/2011 OPERABLE: Producer S -43 (PTD41970520) Tubing Integriy Confirmed • Page Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] I�� Io Sent: Wednesday, November 24, 2010 9:41 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers Cc: Sayed, Mohamed; Janowski, Carrie; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer S -43 (PTD# 1970520) Tubing Integriy Confirmed All, Producer S -43 (PTD #1970520) has been evaluated for TxIA communicatio after sustained IA casing pressure was reported by the operator. A TIF passed on 11/23/10 confirming tubing integrity. The well has been reclassified as Operable and may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 d ;g� �W NOV a I.) 20I It Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, November 22, 2010 4:53 AM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, 0 GC2 Field O &M TL Cc: Sayed, Mohamed; King, Whitney Subject: UNDER EVALUATION: Producer S-43 (PTD# 1970520) POP to eval tubing integrity All, Producer S -43 (PTD #1970520) has been reclassified as Und evaluation so that it maybe placed on production. Once the IA has unloaded to the screened orifi a TIFL will be performed to evaluate TAA communication. Please call with any questions or conce s. The plan forward is as follows: 1. DHD: TIFL 2. Slickline: Change out OGLV 3. D: Re -TIFL Thank you, Torin Roschinger (alt. Jer Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x237 Cell (406) 570 -96 Pager (907) 65 -5100 Ext. 1154 11/24/2010 UNDER EVALUATION: Producer S -43 (PTD# 1970520) POP to eval tubingegrity Page 1 of 2 Regg, James B (DOA) • - From: AK, D &C Well Integrity Coordinator [ AKDCWelilntegrityCoordinator @bp.com] at��z —I td Sent: Monday, November 22, 2010 4:53 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Field O &M TL Cc: Sayed, Mohamed; King, Whitney integrit Subject: UNDER EVALUATION: Producer S-43 (PTD# 1970520) POP to eval g y All, Producer S-43 (PTD #1970520) has been reclassified as Und evaluatio so that it may be placed on production. Once the IA has unloaded to the screened orifice a TIFL will be performed to evaluate TAA communication. Please call with any questions or concerns. The plan forward is as follows: 1. DHD: TIFL / 2. Slickline: Change out OGLV 3. D: Re -TIFL Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 � Cell (406) 570 -9630 `,1 , 1 0 I Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, September 26, 2010 10:09 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Field O &M TL Cc: AK, D &C Well Integrity Coordinator; Sayed, Mohamed; Janowski, Carrie Subject: NOT OPERABLE: Producer S -43 (PTD# 1970520) Secured with Kill Weight Fluid All, Producer S -43 (PTD #1970520) has been secured with kill weight. The well has been reclassified as Not Operable. Pending completion of rig work on an adjacent well, diagnostics will be performed in an attempt to mitigate the sustained casing identified on 9/4/2010. The plan forward is as follows: 1. WIC: Once the rig has moved locations, reclassify the well as under evaluation 2. DHD; TIFL Please call if you have questions or concerns. 11/22/2010 UNDER EVALUATION: Producer S -43 (PTD# 1970520) POP to eval tubingegrity Page 2 of 2 Thank you, - Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, September 08, 2010 5:36 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers Cc: AK, D &C Well Integrity Coordinator; Sayed, Mohamed; Janowski, Carrie Subject: UNDER EVALUATION: Producer S-43 (PTD# 1970520) Sustained casing pressure on the IA All, Producer S -43 (PTD #1970520) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 249/2200/0 psi on 09/04/2010. The well has been reclassified as Under Evaluation and placed under a 28 day clock.. The plan forward is as follows: 1. DHD: TIFL 2. Slickline: Set DGLVs pending TIFL results 3. Pumping: MIT -IA to 3000 psi, LLR if fails A TIO plot and wellbore schematic have been included for your reference. << File: S-43 TIO Plot 09- 08- 10.doc >> << File: S- 43.pdf >> Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 11/22/2010 UNDER EVALUATION: Producer S~(PTD# 1970520) Sustained casing pre~ure on the IA Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Wednesday, September 08, 2010 5:36 PM '\~~j ~~~~/° To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS Prod Controllers Cc: AK, D&C Well Integrity Coordinator; Sayed, Mohamed; Janowski, Carrie Subject: UNDER EVALUATION: Producer S-43 (PTD# 1970520) Sustained casing pressure on the IA Attachments: S-43 TIO Plot 09-08-10.doc; S-43.pdf All, Producer S-43 (PTD #1970520) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 249/2200/0 psi on 09/04/2010. The well has been reclassified as Under Evaluation and placed under a 28 day clock.. The plan forward is as follows: 1. DHD: TIFL 2. Slickline: Set DGLVs pending TIFL results 3. Pumping: MIT-IA to 3000 psi, LLR if fails A TIO plot and wellbore schematic have been included for your reference. «S-43 TIO Plot 09-08-10.doc» «S-43.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ,~,.~~ _ ~1 za~~s SC. {~ = 22~~,, tt F/} ~ ~ l- ~ { ~. L, f ~~~ t t,~. ` ~l %16~Ct ~lC pe,- C~ Q~Z 9/9/2010 PBU 5-43 PTD 1970520 9/8/2010 TIO Pressures Plot 4,000 __ _ Well: 5-43 • 3,000 2,OD0 1,000 -~ Tbg -f- IA -~ OA OOA -+- OOOA On • 06!12!10 06/13/10 06/26/10 07JD3J10 07/10!10 07/17!10 07!24!10 07!31!10 08!07!10 08!14!10 08!21/10 08128!10 09!04!10 • ~ ®~ ~ ~ ~ SAFETY :WELL ANGLE> 70 DEG @ 9$20' . * RESTRIC 2' BELOW STA#1' (ID=3.25")*** FISH- MISC PARTS FROM STA #6 {3!24!06)*** 9-518" ES CMTR 2197' 22pg' ~-i4-112" HES HXO SSSVN, ID = 3.813" GAS LIFT MANDRELS 9-5/8" CSG, 40#, L-80, ID = $.835" {-j 3121' Minimum ID = 3.70" @ 8885' CEMENT SHEATH TOP OF IA CEMENT (01/23/09) $817' (CEMENT SHEATH (01123!09} ~ $$$5'-$990' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3028 2977 18 KBG-2LS DOME INT 16 08/22/09 6 5308 5144 19 KBG-2LS DOME INT 16 08/22/09 5 6508 6279 18 KBG-2LS DMY {NT 0 04/30/07 4 7205 6941 18 KBG-2LS DOME INT 16 08!22/09 3 8063 7756 20 KBG-2LS DMY INT 0 04(02!01 2 8507 8172 21 KBG-2L5 SO INT 22 08/22!09 1 8952 8518 56 KBG-2LS *DMY INT 0 10/10/07 'EXTF~IDED NAC;KINCi; i3tHINU L:GVIkN I JY1CA I h 9021' -{4-112" HES X NIP, ID = 3.813" 9032' 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 9055' 4-1/2" HES X NIP, ID = 3.813" g077` I-i 4-1 t2" HES X NIP, ID = 3.813" 4-1(2" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 9088, FISH: IBP ELEMENTS (01/14109) - RA PIP TAG 9578' FISH: 2 RLR STEM ROLLERS (09/26109) -~? 7" X 4-1/2" BKR ML PKR, ID = 3.875" I 9774' 4-112" HES X NIP, ID = 3.813" 9792' 4-112" HES XN NIP, ID = 3.725" 9799' 4-1/2" WLEG, ID = 3.958" 9$0$' RA PIP TAG 9824' TOP OF TMJ TIEBACK SLV, ID = 5.374" ~-L 10059, 7" X 4-1/2" TIW S-6 PKR, ID = 3.868" 10065' 7" X 4-1/2" TMj DTH-S HGR, ID = 3.925" 10070' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I-I 10196' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG OF 09!15/99 A NGLE AT TOP PERF: 68 @ 9807' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN g0$g'~--f 4-1/2" WLEG, ID = 3.958" g0$6' ELMD TT LOGGED 09/15/99 7" CSG MILLOUT WINDOW {S-43 L1} 9749' - 9761' / g7$4' BKR. SETTING SLV, ID = 5.250" ~~ g$07' TOP OF 4-1/2" SLID LNR O ` 1 "~. 1 ..,` ` \`d `~~ '~.,. ~~ ~`\` i! 1` S-43 L1 IS AN OH SLID ~ " "' ,. ,,, 1 LNR W/O LNR TOP PKR OR ~ " . ,,, HGR. WELL NOT WL ACCESSIBLE BTM OF 4-112" SLID LNR 13912' 14-1/2"SLTD LNR,12.6#,L-80,.0152bpf, ID = 3.958'" I 12884'- j CTC EXT CSG PKR, ID = 3.885" ,~ \ 1291 TOP OF 4-112" SLTD LNR ~ ~ _ ` ~ ti ES CEMTENTER 12872' .. ~. ~~ BTM OF 4-172" SLTD LNR --L 13845' ~-=' 4-1/2" SLID LNR, 12.6#, L-80, .0152 bpf, ID = 3,958" 13807' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/22197 ORIGINAL COMPLETION 10104109 ?ISV FISH 10/17/08 RRD/PJC SET IBP (10111!08} 01/15!09 BSF15V PULL IBP/FISH (01114109} 02/05/09 RLMlSV IA CMT SOZlSHEATH (01/23/09} 03!04/09 KJB/SV GLV C/O (02!21109} 08/22/09 RPC/PJC GLV CIO PRUDHOE BAY UNIT WELL: S-43 L1 PERM(T No: 1970530 API No: 50-029-22754-60 SEC 35, T12N, T12E, 1068' FNL & 777' FWL BP Exploration (Alaska) # S-43 L'1 ~ PERFORATION SUMMARY REF LOG: PDS JEWELRY ON 09/15!99 ANGLE AT TOP PERF: 68 @ 9807' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE S-43 L1 4-1/2" SLTD 9807 - 13912 d 06/22(97 S-43 2" 4 10600 - 10620 O 05! 17102 2" 4 10645 - 10670 O 05/17/02 2" 4 10710 - 10726 O 05/17!02 2" 4 11840 - 11890 O 05/17!02 2" 4 11915 - 11940 O 05/17/02 2" 4 12010 - 12085 O 05117!02 2" 4 12100 - 12250 O 09116!99 2" 4 12310 - 12490 O 09/16/99 4112" SLTD 12913 - 13805 O 06/22/97 -,. ., o` "~ •. ° .. ~~ '~ .. ~ ` i ~ ` 1 1 \ '` ~ 0 ~ 0 ~ ~ ~ ~ ~ ~ DATE REV BY COMMENTS DATE REV BY COMMENTS O6t22/97 ORIGINAL COMPLETION 10/04/09 ?/SV FISH 10117/08 RRD/PJC SEfIBP(10(11/08) 01/15/09 BSE/SV PULL IBP/FISH (01/14/09) 02/05/09 RLNUSV IA CMT SOZ/SHEATH {01/23/09) 03/04109 KJB/SV GLV CIO {02121/09) 08!22/09 RPC/PJC GLV CIO PRUDHOE BAY UNIT WELL: 5-43 L1 PERMIT No: 1970530 API No: 50-029-22754-60 SEC 35, T12N, T12E, 1068' FNL ~ 777' FWL BP Exploration (Alaska) PERFs I OM8 /09 MS SdI m6erpr N0.5410 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Mahnken A7TN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job k Log Description Date BL Color CD MPC -05A 11661124 MEMORY PROD PROFILE 01125/07 1 L4 -03 AY1 M-00032 PRODUCTION PROFILE 09/09/09 1 1.5 -05 AP30 -00061 PRODUCTION PROFILE 09/15/09 1 03 -24A AZCM -00042 LDL 09/14/09 1 07 -32B BOCV -00027 JEWELRY LOWOK W/PRESS/TEMP /15/09 1 W -214 AYS4 -00095 INJECTION PROFILE 09/12/09 1 04 -26 B5JN-00014 PRODUCTION PROFILE / 09/25/09 1 07 -21 AYS4 -00098 PRODUCTION PROFILE 09/17/09 1 W -04 88K5 -00003 PRODUCTION PROFI 1 09/24/09 1 P2 -53 AP30 -00060 PRODUCTION PROFILE 09/13/09 1 5-43 A6VLB -00037 PRODUCTION PROFILE 091`25109 1 12 -23 AWLB -00035 INJECTION PROFILE 09/19/09 1 05 -38 AYTO -00029 LDL 09118109 1 W -29 AWJI -00050 MEM IN— 0 09/20/09 1 W -30 AY1M -00034 PLUGBACK W/X -FLOW CHECK _ >� 09112109 1 3- 37/L -35 93SO -00024 PRODUCTION PROFILE V - -f 4 09/16/09 1 NK -09 AP30 -00057 USIT 09107/09 1 W -07A AWJI-00047 M CEMENT EVAL ATION 09107/09 1 11 -10 AYTU -00054 US17 08128109 1 02 -06B ANHY -00111 USIT 09/21/09 1 G -18A AWJM048 M£M CEMENT BOND LOG C 09/17/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd, Anchorage. AK 99503 -2838 L/ �/ ~~~~~~~ STATE OF ALASKA ~ ~~ ; ~ ,~,t~~ ~~~~q ALA OIL AND GAS CONSERVATION C~~rC7N REPORT OF SUNDRY V1~~~~~t~I,~S5i0ft ~~t~o9 1. Operations Abandon ~ Repair Well ~, Plug Perforations ~ ~~ Other ~ REPAIR GLM Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory ~~ 197-0520 - 3. Address: P.O. Box 196612 StratlgraphlC I~" Service (~ 6. API Number: Anchorage, AK 99519-6612 50-029-22754-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 68.1 KB ~ PBU S-43- 8. Property Designation: 10. Field/Pool(s): ADLO-028257 - Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 13888.8 - feet Plugs (measured) None true vertical 9017.56 ~ feet Junk (measured) None Effective Depth measured 13807 feet true vertical 9012 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 131 Surface - 131 Surface 3090 9-5/8" 40# L-80 Surface - 3121 Surface - 3066 5750 2370 Intermediate 10165 7" 26# L-80 Surface - 10196 Surface - 8991 7240 5410 Liner 2854 4-1/2" 12.6# L-80 10059 - 12913 8978 - 8986 8430 7500 Slotted Liner 892 4-1/2" 12.6# L-80 12913 - 13085 8986 - 9012 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9088' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1 /2" BKR S-3 PKR 9032' 7"X4-1/2" BKR MIL PKR 9774' 7"X4-1/2" TIW S-6 PKR 10065' CTC EXT PKR 12884' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ;~~ APR ~d ~-~ 2009 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: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~`- Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' - Gas WAG ~ GINJ WINJ WDSPL 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 Gary Preble Printed Name Gary Pre I Title Data Management Engineer Signature Phone 564-4944 Date 2/23/2009 Form 10-404 R ised 04/2006 ~ ~ ' ~ ~sf'~ ~ ~ ~~~4 Submit Original Only 3-~- S-43 197-052 PERF ATTACHMENT L_ J Sw Name Operation. Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-43 6/22/97 OH 12,913. 13,805. 8,985.61 9,012.38 S-43 9/16/99 APF 12,100. 12,250. 9,017.57 9,012.79 S-43 9/16/99 APF 12,310. 12,490. 9,011.16 9,011.69 S-43 5/15/02 APF 12,010. 12,085. 9,020.21 9,018.06 S-43 5/16/02 APF 11,840. 11,890. 9,025.03 9,022.11 S-43 5/16/02 APF 11,915. 11,940. 9,021.72 9,021.48 S-43 5/17/02 APF 10,600. 10,620. 8,989.98 8,992.08 S-43 5/17/02 APF 10,645. 10,670. 8,994.81 8,997.68 S-43 5/17/02 APF 10,710. 10,726. 9,002.44 9,004.2 S-43 1/22/09 BPS 8,990. 8,992. 8,538.17 8,539.18 S-43 1/23/09 BPP 8,990. 8,992. 8,538.17 8,539.18 S-43 1/23/09 SQZ 8,885. 8,990. 8,477.13 8,538.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • \J 5-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/22/2009 CTU #6 w/ 1.75" OD CT. Objective: cement leaking GLM. "**" interact broadcasting ***" MIRU CTU. MU and RIH with PDS memory GR/CCL logging ~ toolstring and 3.60 OD drift to 9200' w/ no problems. POH, verify good data, -5' correction. MU/RIH with Baker 4-1/2" Composite Bridge Plug. Set composite bridge plug at 8990' (ref: tubing tally). Set 2k Ibs on plug to con irm se . ul to surface. MU 2.5" OD BDJSN and park in lubricator while LRS circulates IA and 1 tubing to crude. Perform CMIT-TxIA to 2500 psi, test passed (see job log for l details). Job continued on WSR 01/23/09. ~ .~ __ 1/22/2009 T/i/0= 800/0/0 Temp= SI Assist CTU #6, Circ TxIA with crude (Restore Tbg E , Integrity) Pumped 3 bbls meth, 450 bbls crude down IA up Tbg taking returns to }flowline. *"" Job continued on 1-23-08 WSR**** ~ 1/23/2009 CTU #6 w/ 1.75" OD CT. Continued from WSR 01/22/09. Objective: cement I leaking GLM. RIH with 2.50" OD BDJSN. Tag composite plug at 8990' ctmd. Circulate balanced 15.8 unislur cement lu into tubin and inner annulus, leavin a roximatel 4 bbls of cement in the IA and 2.5 bbls of cement in the tubing. Pull to surface filling pipe voidage with crude. Flush and FP surface equip. - MU otor and 3.70" 3 blade Junk Mill - WOC for 500 psi compressive strength - flab test after 6 hrs at 1300 psi. RIH w/motor and mill tag TOCat 8885' -Mill soft °cement to 8956' -mill firm cement to 8990' - WHP dropped to 30 psi when thru plug I roppe to 5 psi - push p ug out TT to 9200' -Back ream across milled area 3 times and 1 dry run. Begin P OH. While pulling to surface, find a section of the coil tubing below minimum wall thickness. Freeze protect well to 2500' with 60/40 methanol/water. Freeze protect flowline with 60/40 methanol/water. IStandby for nitrogen unit for reel blowdown. Job continued on WSR 01/24/09. _._ ~ _ ~ _r.~ __ _ __. ____ ___... .__ ______.~ 1/23/2009€*'`* Job continued from 1-22-09 WSR*** Assist CTU #6 (Restore Tbg Integrity) Pumped 18.5 bbls crude down Tbg while coil POOH. Final WHPs=100/0/0. CTU on well at time of LRS departure. 1/24/2009CTU #6 w/ 1'.75" OD CT. Continued from WSR 01/23/09. Slowdown reel with ,nitrogen. Release well to operations. RDMO. Job complete. 1/29/2009ILoad and road to location for MITIA.*"* Job continued on 1-30-09 WSR*** 1/30/2009***Continued from 01-29-09 WSR**'` T/I/0=0/200/0 MIT IA PASSED to 2400 psi (Post Cement Squeeze) Pressured up IA with 3.5 bbls of diesel. IA lost 40 psi in the 1st 15 mins and 10 psi in the 2nd 15 mins for a total loss of 50 psi in 30 min test. Bled IA. Final WHPs=0/100/0. SV=C, MV=O, SSV=OTP, lAV=OTG, s OAV=OTG, A/L=C L_J 2/15/2009"*"****'`WELL SHUT IN ON ARRIVAL"""*""** (post pkr sqz). DRIFTED TO 9209' SLM W/ 3.50" CENT. AND SAMPLE BAILER (BAILER RAN PETREDAT GAUGES FOR 3 STOPS @ 8644',8767', 8910' ELMD (GOOD DATA) SET 4 1/2" S.S. CATCHER @ 8622' SLM. RIH W/ 4-1/2" OK6 TO PULL ST#2 INT-DGLV "*""CONT ON WSR 2/16/09**"" 2/16/2009'`**CONT FROM WSR 2/15/09"*" (post pkr sqz) PULLED INT-DGLV's FROM ST#2 8510'SLM/850TMD, ST#4 7208'SLM/7205'MD. PULLED INT-DGLV's FROM ST#6 5305'SLM/5308'MD, ST#7 3012'SLM/3028'MD. ICURRENTLY ATTEMPTING TO SET INT-LGLV AT ST#7 3012'SLM/3028'MD. I***CONT ON 02/17/09 WSR**" 2/17/2009 ***"CONT FROM WSR 2/16/09"*"" (post pkr sqz) SET INT-LGLV IN STA 7 @ 3012' SLM (PORT 16/64", TRO 1835 LBS) j****WELL LEFT S/I TAG HUNG ON WING, OPERATOR NOTIFIED"**** 2/20/2009 "***''*'`WELL SHUT IN ON ARRIVAL*"**"*** SET INT-LGLV IN STA 6 @ 5303' SLM ~ SET INT-LGLV IN STA 4 @ 7205' SLM ~"''**CONT ON WSR 2/21/09"""' 2/21/2009"**"CONT FROM WSR 2/20/09*"** (post pkr sqz) SET INT-DGLV IN STA 2 @ 8512' SLM (PORT 20/64") PULLED SLIP STOP CATCHER FROM 8622' SLM ~""*"""'WELL LEFT SHUT IN, DSO NOTIFIED OF DEPARTURE*""***** FLUIDS PUMPED BBLS 207 60/40 METH 6.4 15.8 PPG UNISLURRY CEMENT 50 GEOVIS 600 1 % SKCL 455 CRUDE 20.5 DIESEL 430 GALLONS N2 1548.9 Totai 5-43 (PTD #1970520) Internal W~er Cancellation -Not Operable Well Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,~Q.l ~ 11(Z~°~t77 Sent: Wednesday, November 21, 2007 9:07 AM C To: Maunder, Thomas E (DOA); Regg, James B (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Ohms, Danielle H; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Forcade, Kirk C Subject: S-43 (PTD #1970520),knternal Waiver Cancellation -Not Operable Well All, This email is a clarification email. The original email was sent for S-43L1; but was intended to be sent for 5-43 the mother bore. An internal waiver was issued for TxIA communication on well S-43 (PTD #1970520) on 04/20/04. The well no longer meets compliance requirements and therefore the waiver is being cancelled. The well has been reclassified as Not Operable. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Plans are progressing to remove the scale from the well and to patch the tubing to restore the well to production. Please call if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~'~i~ NOV ~ ~ ~0~7 11/26/2007 Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 _ L A TTN: Beth '" c:1 VY. oJ. ylL:?-r¡c,. t..l 08/30/07 NO, 4396 SCANNED SEP 1 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay E d' tt ~ n ICO Job# lo!! Description Date Bl Color CD \ MPC-08 ) N/A RSTIWFl 08/10/07 1 ,.,r,,- '" 11767136 MEM INJ PROFilE U:r:~ Ie;; q - JI) ":J- 08/12/07 1 P2-16 11856185 INJECTION PROFilE UTI' Ie. I~ - l~~ 08/02/07 1 07 -02A 11649983 MEM PROD PROFilE ¡Cic. - ~ 'lr 08/07/07 1 R-13 11856186 INJECTION PROFilE ( j "I:f' I~ f~ - f"I../L./ 08/02/07 1 D-11A 11649982 MEM PROD PROFilE ¡C1K- "7(~ 07/26/07 1 S-42 11686773 lDl I q &. - Î'\~(j 08/02/07 1 S-43 11855804 lDl I C ~ -C:5"::J 08/02/07 1 16-07 11855806 STATIC PRESSURE SURVEY J "Í(~ - .c.o4 08/04/07 1 16-21 11855805 STATIC PRESSURE SURVEY '1i~ -,~I~ 08/04/07 1 1-09A1l-21 11849930 SBHP SURVEY Jq~ - t"J~Q 08/04/07 1 2-68/S-17 11630491 lDl l 'fÓ(- ')O,~ 07/27/07 1 1-2310-15 11846802 STATIC PRESSURE SURVEY U:r:0 Iqq - J::J 'X' 08/11/07 1 Z-46 11057080 CH EDIT PDC GR (USITldDÕ-Jf\1 'It I~ '~ 12/14/05 1 A-09A 11216203 MCNl ,ccsD-I-+Lt'- 1~</fJi...1 06/29/06 1 1 l3-11 11801065 RST i "ðt) ~~ ¡ .... ,A"Z ~:~ 05/31/07 1 1 . . PLEASE ACKNOWLEDGE RECEIP1;..~y ~J~~~q,,~N~ R~~~RNING ONE COpy EACH TO: i,,· " ^ ,', 'I" "Ii a PI" BP Exploration (Alaska) Inc. 1('1t ~"". t' H'~' ¡í 'II t'!!"." Petrotechnical Data Center LR2-1 ,,\ ,.~..\,.j' ,'~". ¡¡Ii ¡¡-"~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: r: [) L.' LJ Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 A""'""".. AK """D. ATTN: Beth Received bYC". ~-_._~. /' ~~:::jgf«J :()H 8: {3tJ::,~ C¡'\f¡;':';, C.:c.HT¡íT~i~sfon ANNULAR INJECTION DATA ENTRY SCREEN Asset ~.QA .......................................... Research Rig Name NaI%~.r.~...I.~F,, ............................. Inj Well Name ~.:.~.;3 ............................................ Permit Start ......... .5.:.7.:.9.7. ......... Permit End ......... ~.-.7.. :.9. .8. ......... Sur Csg Dep 3.1.~{.1.'. ............... Cumulative Data [ Rig COmpletion Formation Intermittant Final Well Total MUd/Ctg Wash Fluids Fluids Freeze Freeze ......... ~.~.;~ .................. ~,,.6.:3.6. ................... 1.,Z.1..6. ................... 1.,~;.;I..1 ................................................................................. {~.0. ............ Dai y Data R-=wash '~ ~ Trial' Rate ~. ' · . . ... ~B BB/-~B/~T ...... 384 .................. 384 3 Boo-goo ........................................................................ ~-43 ................... 05/25/97 '~]"~ .................. ~'~ ............. 234 .................. ~ ............. ~'50 ........................................................ S-43 05/27/97 203 204 407 3 850-900 ,~.:~ ..................................... ~]~]~.~ ..................... ~.B.,~ .......................................... ~..~ ........................................................................................................................................................................................................................................ ~,~,~ .................................. 3 ~00 .......................................................................................................................................................................................... S-43 05/30/97 60 126 186 3 900 s-43 06/01/97 303 375 678 2,5 900 ................................................................................................................................................................................................................................................................................................................................................................................... , S-43 06/03/97 75 75 2 900 ..................................................................................................................................................................................................................................................................................................................................................................................... , ~~. 06/04/97 150 150 2 900 ~ ................ ................ 6~b,B~,R ......................................................................... ~ .................................................................................... , ......................................................................................................................................... ~.~ ................................... B ..... 900 ........................................................................................................................................... .................................... i .................................................................................................................................................................................................................................................................................................................................................................................................................... d~ J 06/06/97 107 107 3 800 .......................................................................................................................................................................................... S-43 06/08/97 75 43 118 3 800 .... S-43 06/09/97 226 226 3 900 S-43 06/10/97 ~01 - 201 3 900 S-43L1 06/12/97 25 25 50 3 900 - -- S-43L1 06/14/97 32 68 1 O0 2.5 800 S-43L 1 06/16/97 70 70 3 800 ~:~[~ ............................ ~2~"~ ..................... ~'~'~ ......................................... '~-~ .................................................................................................................................................................................................................................................................... 180 2.5 ~00 .......................................................................................................................................................... ~ ............................... ~:~.~-~.~ ........................... 6~.~.~.~.~ ................... 375 500 875 2.5 ~25 ........................................................................................................................................ ~.~[.i ........................ ~/~. ~ ......................................................................... ~.~ .................................................................................................................................................................................................................................... ~ .................................... ~ 8oo ..................................................................................................................................................................................... ~:'~'~' ......................... ~'~'~'~'~' .......................................................................... ~'~"~ ................................ ~"~'~'"~ ......................................................................................................................................................... ~'~'~"~ ....................... 3 875 ................................................................................................................................................................................. ~:~'~'~ ............................ ~]~ ....................................................................................................................................................................................................................................................................................... ~ ...................................... ~ ...................................... 2.6 1250 '~'~'~'~ ......................................................................................................................................................... .......................................................................................................................................................................................................................................................................................................................... , ................................................................................................ ............................................................................................................... Al h ;sred e. ices ri-!ling TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension AP! # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose'setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid wastes. There are.no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 re.d rvlces rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request DEC 141998 Dear Ms. Mahan: Alaska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular DispoSal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1~03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-01, L-16, J-19, L-25, F-30, L-21, K-38, NMI> #1 & ~2, K-05, K-02, It-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide .you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show-the following wells not listed on your report were used for annular disposal: ,.Annular Disposal Letter 12/14/98 ! · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdouah//3 - ~z°° ~4 ,~ - · ~he Point wells F-06, H-05, H-06, J'13, L-24 - · PBU wells-18-30, 18-31, 14~,~3, E-34, E-36, G-~A, and S-33- · ~d~vldu~ logs ~e provided to you for these ~ogs as We~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opPortunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED ,.OEC !4 1998 ~aska 0ii & Gas Cons, Comm'~sio~ Anchorage har(~,d Se~ice DHIling nn~ar Injection Volumes Jly 25, 1995 until December 1998 umulative Report Sudace Casing ' Inj Well Depth I dicott yon 15 1-19/I-18 ,. Legal Desc Cum Mud Cum Rig Cum Total & Ctgs Wash 5000 Sec. 36, T12N, R16E 8,960 )/On 15 1-23/O-15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 ~?.?..!5_ ............ 1-33/M-23' 5013 3217'NSL, 2114'WEE, Sec 36,T12N, R16E 9,879 /on 15 1-61/Q-20 4236 .3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 7,848 30,604 ...... 9,729 Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Fluids FluidS .F~eeze Freeze SI.art End S!a!us . 992 1,160 150 ...... ........................ !.~(~. ~ 2/5!..95 .... 12!5!96 ........... 0p~n ..... 200 120 9/30/95 12/31/95 Open 8/31/95 12/31/95 Broached fon 14 15-47 3515 3648'NSL 4956'WEL Sec22T11N R14E 3002 903 2009 ' ' 90 11/7/95 12/31/95 Open ~ ....................................... ........'. .......................... .'. ...................... ,. ................................................. !. ...................................................................................................... ,. ......................................................................................................................................................................................................................................................................................................................................................................................... fon 14 DS 15-45 3829' 4749' NSL, 5180' WEL, Sec. 22, T11N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached ton 14 DS 15-48 3548 Sec, 22, T11N, R14E . . . 3,385 216 820 2,283 66 12/21/95 12/21/96 Open ,on 14 DS 15-49 3667 4676' NSL~ 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open 'on 9 18-30 3930 1499'SNL 26'WEL Sec 24 T11N R14E 2 266 936 380 800 150 7/25/95 12/31/95 Open 'on 9 18-31 3680 3719'NSL 64'WEL Sec 24 T11N R14E 6 086 2 250 1 100 2 565 171 7/26/95 12/31/95 Open 'on 9 18-32 3830 3632'NSL, 41'WEL, Sec 24 T11N R14E 3 311 1 861 200 1100 150 8/24/95 12/31/95 Open on 9 18-33 4140 3690'NSL, 56'WEL, Sec 24 T11N R14E 5 215 2 050 3 035 10 120 '9/28/95 12/31/95 Open ors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95. Open ors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open ?.~....1...8.E' ......................... !..3.2~ ........................................ .3...4...3...! .................................. l...5.~..5..~.?....8.~.:..5-~-..8...7-.~.w.....E...~....s..tc...~?1...~-N~-~`~.~ .......................... .4...,..?. ........................... ..3..,._5.2_3- ................... .4,.~?. ............................................................. 150 10/26/95 12/31/95 Open ors 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open Ioration 4 Sourdough/¢3 4236 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed le E MPK-17 3508 3648'NSI.,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open ~rs 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open .)..r..s.?...2..E.. .................... ~. _P..C...-?...5. .......................... .8_5..9...5. ........................ _1..!..4_3 '_F._N_L.:...2..4.3_6_'_F..W_ _l.:.,_s_e c_ _1 o__,.T_13__N ,.L _R_I_0_ .E- ................. 1..,..9.0..5.. ................. _1..,_46.5_ ............. _30% ........................... !40 1/5/96 1/5/97 Open ~rs 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open ~rs 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page I Sha,r,,~d oervice Drilling Annblar Injection Volumes July 25, 199'~ until December 1998 Cumulative Report ~ig Inj Well' · ~abors 22E MPF-06 Jabors 22E MPF-14 Jabors 22E MPF-70 labors 22E MPH-05 Surface Casing Depth 8766 , 6690 7919 5335 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus , Legal Desc Cum Total & Ctgs Wash Fluids Fluids , Freeze ..... Ereeze Start End Status Sec 06,T13N, R10E 1,927 1,731. 196 1/25/96 1/25/97 Open Sec 06,T13N, R10E UM 18,717 17,107 1,270 340' 6/3/96 6/3/97 Open 2189'NSL 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 . 190 56 6/17/96 6/17/97 Open 2882'NSL 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open ./ labors 22E MPH~06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95. 12/31/95 Open labOrs 22E MPI-07 2680 2339'NSL 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 ' 70 9/21/95 12/31/95 Open ,, labors 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28 T13N, R10E 14 127 13,292 645 60 130 10/17/95 12/31/95 Open labors 22E MPJ~16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 Open labors 27E B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 1/25/96 1/25/97 Open labors 27E MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open labors 27E MPF-25 3405 1857'NSL, 2696'WEL, Sec 6,T13N, R10E ' 9,897 9,357 250 . 225 65 12/26/95 12/26/96 Open 'abors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open ' abors 27E MPF-38 8561 1994'NSL, 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 12/31/95 Open abors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open abors 27E MPF-53 6750 2028'NSL 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open abors 27E MPF-61 6585 2077'NSL, 526'WEL Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 12/31/95 Open abors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open abors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 91665 . 75 8/31/95 12/31/95 Open abors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open abors 27E MPL-24 6515 3654'NSL 5180'WEL Sec 8 T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31/95 Open 'OA ~E F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/2i/97 Open !E .................................. .F..:..3.~ ...................................... ..3.~?...! .................................. ~..6..~.2.'.N.....S...L.,......2._8.7..~.?.E.~,...~.,..T.!.,!..,N.:R_!.,3...E,. ................................... ..6..,.?. ................................ !.,.9....9...8.. ............................... ?..5_9. ....................... ..3.,..4....7...!. ............................................................................................................................... ~..3.~ ............ !??~. .................. t2~,!.~!? ...................... ,,0.?., ............... ~yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open 3yon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96 4/10/97 Open ~yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open ?..b...o...r.s...!...8.~ ................ ..S_-_4? ............................ ..3...1_.2..!..'. ........................... .4..2.11__'._N. S_ L_,..4_50__~3:_W_..E L,___S_E_(?5_,_T12 _N_, .R_ 1__2.E__ ........... _5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN Page 2 Shared Se'i~vice Dr. illing Ann~i~l'r ~njeCtion Volumes July 25, 1995, until December 1998 Cumulative Report Sudace Casing Cum Mud Rig Inj Well Depth Legal Desc Cum Total & Ctgs Habors 28E B-33 3504' 969'SNL, 1898'EWL0 Sec 31. TllN. R14E 3,974 2.842 Habors 28E E-34 3664 168'SNL. 500'WEL. Sec 6. T11 N. R 14E 9,656 7.228 . qabors 28E E-36 3648 1706'SNL 822'WEL, Sec 6,T11N. R14E 9,271 4,417 Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Wash Fluids. Fluids Freeze Freeze Start End. S~atus 857 195 80 5/1/96 12/31/96 Broached 1,420 858 40 110 8/23/95 12/31/95 Open' 1,293 3,096 365 100 7/25/95 12/31/95 Open qabors 28E E-37 3810 3391'NSL 881'WEL, Sec 6,T11N, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Open ......................................................................................... ._;.. .......................................... .._ .............................. .. .......................................................................... .. ~labors 28E E~39 3638 . 3358"NSL 501'WEL, Sec 6,.T11N. R14E 2,250 . 928 220 1,022 8 ~abors 28E G-04A 3509 2917'NSL 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 Open , ~labors 28E G-21 3509 2911'NSL 2368'WEL. Sec 12.TllN. R14E 11,430 3,956 3,072 4 270 70 '62 9/8/95 12/31/95 Open qabors 28E S-24 . 2750 1633'SNL 4228'WEL Sec 35.T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open qabors 28E 8-33 29'58 1639'SNL 1487'WEL. Sec 35.T12N. R12E 18,014 6,613 2.431 8,392 270 308 12/1/95 12/1/96 Open ~labors 28E S-41 3331 4152' NSL 4504' WEL, Sec 35,T12N, 8,062 4,159 '2,034 1.754 115 2/8/96 , 2/8/97 Open ~Jabors 28E S-42 3077 Sec 35. T12N, R12E 168 100 68 3/13/96 3/13/97 Open ~abors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 Open ~abors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open Page 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Plugging _ Perforate _X Alter casing _ Repair well _ Other _X FCC 5. Type of Well' 6. Datum elevation (DF or KB feet) Development __X RKB 68 feet Exploratow__ 7. Unit or Property name Stratigraphic__ Service_ (asp's 618929, 5980415) (asp's 622252, 5980884) Operation shutdown_ Pull tubing_ (asp's 623074, 5984201) 1. Operations performed: FCC / ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1068' FNL, 4503' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 652' FNL, 1172' FEL, Sec. 35, T12N, R12E, UM At effective depth 2629' FNL, 293' FEL, Sec. 26, T12N, R12E, UM At total depth 2550' FNL, 309' FEL, Sec. 26, T12N, R12E, UM 12. Present well condition summary Total depth: (asp's 623057, 5984279) measured 13888 feet Plugs (measured) true vertical 9018 feet Prudhoe Bay Unit 8. Well number S-43 9. Permit number / approval number 197-052 10. APl number 50-029-22754-00 11. Field / Pool Prudhoe Bay Field / Prudhoe BaY Pool Effective depth: measured 13807 feet Junk (measured) true vertical 9012 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx AS (Approx) 131' 131' Surface 3090' 9-5/8" 1700 sx CS III, 505 sx 3121' 3066' Class 'G' Intermediate 10165' 7" 580' sx Class 'G' 10196' 8991' Liner 2854' 4-1/2" 310 sx Class'G' 10059'- 12913' 8978'- 8986' Slotted Liner 892' 4-1/2" Uncemented 12913' - 13805' 8986' - 9012' Perforation depth: measured Open Perfs 10600'-10620', 10645'-10670', 10710'-10726', 11840'-1 I890', 11915'-11940', Open Perfs (cont) 12010'-12085', 12100'-12250', 12310'-12490', Slotted Liner 12913'-13805' true vertical Open Perfs 8990'-8992', 8995'-8998', 9002'-9004', 9025'-9002', 9022'-9021',9020'-9018', Open Perfs (continued) 9018'-9013', 9011'-9012', Slotted Liner 8984'-9012' 4-1/2", 12.6#, L-80, TBG @ 9032' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 9089' MD. 4-1/2" Isolation Assembly from 9774' to 9808'. 7"x 4-1/2" BKR S-3 PKR @ 9032'. 7"x 4-1/2" BKR ML PKR @ 977~L _. 7" x 4-1/2" TIW S-6 PKR @ 10065'. 4-1/2" HES HXO SSSV @ 22~r~. C F IV F r) 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached),.I!~J ~" 'k ~ 0 ~I ~0~';2~ ~ :' Treatment description including volumes used and final pressure 14. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) OiI-Bbl 468 601 Prior to well operation 05/15/2002 Subsequent to operation 05/23/2002 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations _ Oil _X Gas _ orrect to the best of my knowledge. Title: Technical Assistant DeWayne R. Schnorr Representative Daily Average Production or Iniectio~~t. [~jiJ & '(~;;i:.; (;~.;~i-i~?;, Udiit~iI~'-;:~,¢t..~ Gas-Mcf Water-Bbl Casi '.r~~{~¢ Tubing Pressure 5730 1733 296 684 1179 278 16. Status of well classification as: Suspended _ Service Form 10-404 Rev 06/15/88 · Date. May .24., 2002. Prepared by DeWayne R. Schnorr 564-5174 GANNEP jUN & 2D Z SUBMIT IN DUPLICATE S-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/27/2002 PERFO~TfNG: DR]:FT/TAG 03/30/2002 PERFOF~TTNG: PERFORATTNG 03/31/2002 PERFORATZNG: PERFORATTNG 04/02/2002 PERFORAT]:NG: F:[LL CLEAN OUT; PERFORAT:[NG 05/13/2002 PERFORAT]:NG: FTLL CLEAN OUT W! N2; PERFORAT]:NG 05/14/2002 PERFORATING: F:~LL CLEAN OUT W! N2; PERFORAT]:NG 05/15/2002 PERFORAT[NG: PERFOI::;~T:[NG 05/16/2002 PERFORATfNG: PERFOI:;~T:[NG 05/17/2002 PERFORAT:[NG: PERFORAT]:NG EVENT SUMMARY O3/27/02 DRIFT TBG W/3-3/8" DUMMY GUN UNABLE TO PASS 8949' WLMD -- DRIFT W/ 3.5 CENT. & 3.25 LIB TO 9004' WLMD, LIB INCONCLUSIVE -- RUN 2.8 CENT. TO 9880, SET DOWN DUE TO DEVIATION -- RUN 3.6 GR TO 8949' WLMD UNABLE TO PASS -- RUN 3-3/8" DMY GN & SAMPLE BAILER TO 8955' WLMD, PULL 1,150 # BIND TO COME FREE -- RUN 2.68 CENT. & 2-1/4" DMY GN TO 9878' WLMD, SET DOWN DUE TO DEVIATION -- RUN 2-7/8" DMY GN TO 9882' WLMD, SAT DOWN DUE TO DEVIATION-- **** WELL READY TO POP **** 03/30/02 03/31/02 O4/O2/02 05/13/02 05/14/02 MIRU DS CT UNIT#3- MU GR/CCL LOGGING TOOLS RIH. RIH WITH 3.25" CENTRALIZER & MEM TOOLS - CAN'T MAKE IT PAST 10,073' CTDM, POOH. MU 3" JSN & RIH FOR FCO - DRY TAG AT 10109' CTDM. START BIO SWEEP/FCO. UNABLE TO LOAD HOLE W/TOTAL 590 BBL FLUID. MIRU DS CTU #3. RIH W/3.5" JSN - WON'T PASS 9027' CTDM. CHANGE TO 3"NOZ. ATTEMPT CLEAN OUT,SOLIDS STUCK PIPE,WORK PIPE AND PUMP RATE TO FREE PIPE, POOH. MIRU CTU. MU 3" JSN RIH AND DRY TAG FILL @ 10,123 (PICK-UP STICKY). START FCO WITH 1 BPM XSL 2% KCL (W/0.02% SURFACTANT) AND 900 SCF/MIN N2. WELL FLOWING W/1MM GL. TAKE RETURNS TO SYSTEM. CONTINUED NITRIED CLEAN OUT TO 12,150' CTMD W/SWEEPS OF BIO AND XSLICK 2% KCL. POOH CHASING RETURNS. RU PSD MEMORY LOGS (GR- CCL). RIH LOGGING FIRST SERIES OF PERFS FROM 12,100' TO 11,700'. 05/15/02 RIH W/2" 25' HSD 4 SPF GUN #1. SHOOT FIRST GUN @ 12,085' TO 12,060'. RIH WITH 2ND 25' HSD 4 SPF GUN AND PERFORATE FROM 12,035' TO 12,060'. RIH WITH GUN #3 (25' HSD 4 SPF) AND PERF FROM 12,010' TO 12,035'. MU NEW MHA AND RUN PDS MEMORY LOG (GR-CCL). Page 1 6ANNED J U N 20 02: S-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/16/02 MEMORY LOG FROM 12,000' TO 11,600', FLAG AT 11,940' CTMD. POOH. RIH WITH 2" 25' GUN #4, SHOT 11,915'- 11,940' MD. POOH. RIH WITH 2" 25' GUN #5, SHOT 11,865- 11,890' MD. POOH. RIH WITH 2" 25' GUN #6, SHOT 11,840- 11,865' MD. POOH. 05/17/02 RIH W/WFD CONNECTOR AND PDS MEMORY TOOLS. LOG FROM 10,300' TO 10,700' CTMD. POOH. WEEKLY BOP TEST. RIH WITH 7TH GUN AND PERF 16' FROM 10,710' TO 10,726'. RIH WITH RUN #8 AND PERF FROM 10,645' TO 10,670'. RIH WITH RUN #9 AND PERF 20' FROM 10,600' TO 10,620' MD. POOH. <<<JOB COMPLETE. LEAVE WELL FLOWING & TURN OVER TO PAD OPERATOR>>> ,, , Fluids Pumped , BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) . 167 50/50 METHANOL WATER 183 SLICK 2°/° KCL WATER ...... 55 2% EXTRA SLICK KCL WATER WITH SURFACTANT ....... 65 BIOZAN 470 TOTAL ADD PERFS 05/15-17-2002 THE FOLLOWING INTERVALS WERE PERFORATED WITH THE 2" HSD PJ, 4 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 10600' - 10620' 10645' - 10670' 10710'- 10726' 11840' - 11890' 11915' - 11940' 12010' - 12085' Page 2 JUN 2.'& 2002 __._ STATE OF ALASKA ALASKA, ,LAND GAS CONSERVATION CO, /IISSION REPORT OF SUNDRY WELL OPERATIONS 121 Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Name of Operator 15. Type of well: . 6. Datum Elevation (DF or KB) BP Exploration (Alaska)Inc. I ~ Deve opmen[ KBE = 68.1' 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4211' NSL, 4503' WEL, SEC. 35, T12N, R12E, UPM At top of productive interval 4627' NSL, 1172' WEL, SEC. 35, T12N, R12E, UPM At effective depth 2629' NSL, 293' WEL, SEC. 26, T12N, R12E, UPM At total depth 2731' NSL, 316' WEL, SEC. 26, T12N, R12E, U PM [] Exploratory [] Stratigraphic [] Service 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-43 9. Permit Number / Approval No. 197-052 10. APl Number 50- 029-22754 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 13888 feet true vertical 9018 feet Effective depth: measured 13807 feet true vertical 9012 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 110' 20" 3090' 9-5/8" Plugs (measured) Junk (measured) Cemented 260 sx Arctic Set (Approx.) 150 sx CSlII, 505 sx 'G', 1550 sx CSlII MD TVD 110' 110' 3121' 3065' Perforation depth: measured slotted liner 12913'-13805' true vertical 8986'-9012' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 9089 4-1/2", 12.6#, L-80 @ 9774-9808 Packers and SSSV (type and measured depth) Packer @ 9032, 9774 SSSV @ 22O9' !13. Stimulation or cement squeeze summary See Attachment iIntervals treated (measured) Treatment description including volumes used and final pressure . I 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl 614 1343 407 1005 1661 942 Casing Pressure Tubing Pressure 227 247 15. Attachments i 16. Status of well classifications as: [] Copies of Logs and Surveys run i ~ Oil r-~ Gas r~ Sus-ended - · [] Daily Report of Well Operatio.~ns i L..N bJ LJ P ~erv~ce 17. I hereby..ca4tify.,~at the,~reg0i/!~g is true and/,,~rect to the best of my knowledge Si g n e'~ ~?./'(/.,¢'.,,¢,~z,~ 7 i /'~ichael ~ll~'ms ' v- /q,,,~/;~,~~ __ Title Tec__h..__n_!_ca! A__S___S_!_stan~_.!__V.. ..... Prepared By Narne/Nurnben D ate///"/~-/,/~ ~' Submit In Duplicat Form 10-404 Rev. 06/15/88 S-43 DESCRIPTION OF WORK COMPLETED Stimulation Operation 07/O9/99 A Acid Stimulation Treatment was performed using the following fluids: SUMMARY Shut in gas lift, ru and rih w/2.5" nozzle; started circulation kill at 1000'. Well died and closed wing. Injection was 2.4 bpm @ 60 psi. Rih and "tagged-up" at 13,607 ctmd, tried working down but kept working the coil upwards; bad...not good, suspect that friction was preventing downward advancement. Jetted 18 bbls acid from 12,900 to final working depth of 13,435. Shut down, pulled to 12,900 and let soak for one hour. Rih jetting 48 bbls acid and easily progressed to 13,700 so plf (pulled little faster) to 12,910 and jetted down to 13,700. Shutdown and pulled to 12,900 and let soak for one hour. Rih and jetted with 150 bbls KCI water flush; had Iockup again at 13,610. Pooh and put well on production. Fluids Pumped BBLS. Description 490 Freshwater w/2% Kcl. 66 15% HCI/10% Xylene (see summary below) 556 Total Pumped 09/16/99 S-43 DESCRIPTION OF WORK COMPLETED AddPerf Operation RECEIVED .& Gas Cons. Comnd~l~n Anchorage SUMMARY The following additional interval were perforated using 2" guns, 4 SPF, random orientation and 0° phasing. 12,100'-12,250' MD 12,310'-12,490' MD PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS ........ Page: 1 Date: 05/24/99 RUN RECVD 97-052 PACKER SET ~L 9748 97-052 CD~_RC5 - MD ~- 8410-13850 97-o52 CD~C5-MD ~ 8410-13850 97-052 CDR/~CS-TW ~ FINA/~ 08/07/97 FINAL 11/05/97 T FINAL 11/05/97 T FINAL 11/05/97 T FINAL 11/05/97 T 1-7 11/05/97 11/03/97 10-407 ~COMPLETION DATE @ ~ ~R /~7/ DAI~¥ WE~ OPS ~ @ J--I ~ 1~71 TO ~ I~1~?1 Are dry ditch samples required? yes ~._~d received? Was the well cored? yes ~.~A~alysis & description received? Are well tests required?ii~es ~Received~2~~ Well is in compliance ~ ~r~ Initial COMMENTS T D BOX .... STATE OF ALASKA ALASKA ...,~. AND GAS CONSERVATION COb, MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--IOperation Shutdown [] Stimulate [] Plugging E~] Perforate I~1 Pull Tubing E~]Alter Casing F-I Repair Well I--IOther 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4211' NSL, 4503' WEL, SEC. 35, T12N, R12E, UPM At top of productive interval 4627' NSL, 1172' WEL, SEC. 35, T12N, R12E, UPM At effective depth 2629' NSL, 293' WEL, SEC. 26, T12N, R12E, UPM At total depth 2731' NSL, 316' WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 13888 feet true vertical 9018 feet Effective depth: measured 13807 feet true vertical 9012 feet Casing Length Structural Conductor 110' Surface 3090' Intermediate Production Liner 3737' Size 20" 9-5/8" Plugs (measured) Junk (measured) 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 68.1' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-43 9. Permit Number / Approval No. 97-52 10. APl Number 50-029-22754 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Cemented 260 sx Arctic Set (Approx.) 150 sx CSIII, 505 sx 'G', 1550 sx CSIII 4-1/2" 310 sx Class 'G' Perforation depth: measured 12913'-13805' slotted liner true vertical 8986'-9012' Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 @ 9089' MD TVD 110' 110' 3121' 3065' 10070'-13807' 8980'-9012' 4-1/2", 12.6#, L-80 @ 9774'-9808' Packers and SSSV (type and measured depth) Packer @ 9032' SSSV @ 2209' Packer @ 9774' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl SI Casing Pressure Tubing Pressure 2013 2489 403 781 126 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended I--I Daily Report of Well Op/e~ations 7. I hereby, cert, f)Cy that/~he fg/r~going is 1;¢~ffC-abd correct to the best of my knowledge f~ORAr=LW~I~L¥~Cv~I~ ~ ""~_¢?~/'z'"'~ Title Technical Assistant III Prepared By Name/Number: Service Date Form 10-404 Rev. 06/15/88 Submit In Duplicate"-q S-43 DESCRIPTION OF WORK COMPLETED Stimulation Operation 09/22/97 A Scale Inhibitor Treatment was performed using the following fluids: SUMMARY Well was flowing prior to pumping; shut well and gas lift in. Pumped scale inhibitor, volumes shown below. Left well shutin until 10 pm tonight. Fluid Summary 400 I Filtered seawater. 30 I Scale inhibitor, B34 10% solution in seawater. 430I Total GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11605 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12/3/97 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape S-22B (REDO) 97473 GR & ARC5 "~ 7 ~a~ 0 '7_,.... 970708 1 *REDO -INCORRECT MNEMONICS S-43 (REDO) 97471 CDR&ARC5 ~"7~'? 970'530 1 *REDO -SPLICE RESISTIVITY S-43 L1 (REDO) 97472 CDR&ARC5 ~ "'7;?~,~ 970617 1 *REDO -MERGE RESISTIVITY IN EDIT FILE , . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 [)L'C 0 $ 199'1 Date Delivered: '-t5 ~-~ ~*'& ~/~ I~ ~' q~ "~c~ l~/~/~'7~ Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-52 397-090 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22754 4. Location of well at surface ! ~':;~':'i:~"?"-i:':-~ ~~'~i 9. Unit or Lease Name _/:'..:,:; ~ Prudhoe Bay Unit 4211' NSL, 4503' WEL, SEC. 35, T12N, R12E, UPMAt top of productive interval!? ~ -~~~i ~ ~ -'"~l~' ~'t 10. Well Number 4627' NSL, 1172' WEL, SEC. 35, T12N, R12E, OPM ?."-¥!i:- !~_i~~ i~i~.-'-~ S-43 At total depth i ~/~_.~r.,._ .~: .......... ~,~. 11. Field and Pool 2731' NSL, 316' WEL, SEC. 26, T12N, R12E, UPM~ ' Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 68.1'I ADL 028257 12. Date Spudded5/3/97 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' °f COmpletiOns5/30/97 6/22/97 N/A MSL, One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13888 9018 FTI 13807 9012 FTI [~Yes [--INoI (Nipple) 2209' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, LWD/FE, CCL, 23. CASING, LINER AND CEMENTING RECORD CASING SE'FrINS DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 30' 3121' 12-1/4" 1700 sx CSIII, 505 sx 'G' 7" 26# L-80 27' 10196' 8-1/2" 580 sx Class 'G' - 4-1/2" 12.6# L-80 10070' 13807' 6" 310 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 9089' 9032' MD TVD MD TVD 4-1/2", 12.6#, L-80 9774'- 9808' 9774' 12913' - 13805' 8986' - 9012' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) July 4, 1997 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL !GAs-MOF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,. ..0,1ask~.~ 0ii & 6~as Cons, ~issi0ri Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9751' 8864' Shublik 9820' 8897' Top of Sadlerochit 10140' 8989' 31. List of Attachments Summary of Daily Drilling Rep~, Surveys, Annular Pumping Report 32. I hereby certify that the/f~regoir~ is tru,~d c_~rect to the best of my knowledge Signed ~1. Dan Stoltz ~.~~_~ ~ Title Senior Drilling Engineer S-43 /'--- ..... ~ "'- 97~-52 397-090 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / 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 (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 2?: 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 ANNULAR INJECTION DATA ENTRY SCREEN Asset .~.O~, .......................................... Rig Name ~.a,b.cff.$...l~F,, ............................. Inj Well Name ~.:~ ............................................ Sur Csg Dep ;~.1.~.1.'. ............... Cumulative Data Legal Desc .~;~.I..1.'.~.~.5.0;~.'.~.E,I,~.~.F,,~.;3.5.,.T..~?,,bI.,B.I.~ ..................................... Research Permit Start ......... .~;Z:~7. ......... Permit End ......... ~:.7..:.~J~. ......... .............................................................. .............................................................. Daily Data S-43 05/22/97 280 280 3 850 S-43 05/23/97 '384 384 3 600-900 S-43 05/25/97 111 123 234 3 ' 850 -- S-43 05/27/97 203 204 407 3 850-900 $-43 05/28/97 151 120 271 3 900 S-43 05/30/97 60 126 186 3 900 S-43 06/01/97 303 375 678 2.5 900 S-43 06/03/97 75 75 2 900 S-43 06/04/97 150 150 2 900 S-43 06/05/97 70 70 3 900 S-43 06/06/97 107 107 3 800 S-43 06/08/97 75 43 118 3 800 S-43 06/09/97 226 226 3 900 S-43 06/10/97 201 201 3 900 S-43L1 06/12/97 25 25 50 !3 900 S-43L1 06/14/97 32 68 100 12.5 800 S-43L1 06/16/97 70 70 3 800 ..S...:..4...~.~:! .......................... ...0..~.!.!....7..!?. ................... .!....4.....0.. ...................................... ...4....o.. ............................................................................................................................... ~80 2.5 8oo S-43L1 06/18/97 375 500 875 2.5 725 !3 800 .................................................................................................................................. iS-43L1 06/19/97 75 75 ~'§---4~E~ .................. ~?~'~'7 .................................................... ~-fg ................. ~"i-~'~ .............................................................................................................. C~"~'~- ............... 13 ~75 ............................................................................................................................................................................................................................................... I ............................................................................................................................................................................................................................................................................................................................................. $_43L~ O6/23/97 '§i5' .................................... ~.i5 .................................... ~2.6 1250 OF'~ , I Performance Enquiry Report Operator BP Exploration Date 01:40, 28 Aug 97 Page 1 The analysis is from - 21:30, 06 May 97 - to - 21:30, 06 May 97 Programs in Result Table: S-43 Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) S-43 Event 21:30, 06 May 97 21:30, 06 May 97 0 hr 0 min Obtained leak off 11.570 Hole Size MDR 8-1/2 Facility PBS Pad Progress Report Well S-43 Rig Nabors 18E Page Date 1 27 August 97 Date/Time 02 May 97 03 May 97 04 May 97 05 May 97 06 May 97 07 May 97 17:00-18:00 18:00-18:30 18:30-19:30 19:30-03:00 03:00-06:00 06:00-10:00 10:00-12:30 12:30-13:00 13:00-14:30 14:30-02:00 02:00-02:30 02:30-03:00 03:00-06:00 06:00-09:30 09:30-10:30 10:30-16:00 16:00-16:30 16:30-17:00 17:00-22:30 22:30-00:00 00:00-01:00 01:00-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-12:30 12:30-14:30 14:30-15:00 15:00-17:00 17:00-20:00 20:00-20:30 20:30-23:00 23:00-02:30 02:30-04:30 04:30-06:00 06:00-07:00 07:00-10:30 10:30-12:00 12:00-12:30 12:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:30 20:30-21:00 21:00-21:30 21:30-01:30 01:30-02:30 02:30-06:00 Duration lhr 1/2 hr lhr 7-1/2 hr 3hr 4hr 2-1/2 hr 1/2 hr 1-1/2 hr 11-1/2 hr 1/2 hr 1/2hr 3hr 3-1/2 hr lhr 5-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr lhr 1-1/2 hr 1/2 hr lhr 1/2 hr 4-1/2 hr 2hr 1/2 hr 2hr 3hr 1/2 hr 2-1/2 hr 3-1/2 hr 2hr 1-1/2 hr lhr 3-1/2 hr 1-1/2 hr 1/2 hr 3hr 1/2 hr 2hr 1/2 hr 1/2hr 1/2 hr lhr 1/2 hr 1/2 hr 4hr lhr 3-1/2 hr Activity Rigged down Drillfloor / Derrick Held safety meeting Rig moved 50.00 % Rig moved 100.00 % Rigged up Fluid system Rigged up Divertor Fill pits with Water based mud Held safety meeting Made up BHA no. 1 Drilled to 1145.00 ft Pulled out of hole to 207.00 ft R.I.H. to 1145.00 ft Drilled to 1450.00 ft Drilled to 1640.00 ft (cont...) Repaired Drilling tool / logs Drilled to 2266.00 ft Pulled out of hole to 1050.00 ft R.I.H. to 2226.00 ft Drilled to 3135.00 ft Circulated at 3135.00 ft Pulled out of hole to 665.00 ft R.I.H. to 3135.00 ft Circulated at 3135.00 ft Pulled out of hole to 665.00 ft Pulled BHA Pulled BHA (cont...) Rigged up Casing handling equipment Held safety meeting Ran Casing to 3120.00 ft (9-5/8in OD) Circulated at 3120.00 ft Held safety meeting Mixed and pumped slurry - 153.700 bbl Circulated at 2200.00 ft Held safety meeting Mixed and pumped slurry - 530.000 bbl Removed Divertor Installed Casing head Rigged up BOP stack Rigged up BOP stack (cont...) Tested BOP stack Repaired Blind / Shear ram Tested Blind ram Made up BHA no. 2 R.I.H. to 2197.00 ft Drilled cement to 2310.00 ft R.I.H. to 2992.00 ft Tested Casing - Via string Held drill (Kick (well kill)) Drilled cement to 3155.00 ft Circulated at 3155.00 ft Performed formation integrity test - Drilled to 3573.00 ft Circulated at 3573.00 ft Drilled to 3940.00 ft Facility PBS Pad Progress Report Well S-43 Rig Nabors 18E Page Date 2 27 August 97 Date/Time 08 May 97 09 May 97 10 May 97 11 May 97 12 May 97 13 May 97 14 May 97 15 May 97 16 May 97 06:00-08:30 08:30-09:00 09:00-09:30 09:30-21:30 21:30-22:00 22:00-01:30 01:30-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-08:30 08:30-19:30 19:30-20:00 20:00-20:30 20:30-06:00 06:00-10:00 10:00-10:30 10:30-11:00 11:00-03:30 03:30-04:30 04:30-06:00 06:00-07:30 07:30-08:30 08:30-10:00 10:00-13:00 13:00-06:00 06:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-11:30 11:30-12:00 12:00-16:30 16:30-06:00 06:00-13:30 13:30-15:30 15:30-19:00 19:00-06:00 06:00-08:00 08:00-10:30 10:30-12:30 12:30-14:30 14:30-18:00 18:00-00:30 00:30-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-14:30 14:30-21:30 21:30-00:00 00:00-02:00 Duration 2-1/2 hr 1/2 hr 1/2 hr 12hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 2-1/2 hr llhr 1/2 hr 1/2 hr 9-1/2 hr 4hr 1/2 hr 1/2 hr 16-1/2 hr lhr 1-1/2 hr 1-1/2 hr lhr 1-1/2 hr 3hr 17hr 24 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 4-1/2 hr 13-1/2 hr 7-1/2 hr 2hr 3-1/2 hr llhr 2hr 2-1/2 hr 2hr 2hr 3-1/2 hr 6-1/2 hr 2hr 1-1/2 hr 1/2hr 1-1/2 hr 8-1/2 hr 7hr 2-1/2 hr 2hr Activity Drilled to 4162.00 ft (cont...) Pulled out of hole to 3120.00 ft R.I.H. to 4162.00 ft Drilled to 5210.00 ft Held safety meeting Drilled to 5409.00 ft Circulated at 5409.00 ft Pulled out of hole to 657.00 ft Pulled BHA Made up BHA no. 3 R.I.H. to 5409.00 ft Drilled to 6440.00 ft Pulled out of hole to 5350.00 ft R.I.H. to 6440.00 ft Drilled to 7150.00 ft Drilled to 7406.00 ft (cont...) Pulled out of hole to 6350.00 ft R.I.H. to 7406.00 ft Drilled to 8470.00 ft Circulated at 8470.00 ft Pulled out of hole to 4500.00 ft Pulled out of hole to 218.00 ft (cont...) Pulled BHA Made up BHA no. 4 R.I.H. to 8740.00 ft Drilled to 8864.00 ft Drilled to 9461.00 ft (cont...) Circulated at 9461.00 ft Pulled out of hole to 218.00 ft Pulled BHA Installed Wear bushing Made up BHA no. 5 R.I.H. to 3120.00 ft Serviced Block line R.I.H. to 9461.00 ft Drilled to 9867.00 ft Drilled to 10001.00 ft (cont...) Circulated at 10001.00 ft Circulated at 10001.00 ft Drilled to 10153.00 ft Drilled to 10205.00 ft Circulated at 10205.00 ft Pulled out of hole to 3100.00 ft R.I.H. to 10205.00 ft Circulated at 10205.00 ft Laid down 9600.00 ft of 5in OD drill pipe Pulled BHA Rigged up Top ram Rigged up Casing handling equipment Ran Casing to 7in (1000.00 ft OD) Ran Casing to 9632.00 ft (7in OD) (cont...) Laid down 328.00 ft of Casing Circulated at 9300.00 ft Laid down 820.00 ft of Casing Facility PBS Pad Progress Report Well S-43 Rig Nabors 18E Page Date 3 27 August 97 Date/Time 17 May 97 18 May 97 19 May 97 20 May 97 21 May 97 22 May 97 02:00-03:30 03:30-06:00 06:00-16:00 16:00-16:30 16:30-19:00 19:00-22:30 22:30-23:00 23:00-03:00 03:00-04:00 04:00-06:00 06:00-12:00 12:00-12:30 12:30-14:00 14:00-15:30 15:30-02:30 02:30-05:00 05:00-06:00 06:00-20:30 20:30-21:30 21:30-22:00 22:00-02:00 02:00-05:00 05:00-06:00 06:00-08:00 08:00-10:00 10:00-12:30 12:30-13:00 13:00-14:30 14:30-15:30 15:30-16:00 16:00-17:00 17:00-00:00 00:00-06:00 06:00-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-18:30 18:30-19:00 19:00-20:30 20:30-23:30 23:30-00:00 00:00-01:00 01:00-02:00 02:00-06:00 06:00-12:00 12:00-15:30 15:30-17:30 17:30-19:30 19:30-20:30 20:30-21:00 21:00-23:00 23:00-00:00 00:00-01:00 Duration 1-1/2 hr 2-1/2 hr 10hr 1/2 hr 2-1/2 hr 3-1/2 hr 1/2 hr 4hr lhr 2hr 6hr 1/2 hr 1-1/2 hr 1-1/2 hr llhr 2-1/2 hr lhr 14-1/2 hr lhr 1/2 hr 4hr 3hr lhr 2hr 2hr 2-1/2 hr 1/2 hr 1-1/2 hr lhr 1/2hr lhr 7hr 6hr 7hr lhr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 3hr 1/2 hr lhr lhr 4hr 6hr 3-1/2 hr 2hr 2hr lhr 1/2 hr 2hr lhr lhr Activity Circulated at 8480.00 ft Laid down Casing of 1190.00 ft Laid down 8480.00 ft of Casing (cont...) Removed Casing handling equipment Rigged up Top ram Tested BOP stack Installed Bore protector Made up BHA no. 6 Made up BHA no. 6 Singled in drill pipe to 2000.00 ft Singled in drill pipe to 2000.00 ft (cont...) Reamed to 9330.00 ft Worked stuck pipe at 9325.00 ft Circulated at 9240.00 ft Reamed to 9504.00 ft Circulated at 9240.00 ft Washed to 9340.00 ft Washed to 9340.00 ft (cont...) Pulled out of hole to 9125.00 ft R.I.H. to 9428.00 ft Reamed to 9625.00 ft Reamed to 9632.00 ft Reamed to 9645.00 ft Reamed to 9645.00 ft (cont...) Circulated at 9664.00 ft Pulled out of hole to 500.00 ft Pulled BHA Rigged up Kelly Tested BOP stack Tested Kelly Made up BHA no. 7 Singled in drill pipe to 9420.00 ft Reamed to 9717.00 ft Reamed to 10205.00 ft Circulated at 10205.00 ft Pulled out of hole to 8955.00 ft R.I.H. to 9740.00 ft Reamed to 9835.00 ft R.I.H. to 10205.00 ft Circulated at 10205.00 ft Pulled out of hole to 600.00 ft Pulled BHA Rigged up Top ram Rigged up Casing handling equipment Ran Casing to 7in (3100.00 ft OD) Ran Casing to 3100.00 ft (7in OD) (cont...) Circulated at 9250.00 ft Ran Casing to 10196.00 ft (7in OD) Circulated at 10196.00 ft Circulated at 10196.00 ft Held safety meeting Rig waited · Equipment Mixed and pumped slurry - 242.000 bbl Displaced slurry - 387.000 bbl Facility PBS Pad Progress Report Well S-43 Page 4 Rig Nabors 18E Date 27 August 97 Date/Time 23 May 97 24 May 97 25 May 97 26 May 97 01:00-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-09:30 09:30-12:30 12:30-14:30 14:30-15:00 15:00-16:30 16:30-19:00 19:00-22:30 22:30-23:30 23:30-00:00 00:00-06:00 06:00-12:30 12:30-13:00 13:00-14:00 14:00-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-19:00 19:00-19:30 19:30-20:00 20:00-21:00 21:00-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-12:30 12:30-15:30 15:30-06:00 06:00-22:00 22:00-23:30 23:30-01:00 01:00-01:30 01:30-04:30 04:30-05:30 05:30-06:00 06:00-08:00 08:00-12:30 12:30-13:30 13:30-16:30 16:30-19:00 19:00-21:30 21:30-01:30 Duration lhr 2hr lhr lhr 3-1/2 hr 3hr 2hr 1/2 hr 1-1/2 hr 2-1/2 hr 3-1/2 hr lhr 1/2 hr 6hr 6-1/2 hr 1/2 hr lhr 1-1/2 hr lhr 1/2 hr lhr lhr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr lhr 1/2hr lhr 1/2 hr 3hr lhr 1/2 hr 3-1/2 hr lhr 1-1/2 hr 3hr 14-1/2 hr 16hr 1-1/2 hr 1-1/2 hr 1/2 hr 3hr lhr 1/2 hr 2hr 4-1/2 hr lhr 3hr 2-1/2 hr 2-1/2 hr 4hr Activity Cleared Cement head Installed Seal assembly Rigged up Top ram Serviced Annular preventor Serviced Annular preventor (cont...) Tested BOP stack Rigged up Kelly Serviced Block line Rig waited: Equipment Made up BHA no. 8 R.I.H. to 9600.00 ft Circulated at 9600.00 ft Held drill (Kick (well kill)) Laid down 3100.00 ft of 5in OD drill pipe Laid down 9400.00 ft of 5in OD drill pipe (cont...) Removed Drillstring handling equipment Rigged up Drillstring handling equipment Singled in drill pipe to 9970.00 ft Drilled cement to 10103.00 ft Circulated at 10103.00 ft Tested Casing - Via annulus and string Drilled cement to 10205.00 ft Took MWD survey at 10190.00 ft Drilled to 10225.00 ft Circulated at 10225.00 ft Circulated at 10200.00 ft Took MWD survey at 10225.00 ft Drilled to 10263.00 ft Took MWD survey at 10263.00 ft Drilled to 10294.00 ft Took MWD survey at 10260.00 ft Drilled to 10358.00 ft Took MWD survey at 10358.00 ft Took MWD survey at 10358.00 ft (cont...) Pulled out of hole to 260.00 ft Downloaded MWD tool Made up BHA no. 9 R.I.H. to 10358.00 ft Drilled to 10723.00 ft Drilled to 11658.00 ft (cont...) Circulated at 11568.00 ft Pulled out of hole to 9840.00 ft Logged hole with LWD: Formation evaluation (ERE) from 9840.00 ft to 9596.00 ft Pulled out of hole to 260.00 ft Downloaded MWD tool Made up BHA no. 10 Made up BHA no. 10 (cont...) R.I.H. to 11568.00 ft Worked toolstring at 10568.00 ft Pulled out of hole to 260.00 ft Pulled BHA Made up BHA no. 11 R.I.H. to 11578.00 ft Facility PBS Pad Progress Report Well S-43 Page 5 Rig Nabors 18E Date 27 August 97 Date/Time 27 May 97 28 May 97 29 May 97 30 May 97 31 May 97 01 Jun 97 02 Jun 97 01:30-06:00 06:00-10:30 10:30-11:00 11:00-12:30 12:30-13:00 13:00-16:30 16:30-17:00 17:00-19:00 19:00-23:00 23:00-06:00 06:00-03:00 03:00-04:30 04:30-06:00 06:00-08:30 08:30-10:00 10:00-10:30 10:30-13:30 13:30-14:00 14:00-16:00 16:00-17:30 17:30-18:00 18:00-21:30 21:30-06:00 06:00-13:30 13:30-15:00 15:00-16:30 16:30-19:00 19:00-20:00 20:00-22:00 22:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-15:00 15:00-22:30 22:30-00:00 00:00-05:00 05:00-06:00 06:00-07:00 07:00-09:00 09:00-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-15:30 15:30-18:30 18:30-19:30 19:30-22:00 22:00-04:00 04:00-06:00 06:00-06:30 Duration 4-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 2hr 4hr 7hr 21 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1/2hr 3hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 3-1/2 hr 8-1/2 hr 7-1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr lhr 2hr 8hr 1-1/2 hr lhr 1/2 hr 6hr 7-1/2 hr 1-1/2 hr 5hr lhr lhr 2hr 1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr 3hr lhr 2-1/2 hr 6hr 2hr 1/2hr Activity Drilled to 11809.00 ft Drilled to 11949.00 ft (cont...) Repaired High pressure lines Drilled to 12012.00 ft Worked toolstring at 12012.00 ft Pulled out of hole to 260.00 ft Pulled BHA Made up BHA no. 12 R.I.H. to 12012.00 ft Drilled to 12416.00 ft Drilled to 13188.00 ft (cont...) Circulated at 13188.00 ft Pulled out of hole to 7000.00 ft Pulled out of hole to 261.00 ft (cont...) Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 13 R.I.H. to 4000.00 ft Serviced Block line R.I.H. to 13188.00 ft Drilled to 13544.00 ft Drilled to 13888.00 ft (cont...) Circulated at 13888.00 ft Pulled out of hole to 9552.00 ft Logged hole with LWD: Formation evaluation (FE) from 9552.00 ft to 10250.00 ft R.I.H. to 13888.00 fl Circulated at 13888.00 ft Pulled out of hole to 261.00 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 3748.00 ft (4-1/2in OD) Ran Drillpipe in stands to 10196.00 ft Circulated at 10196.00 ft Ran Drillpipe in stands to 13807.00 ft Circulated at 13807.00 ft Circulated at 13807.00 ft (cont...) Circulated at 13807.00 ft Held safety meeting Batch mixed slurry - 67.000 bbl Displaced slurry - 67.000 bbl Functioned Permanent packer Reverse circulated at 10059.00 ft Pumped out of hole to 8670.00 ft Circulated at 8670.00 fl Pumped out of hole to 0.00 ft Ran Drillpipe in stands to 3441.00 ft Laid down 3441.00 ft of 3-1/2in OD drill pipe Made up BHA no. 14 R.I.H. to 8670.00 ft R.I.H. to 10059.00 ft (cont...) Facility PBS Pad Progress Report Well S-43 Page 6 Rig Nabors 18E Date 27 August 97 Date/Time 03 Jun 97 04 Jun 97 05 Jun 97 06 Jun 97 07 Jun 97 06:30-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-10:30 10:30-15:00 15:00-21:00 21:00-05:00 05:00-06:00 06:00-07:00 07:00-08:30 08:30-09:30 09:30-13:00 13:00-18:00 18:00-18:30 18:30-20:30 20:30-23:00 23:00-00:00 00:00-05:30 05:30-06:00 06:00-07:00 07:00-11:00 11:00-12:30 12:30-13:00 13:00-14:30 14:30-17:00 17:00-17:30 17:30-04:00 04:00-05:30 05:30-06:00 06:00-08:30 08:30-10:00 10:00-11:00 11:00-14:00 14:00-14:30 14:30-16:00 16:00-19:30 19:30-03:30 03:30-04:30 04:30-06:00 06:00-08:30 08:30-09:00 09:00-10:00 10:00-10:30 10:30-11:00 11:00-13:30 13:30-14:00 14:00-06:00 06:00-07:00 07:00-07:30 Duration 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2hr 4-1/2 hr 6hr 8hr lhr lhr 1-1/2 hr lhr 3-1/2 hr 5hr 1/2hr 2hr 2-1/2 hr lhr 5-1/2 hr 1/2hr lhr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 10-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr lhr 3hr 1/2 hr 1-1/2 hr 3-1/2 hr 8hr lhr 1-1/2 hr 2-1/2 hr 1/2 hr lhr 1/2hr 1/2 hr 2-1/2 hr 1/2 hr 16hr lhr 1/2 hr Activity Circulated at 10059.00 ft Held drill (Kick (well kill)) Tested Casing - Via annulus R.I.H. to 10094.00 ft Drilled cement to 10097.00 ft R.I.H. to 12567.00 ft Laid down 270.00 ft of 3-1/2in OD drill pipe Drilled cement to 12872.00 ft Drilled installed equipment - DV collar Drilled installed equipment - Landing collar Circulated at 12940.00 ft R.I.H. to 13814.00 ft Circulated at 13800.00 ft Laid down 744.00 ft of 3-1/2in OD drill pipe Pulled out of hole to 3971.00 ft Laid down 3791.00 ft of 2-7/8in OD drill pipe Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Wireline units Made up BHA no. 1 Pulled BHA Downloaded MWD tool R.I.H. to 9628.00 ft Logged hole with LWD: Formation evaluation (FE) from 9540.00 ft to 9583.00 ft R.I.H. to 9774.00 ft Serviced Other sub-surface equipment Worked toolstring at 9750.00 ft Tested Downhole equipment - Via annulus and string Milled Casing at 9778.00 ft Circulated at 9778.00 ft Pulled out of hole to 9000.00 ft Pulled out of hole to 262.00 ft (cont...) Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 16 R.I.H. to 9778.00 ft Drilled to 9873.00 ft Circulated at 9873.00 ft Pulled out of hole to 7000.00 ft Pulled out of hole to 239.00 ft (cont...) Pulled BHA Made up BHA no. 17 R.I.H. to 2000.00 ft Serviced Block line R.I.H. to 9711.00 ft Logged hole with LWD: Formation evaluation (FE) from 9774.00 ft to 9811.00 ft Drilled to 10016.00 ft Drilled to 10042.00 ft (cont...) Investigated pressure change Facility PBS Pad Progress Report Well S-43 Page 7 Rig Nabors 18E Date 27 August 97 Date/Time 08 Jun 97 09 Jun 97 10 Jun 97 11 Jun 97 12 Jun 97 13 Jun 97 07:30-12:30 12:30-12:45 12:45-13:00 13:00-13:30 13:30-14:30 14:30-15:00 15:00-18:30 18:30-19:00 19:00-23:00 23:00-00:00 00:00-01:00 01:00-04:00 04:00-04:30 04:30-06:00 06:00-09:30 09:30-10:30 10:30-13:30 13:30-17:00 17:00-03:00 03:00-04:00 04:00-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-22:00 22:00-23:00 23:00-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-06:00 06:00-16:00 16:00-17:30 17:30-21:30 21:30-22:00 22:00-23:00 23:00-02:00 02:00-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-01:00 01:00-01:30 01:30-06:00 06:00-07:30 07:30-09:00 09:00-01:30 Duration 5hr 1/4 hr 1/4 hr 1/2 hr lhr 1/2hr 3-1/2 hr 1/2 hr 4hr lhr lhr 3hr 1/2 hr 1-1/2 hr 3-1/2 hr lhr 3hr 3-1/2 hr 10hr lhr 2hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr lhr lhr 7-1/2 hr lhr 3-1/2 hr 1-1/2 hr 1/2hr 1-1/2 hr lhr 23 hr 10hr 1-1/2 hr 4hr 1/2 hr lhr 3hr 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 17-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 16-1/2 hr Activity Pulled out of hole to 192.00 ft Removed Wear bushing Installed Wear bushing Held safety meeting Rig waited · Downhole fish Made up BHA no. 18 R.I.H. to 9849.00 ft Fished at 9849.00 ft Pulled out of hole to 15.00 ft Laid down fish Made up BHA no. 19 R.I.H. to 9857.00 ft Fished at 9857.00 ft Pulled out of hole to 7000.00 ft Pulled out of hole to 15.00 ft (cont...) Laid down fish Made up BHA no. 20 R.I.H. to 10042.00 ft Drilled to 10414.00 ft Circulated at 10414.00 ft Pulled out of hole to 7000.00 ft Pulled out of hole to 255.00 ft (cont...) Pulled BHA Made up BHA no. 21 R.I.H. to 10340.00 ft Logged hole with LWD: Formation evaluation (FE) from 10340.00 ft to 10414.00 ft Drilled to 10426.00 ft Functioned Drilling tool / logs Drilled to 10765.00 ft Circulated at 10765.00 ft Pulled out of hole to 223.00 ft Pulled BHA Made up BHA no. 22 R.I.H. to 5000.00 ft R.I.H. to 10765.00 ft (cont...) Drilled to 11750.00 ft Drilled to 12069.00 ft (cont...) Circulated at 12069.00 ft Pulled out of hole to 100.00 ft Pulled BHA Rigged up High pressure lines Tested BOP stack Made up BHA no. 23 R.I.H. to 6000.00 ft Serviced Block line R.I.H. to 8000.00 ft R.I.H. to 12069.00 ft (cont...) Drilled to 12452.00 ft Took MWD survey at 12452.00 ft Drilled to 12524.00 ft Drilled to 12705.00 ft (cont...) Circulated at 12705.00 ft Pulled out of hole to 12705.00 ft Facility PBS Pad Progress Report Well S-43 Page 8 Rig Nabors 18E Date 27 August 97 Date/Time 14 Jun 97 15 Jun 97 16 Jun 97 17 Jun 97 18 Jun 97 19 Jun 97 20 Jun 97 01:30-02:30 02:30-04:00 04:00-06:00 06:00-08:00 08:00-19:30 19:30-00:30 00:30-01:00 01:00-02:00 02:00-05:00 05:00-06:00 06:00-08:00 08:00-06:00 06:00-17:00 17:00-18:00 18:00-20:00 20:00-21:30 21:30-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-13:00 13:00-14:00 14:00-14:30 14:30-18:00 18:00-22:30 22:30-01:30 01:30-02:00 02:00-03:30 03:30-06:00 06:00-07:00 07:00-08:30 08:30-13:00 13:00-15:00 15:00-06:00 01:30-03:30 03:30-05:30 05:30-06:00 06:00-09:30 09:30-12:00 12:00-13:00 13:00-14:30 14:30-18:00 18:00-18:30 18:30-22:00 22:00-23:00 23:00-02:00 02:00-03:30 03:30-06:00 06:00-11:00 11:00-13:00 13:00-16:00 16:00-18:00 18:00-19:30 Duration lhr 1-1/2 hr 2hr 2hr 11-1/2 hr 5hr 1/2 hr lhr 3hr lhr 2hr 22 hr llhr lhr 2hr 1-1/2 hr 3hr 2hr 2hr 1-1/2 hr 7hr lhr 1/2hr 3-1/2 hr 4-1/2 hr 3hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 1-1/2 hr 4-I/2 hr 2hr 15hr 2hr 2hr 1/2 hr 3-1/2 hr 2-1/2 hr lhr 1-1/2 hr 3-1/2 hr 1/2hr 3-1/2 hr lhr 3hr 1-1/2 hr 2-1/2 hr 5hr 2hr 3hr 2hr 1-1/2 hr Activity Pulled BHA Made up BHA no. 24 R.I.H. to 6000.00 ft R.I.H. to 12705.00 ft (cont...) Drilled to 12888.00 ft Pulled out of hole to 100.00 ft Pulled BHA Made up BHA no. 24 R.I.H. to 12888.00 fi Took MWD survey at 12713.00 ft Took MWD survey at 12713.00 ft (cont...) Drilled to 13640.00 ft Drilled to 14014.00 ft (cont...) Circulated at 14014.00 ft Drilled to 14061.00 ft Circulated at 14061.00 ft Pulled out of hole to 9740.00 ft R.I.H. to 14000.00 ft Circulated at 14000.00 fi Pulled out of hole to 13300.00 ft Pulled out of hole to 100.00 ft (cont...) Pulled BHA Removed Bore protector Ran Liner to 4161.00 ft (4-1/2in OD) Ran Tubing to 4121.00 ft (2-1/16in OD) Ran Drillpipe in stands to 9750.00 ft Circulated at 9750.00 ft Ran Liner to 13945.00 ft (4-1/2in OD) Circulated at 13945.00 ft Circulated at 13945.00 ft (cont...) Pulled Drillpipe in stands to 9755.00 ft Circulated at 9755.00 ft Pulled Drillpipe in stands to 4161.00 ft Laid down 4120.00 ft of Tubing R.I.H. to 9670.00 ft Logged hole with LWD: Formation evaluation (FE) from 9552.00 ft to 9585.00 ft Took MWD survey at 9731.00 ft Took MWD survey at 9731.00 ft (cont...) Fished at 9753.00 ft Fished at 9753.00 ft Fished at 9753.00 ft Pulled out of hole to 954.00 ft Pulled BHA Tested BOP stack Made up BHA no. 27 R.I.H. to 9749.00 ft Circulated at 9761.00 ft Pulled out of hole to 0.00 ft R.I.H. to 9730.00 ft Fished at 9753.00 ft Pulled out of hole to 900.00 ft Pulled BHA Made up BHA no. 28 Facility Date/Time 21 Jun 97 22 Jun 97 PBS Pad Progress Report Well S-43 Page 9 Rig Nabors 1SE Date 27 August 97 19:30-22:00 22:00-00:00 00:00-06:00 06:00-07:00 07:00-08:00 08:00-09:30 09:30-18:00 18:00-19:00 19:00-20:30 20:30-22:30 22:30-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-07:00 07:00-08:00 08:00-13:00 Duration 2-1/2 hr 2hr 6hr lhr lhr 1-1/2 hr 8-1/2 hr lhr 1-1/2 hr 2hr 2hr 2hr 2hr 1-1/2 hr lhr lhr 5hr Activity R.I.H. to 9808.00 ft Circulated at 9808.00 ft Laid down 6500.00 ft of 3-1/2in OD drill pipe Laid down 9700.00 ft of 3-1/2in OD drill pipe (cont...) Tested Top ram Rigged up Tubing handling equipment Ran Tubing to 6800.00 ft (4-1/2in OD) Installed SCSSSV control line Ran Tubing to 9088.00 ft (4-1/2in OD) Installed Tubing hanger Reverse circulated at 9088.00 ft Set packer at 9089.00 ft with 2800.0 psi Removed BOP stack Installed Xmas tree Installed Xmas tree (cont...) Removed Hanger plug Freeze protect well - 75.000 bbl of Diesel SURVEY REPORT Anadrill Client: BP Exploration Field: Prudhoe Bay Well Name: $-43 Permanent datum MSL Depth measured from KB, 68.1 FT Elevation of kelly bushing 68.1 FT Elevation of drill floor 66.6 FT Elevation of ground level 37.2 FT Magnetic Declination 28.3 DEG Grid Convergence 0.00 DEG Total Correction 28.3 DEG Spud Date: Last Survey Date 5/30/97 TIE IN POINT Measured depth True vertical depth N/S disp (-va for S) E/W disp (-ye for W) 0.00 IrT Inclination 0.00 0.00 FT Azimuth 0.00 0.00 FT Azimuth from rotary table 0.00 FT to the target 47.4 Mir~mum Curvature Method Schlumberger ANADRILL Survey Report 30-MAY-97 Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DL$ Srvy Tool # Depth angle angle length depth sec'don +N/S- +F/W- isplacement (deg/ tool quality (ft) (de~) (deg) (ft) (fi) (fi) (ffl (fi) (ft) (dec~) 10Of) t~pe type 1 0.00 0,00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 0,00 0,00 TIP 2 155.85 0.54 324.40 155.90 155.90 0.09 0.60 -0.43 0.73 324.40 0.35 MWD 6-axis 3 258.85 0.75 326.00 103.00 258.89 0.25 1.55 -1.09 1.89 324.97 0.20 MWD M 4 343.33 0.76 328.10 84.40 343.28 0.44 2.48 -1.69 3.01 325.74 0.03 MWD 6-axis 5 ~152 0.85 ~1~ 91.20 434.47 0.90 3.66 -2.14 4.24 329.67 0.33 MWD 6-axis 6 525.24 0.65 9.80 90.70 525.17 1.66 4.83 -2.18 5.30 335.67 0.37 MWD 6-axis 7 617.58 1.12 30.10 92.40 617.56 2.94 6.13 -1.64 6.34 345.00 0.60 MWD 6-axis 8 712.34 1.28 35.00 94.70 712.24 4.86 7.79 -0.57 7.81 355.81 0.20 MWD 6-axis 9 805.13 1.32 34.20 92.80 805.01 6.91 9.53 0.62 9.55 3.75 0.05 MWD 6-axis 10 897.82 1.30 46.10 92.70 897.69 9.00 11.14 1.98 11.31 10.09 0.29 MWD 6-axis 11 990.01 1.11 62.40 92.20 989.87 10.91 12.28 3.53 12.77 16.03 0.42 MWD 6-axis 12 1083,55 0.80 103,10 93.60 1083.46 12.15 12.55 4.97 13,50 21.59 0.77 MWD 6-axis 13 1175.62 1.43 123,60 92.00 1175.44 12.79 11.77 6.55 13.47 29.10 0.80 MWD 6-axis 14 1269.01 1.76 137.50 93.40 1268.80 13.06 10.07 8.49 13.17 40.14 0.54 MWD 6-axis 15 1364,37 2.12 138,30 95.40 1364.15 13,03 7,67 10,65 13,13 54.25 0.38 MWD 6-axis 16 1457.30 2.36 139.00 92.90 1456.98 12.95 4.94 13.05 13.95 69.26 0.26 MWD 6-axis 17 1550.01 2.73 123.20 92.70 1549.59 13.44 2.29 16.15 16.31 81.92 0.85 MWD 6-axis 18 1644.87 4.75 107.00 94.90 1644.28 15.98 -0.09 21.80 21.80 90.25 2.38 MWD 6-axis 19 1738.09 7.67 98.70 93.20 1736.93 21.82 -2.16 31.64 31.71 93.91 3.27 MWD 6-axis 20 1831.56 10.61 95.70 93.60 1829.33 31.45 -3.98 46.39 48.56 94.88 3.18 MWD 6-axis 21 1924.97 11.53 92.90 93.30 1920.89 43.70 -5.29 64.25 64.47 94.71 1.14 MWD 6-axis 22 2018.89 12.62 92.10 93.90 2012.71 57.56 -6.14 83.88 84.10 94.19 1.11 NM/D 6-axis 23 2113,84 14.32 92,30 94,90 2105,00 73.24 -6.99 105,96 106,19 93,77 1.79 MWD 6-axis 24 2208.27 15.66 89.90 94.50 2196.28 90.92 -7.44 130.40 130.61 93.26 1.56 MWD 6-axis 25 2300.15 15.52 90.90 91.90 2284.80 108.97 -7.61 155.09 155.28 92.81 0.33 MWD 6-axis 26 2392.67 17.10 89.20 92.50 2373.58 128.08 -7.61 181.07 181.23 92.41 1.78 MWD 6.-axis 27 2486.92 18.43 90.40 94.20 2463.28 149.29 -7.52 209.81 209.94 92.05 1.46 MWD 6-axis 28 2581.72 18.74 91.40 94.80 2553.14 171.20 -8.00 240.02 240.15 91.91 0.47 MWD 6.axis 29 2675.45 18.83 91.30 93.80 2641.94 192.94 -8.71 270.21 270.35 91.85 0.10 MWD 6-axis 30 2772.79 18.73 88.80 97.30 2734.06 215.96 -8.74 301.53 301.56 91.66 0.83 MWD 6-axis 31 2865.85 17,50 87,10 93.10 2822,65 237,94 -7,72 330,46 330.55 91,34 1.44 MWD 6-axis 32 2958.25 17.56 87.10 92.30 2910.56 259.33 -6.31 358.22 358.28 91.01 0.07 MWD 6-axis 33 3052.43 18.03 87.90 94.20 3000.25 281.34 -5.06 386.98 387.01 90.75 0.56 MWD 6-axis 34 3076.17 17.92 87.50 23.80 3022.89 286,94 -4,77 394.32 394,35 90,69 0.69 MWD 6-axis 35 3140.40 17.57 88.00 64.20 3084.04 301.85 -4.00 413.87 413.89 90.55 0.59 MWD M 36 3235,11 18,84 56.90 94.70 3174,05 324.14 -3,20 443,45 443,46 90,41 1,37 NNVD 6-axis 37 3266,86 18.85 88.90 31.80 3204,09 331,84 -3.01 453,72 453.73 90,38 0.03 NNVD 6-axis 38 3361.92 18.55 89.80 95.00 3294.05 354.48 -2.66 484.17 484.18 90.31 0.44 MWD 6-axis 39 3454,85 18.21 90.40 93.00 3382.33 376,03 -2.71 513,50 513.50 90,30 0.42 NNVD 6-axis Page 1 ORIGINAL Schlumberger ANADRILL Survey Report 30-MAY-97 Seq Measured Incl Azimu~ Course 'rVD Vertical Displacement Total at Azm DLS Srvy Tool # Depth angle angle length depth sec'don +NJ$- +E/W- isplacement (deg/ tool quality (fi) (deg) (deg) (fi) (fi) (fi) {fi) (fi) (fi) (de~7) 100f) t~pe t~e 40 3547.66 17.90 89,90 92.80 3470.56 397.14 -2,79 542,26 542,26 90.29 0,37 MWD 6-axis 41 3641.45 17.49 90.10 93.70 3559.83 418.10 -2.79 570.74 570.74 90.28 0.44 MWD 6-axis 42 3736.40 17.58 92.70 95.00 3650.42 438.67 -3.49 599.34 599.35 90.33 0.83 MWD 6-axis 43 3829.16 17.34 95.00 92.80 3738.94 457.85 -5.35 627.12 627.14 90.49 0.79 MWD 6-axis 44 3920.56 16.92 95.10 91.40 3826.29 475.98 -7.72 653.94 653.98 90.68 0.45 MWD 6-axis 45 4013.10 16.07 94.20 92.50 3914.51 494.85 -9.97 681.65 681.72 90.84 1.28 MWD 6-axis 46 4106.97 18.12 98.00 93.90 4003.76 514.47 -12.56 710.70 710.81 91.01 0.60 MWD 6-axis 47 4202.02 18.59 90.30 95.00 4093.94 535.32 -14.18 740.53 740.67 91.10 1.95 MWD 6-axis 48 4297.44 18.49 88.90 95.40 4184.39 557.79 -13.97 770.86 770.99 91.04 0.48 MWD 6-axis 49 4392.20 18.57 89.80 94.80 4274.27 580.19 -13.63 800.99 801.11 90.98 0.31 MWD 6-axis 50 4486.13 18.09 90.40 93.90 4363.41 601.88 -13.68 830.52 830.63 90.94 0.55 MWD 6-axis 51 4579.21 17.59 91.30 93.10 4452.03 622.58 -14.10 659.04 859.15 90.94 0.61 MWD 6-axis 52 4672.22 19.15 94.00 93.00 4540.29 643.18 -15.49 888.31 888.44 91.00 1.91 MWD 6-axis 53 4765.66 18.74 94.50 93.50 4628.73 663.94 -17.73 918.58 918.75 91.11 0.47 MWD 6-.axis 54 4859.03 18.21 96.70 93.30 4717.22 683.64 -20.61 948.00 948.22 91.25 0.94 MWD 6-axis 55 4951.28 18.22 98.70 92.30 4804.89 702.44 -23.98 976.65 976.95 91.41 0.01 MWD 6-axis 56 5046.30 17.98 94.90 95.00 4895.19 722.03 -26.96 1006.01 1006.37 91.64 0.64 MWD 6-axis 57 5138.08 18.23 93.70 91.80 49,52.45 741.51 -29.10 1034.46 1034.87 91.61 0.49 MWD 6-axis 56 5232.22 18.12 93.80 94.10 5071.85 761.77 -31.02 1063.75 1064.20 91.67 0.12 MWD 6-axis 59 5325.12 19.23 91.30 92.90 5159.86 782.75 -32.32 1093.45 1093.94 91.69 1.47 MWD 6-axis 50 5426.04 19.03 89.40 100.90 5255.19 806.94 -32.53 1126.52 1126.99 91.65 0.65 MWD 6-axis 61 5521.28 18.88 89.90 95.30 5345.32 829.84 -32.34 1157.47 1157.93 91.60 0.23 MWD 6-axis 62 5614.92 18.93 68.80 93.60 5433.87 852.39 -31.99 1187.80 1188.23 91.54 0.38 MWD 6-axis 63 5708.52 18.86 89.10 93.60 5622.43 875.07 -31.44 1218.10 1218.51 91.48 0.13 MWD 6-axis 64 5804.45 19.01 88.80 95.90 5613.14 898.35 -30.87 1249.22 1249.60 91.42 0.19 MWD 6-axis 65 5897.69 19.13 88.80 93.30 5701.32 921.21 -30.23 1279.69 1280.05 91.35 0.13 MWD 6-axis 66 5992.08 19.18 87.80 94.40 5790.50 944.61 -29.31 1310.65 1310.98 91.28 0.35 MWD 6-axis 67 6086.72 19.04 90.70 94.60 5679.88 957.67 -28.90 1341.61 1341.92 91.23 1.01 MWD 6-axis 68 6180.16 19.06 91.40 93.50 5968.26 989.74 -29.46 1372.12 1372.44 91.23 0.25 MWD 6-axis 69 6274.00 19.33 91.50 93.50 6056.65 1011.90 -30.24 1402.95 1403.28 91.23 0.29 MWD 6-axis 70 6387.02 18.01 64.80 93.00 6144.96 1034.37 -29.34 1432.66 1432.96 91.17 2.71 MWD 6-axis 71 6462.72 17.84 84.70 95.70 6236.02 1087.78 -26.65 1451.99 1462.24 91.04 0.18 MWD 6-axis 72 6556.21 18.12 87.00 93.50 6324.95 1080.37 -24.56 1490.77 1490.98 90.94 0.82 MWD 6-axis 73 6649.62 17.88 88.10 93.40 6413.78 1102.43 -23.33 1519.61 1519.79 90.88 0.45 MWD 6-axis 74 6741.45 17.95 86.90 91.80 6501.13 1124.02 -22.09 1547.82 1547.98 90.82 0.41 MWD 6-axis 75 6834.56 18.25 91.50 93.20 6589.72 1145.58 -21.70 1576.76 1576.91 90.79 1.57 MWD 6-axis 76 6928.64 18.36 94.40 94.00 6678.95 1166.24 -23.22 1606.24 1606.41 90.83 0.97 MWD 6-axis 77 7021.41 18.35 106.30 92.80 6767.07 1183.76 -28.44 1634.84 1535.09 91.00 4.03 MWD 6-axis 78 7113.38 18.23 102.90 92.00 6854.43 1199.38 -35.72 1662.77 1663.15 91.23 1.17 MWD 6-axis 79 7208.16 18.14 102.50 94.80 6944.49 1216.21 -42.23 1691.53 1692.16 91.43 0.16 MWD 6-axis 80 7302.29 18.33 102.00 94.10 7033.87 1233.16 -48.47 1720.41 1721.09 91.61 0.26 MWD 6-axis 81 7397.08 18.01 102.00 94.80 7123.94 1250.27 -54.62 1749.32 1750.18 91.79 0.34 MWD 6-.axis 82 7492.17 17.70 103.50 95.10 7214.46 1266.82 -61.08 1777.76 1778.80 91.97 0.61 MWD 6-axis 83 7584.60 17.59 103.60 92.40 7302.51 1282.40 -67.66 1804.98 1808.25 92.15 0.12 MWD 6-axis 84 7678.22 17.70 102.60 93.50 7391.71 1298.38 -74.09 1832.61 1534.11 92.32 0.34 MWD 6-axis 85 7773.83 17.42 102.80 95.60 7462.85 1314.79 -80.43 1860.75 1862.49 92.48 0.30 MWD 6-.axis 86 7867.95 18.86 101.40 94.10 7572.28 1331.72 -86.56 1659.39 1891.38 92.62 1.60 MWD 6-axis 87 7981.13 19.98 101.30 93.20 7660.17 1349.95 -92.68 1919.78 1922.01 92.76 1.20 MWD 6-axis 88 8056,03 20,30 101,80 g~.gO 7749,27 1369,07 -~9.20 1951,79 1954.31 92,91 0.38 MWD 6-axis 89 8148.91 20.68 101.80 92.90 7836.29 1387.99 -105.85 1983.62 1686.44 93.05 0.41 MWD 6-axis 90 8242.59 20.47 102.70 93.70 7924.01 1406.94 -112.84 2015.80 2018.98 93.20 0.41 MWD 6-axis 91 8337.15 19.95 102.50 94,50 8012,70 1425.56 -119.95 2047.66 2051.17 93.35 0,56 MWD 6-axis 92 6397.27 19.89 102.00 60.20 8069.29 1437.37 -124.31 2087.70 2071.44 93.44 0.30 MWD 6-axis 93 8491.24 20.20 100.40 93.90 8157.51 1456.37 -130.56 2099.27 2103.33 93.56 0.67 MWD 6-axis 94 8523.01 22.78 95.70 31.80 8187.10 1463.68 -132.27 2110.79 2114.93 93.59 9.16 MWD 6-axis 95 6554.74 25.98 92.40 31.70 8215.97 1472.60 -133.27 2123.83 2128.00 93.59 11.54 MWD 6-axis 96 8585.91 28.93 90.20 31.20 8243.65 1452.96 -133.59 2138.20 2142.37 93.57 10.00 MWD 6-axis 97 8618.38 31.54 87.00 32.50 8271.73 1495.28 -133.17 2154.56 2158.67 93.54 9.44 MWD 6-axis Page 2 Schlumberger ANADRILL Survey Report 30-MAY-97 Seq M~asuru~l In¢l ~.imuth Ooume TVD V, rti¢al =ispInc~men~ '!'o1~1 n~Azm DLS Srvy r~I # Depl~ angle angle length del~h .~.~i o n +N/S- +D~.~- isplacernen~ (decj/ I~ol qunli~ I (~c) (de<j) (deg) iff) (it) iff) (ft) (it) (It) (deg) 1000 ~ t)~ae 98 8649.31 33.36 84.10 30.90 8297.80 1508,32 -131.87 2171.08 2175.08 93.48 7.75 MWD 6-axis 99 8680.50 35.12 80.40 31.20 8323.60 1522.72 -129.49 2188.47 2192.29 93.39 8.74 MWD 6-axis 100 8710.99 36.30 79.60 30.50 8348,36 1537.72 -126.40 2206.00 2209,62 93.28 4.16 MWD 6-axis 101 8742.03 37.29 78.80 31.08 8373.19 1553.49 -122.92 2224.24 2227.63 93.16 3.55 MWD 6-axis 102 8772,63 39,62 75.80 30.60 8397.15 1569.99 -118.73 2242.79 2245.93 93.03 9,75 MWD 6-axis 103 8803.59 42.68 73.20 31.00 8420,49 1588,15 -113,26 2262.44 2265.27 92.87 11.31 MWD 6-axis 104 8833.21 45.20 71.00 29,60 8441.81 1606,80 -106.94 2281.98 2264.48 92.68 9,95 MWD 6-axis 105 8864.59 47.28 71.10 31.40 8463,52 1627,57 -99.58 2303.42 2305.58 92.48 6.63 MWD 6-axis 106 8894.57 49.95 70.40 30,00 8483.35 1648.23 -92.16 2324.67 2326.50 92.27 9.07 MWD 6-axis 107 8925.06 53.17 70.00 30.50 8502.31 1670.25 -84.06 2347.15 2348.65 92,05 10.61 MWD 6-axis 108 8957,08 56.55 68,80 32.00 8520.73 1694.51 -74.85 2371.53 2372.81 91.81 11.00 MWD 6-axis 109 8988,99 59.34 67,80 31,90 8537.56 1719,76 -64.65 2396.75 2397.63 91.55 9.14 MWD 6-axis 110 9020.51 61.65 66.20 31.50 8553.17 1745.58 -54.14 2421.98 2422,59 91.28 8,56 MWD 6-axis 111 9052.42 63.03 67.20 31.90 8567.98 1772.24 -42.98 2447.93 2448.31 91.01 5.14 MWD 6-axis 112 9083.95 63.31 65.40 31.50 8582.20 1798.83 -31.67 2473.67 2473.87 90.73 5.18 MWD 6-axis 113 9114.63 64.28 65.70 30,70 8595.76 1825,00 -20.27 2498.74 2498.82 90,45 3.28 MWD 6-axis 114 9145.88 66.03 66.10 31.30 8608.91 1851.93 -8.67 2524.67 2524.68 90.20 5.71 MWD 6-axis 115 9177.09 66.12 66.50 31.20 8621.56 1878.91 2.79 2550.78 2550.78 89.94 1,21 MWD 6-axis 116 9207.39 66,10 65.20 30,30 8633.63 1905.19 14.13 2576,05 2576.10 89.69 3.92 MWD 6-axis 117 9239.16 66.19 64,90 31,80 8646.69 1932.90 26.40 2602.43 2602.58 89.42 0.91 MWD 6-axis 118 9271.08 66,39 64.80 31.90 8659.52 1960.76 38.81 2628.87 2629,15 89.15 0.69 MWD 6-axis 119 9301.32 65,41 65.30 30.20 8671.61 1987.13 50.48 2653.98 2654,44 68.91 1.52 MWD 6-axis 120 9332.59 56,52 64,80 31,30 8684.11 2014.47 62.59 2679,98 2680.71 68.56 1.51 MWD 6-axis 121 9362.26 66.70 63,90 29.70 8695.90 2040.54 74,39 2704.55 2705.57 88.42 2.85 MWD 6-axis 122 9393.96 66.92 62.90 31.70 8708.38 2068,55 87.43 2730.60 2732.00 88.17 2.98 MWD 6-axis 123 9427.67 67.00 63.40 33.70 8721.57 2098.39 101.44 2758.27 2760,14 87.89 1.39 MWD 6-axis 124 9458,60 66,96 63.60 30.90 8733.56 2125.71 114.13 2783,72 2786,05 87,65 0.61 MWD 6-axis 125 9490.20 65.03 62.30 31,60 8745,51 2153.52 127.26 2809,43 2812.31 87.41 7.17 MWD 6-axis 126 9522.06 54,63 62.10 31.90 8760.08 2181.43 140.72 2834.97 2838.46 87.16 1.38 MWD 6-axis 127 9853.35 64.64 63.20 31.20 8773,44 2208.63 153.67 2860,01 2864.14 86.92 3.19 MWD 6-axis 128 9584.66 64.80 53.40 31.40 8756.85 2235.93 165.43 2885.38 2890.17 86.70 0.77 MWD 6-axis 129 9615.74 64,87 63,30 31.00 8800,04 2262.91 179.01 2910.45 2915.95 86.48 0,37 MWD 6-axis 130 9647.66 63,85 64.20 32.00 8813.88 2290.58 191,77 2938,33 2942.58 86.26 4.07 MWD S-axis 131 9678.73 61.23 54,00 31.00 8828.18 2316.93 203,79 2961,07 2968,07 68.06 8,47 MWD 6-axis 132 9709,65 60.70 64.20 31.00 8843.22 2342.88 215.63 2985.45 2993.23 85.87 1.8 MWD 6-axis 133 9741.27 60,53 64,60 31.60 8858,73 2369.21 227.52 3010.28 3018,87 65.68 1,23 MWD 6-axis 134 9772.12 60.54 63,80 30.80 8873.88 2394.68 239,20 3034.42 3043.84 85,49 2.26 MWD 6-axis 135 9804,05 60.37 63,00 32.00 8889,56 2421.64 251,56 3059.32 3069.65 85,30 2,24 MWD 6-axis 136 9835.90 60.81 63.00 31.80 8905.27 2448,32 264,24 3084.00 3095.30 85.10 1,38 MWD 6-axis 137 9866.55 63.50 63.20 30.60 8919.56 2474.36 276.48 3108.13 3120.40 84.92 8.81 MWD 6-axis 138 9899.21 56.92 62.00 32.70 8933.27 2503,00 290.14 3134.48 3147.88 84.71 10.98 MWD 6-axis 139 9930.14 70,23 59.30 30.90 8944.56 2530.99 304,24 3159.54 3174.15 34.50 13.45 MWD 6-axis 140 9961.62 73.15 60.10 31.50 8954.46 2560.21 319.33 3185.36 3201.32 84.28 9.68 MWD 6-axis 141 9993.52 75.29 57.50 31.90 8963.13 2590.29 335.23 3211.61 3229.08 84.04 10.32 MWD 6-axis 142 10026.71 76.01 58,60 33.20 8971.36 2622.00 352.72 3238.60 3257.75 63,78 3.41 MWD 6-axis 143 10059.69 79.35 56.30 33.00 8978.40 2653.63 370.54 3265,46 3286.42 63,63 10.16 MWD 6-axis 144 10090.15 82,33 55.30 ~0.40 8983,24 2683.52 387.41 3290.28 3313.01 63.28 10,33 MWD 6-axis 145 10119.84 84,08 54.70 29.70 8986,75 2712.75 404.32 3314.44 3339.01 63.04 6.22 MWD 6-axis 146 10141.52 85.63 54.90 21.70 8988.70 2734.18 416.78 3332.10 3358.06 82.87 7.2 MWD 6-axis 147 10173.92 88.05 54,20 32.40 8990.48 2766.27 435.54 3368,45 3386.67 82.61 7.77 MWD M S-axis 148 10203.82 87,33 53.50 29.90 8991,69 2795.96 453.17 3382.57 3412.79 82.37 3.38 MWD M 6-axis 149 10235.62 88.70 52.80 31.80 8992,79 2827.58 472,23 3408,00 3440,56 82,11 4.84 MWD 6-axis 150 10268.15 90.70 63.40 32.60 8992.96 2860.01 491.80 3434.07 3469.11 81.85 6.4 MWD M 6-axis 151 10295.49 94.20 54.30 27.30 8991.79 2887.11 507.90 3456.08 3493.20 81.64 13.15 MWD M 6-exis 152 10327.79 97.50 52.50 32.30 8988.50 2919.07 527.10 3481.84 3521.51 81.39 11.62 MWD 6-axis 153 10359.80 97.55 49,60 32.00 8984.31 2950.72 547.07 3506.49 3548.91 81.13 8.68 MWD 6-axis 154 10392.19 94,95 45,30 32,40 8980.78 2982,92 568.63 3530,40 3575.90 80,85 12.92 MWD 6-axis 155 10423.85 91,95 46.00 31.70 8976,88 3014,55 5~0,55 3553,21 3801,96 80,56 9,51 MWD 6-axis Page 3 Schlumberger ANADRILL Survey Report 30-MAY-97 Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azrn DL$ Srvy Tool ~ Depth angle angle length depth section +N/S- +E/W- isplacement (deg/ tool quality (fi) (de<j) (deg) (fi) (fi) (fi) 156 10456.16 89.00 44.90 32.30 8978.61 3046.83 613,21 3576,23 3628.42 80.27 9,75 MWD 6-axis 157 10488.17 86.25 43.10 32.00 8979.93 3078.74 636.20 3598.44 3654.24 79,97 10.27 MWD 66axis 158 10520.02 85.15 39.80 31.80 8982.32 3110.28 659,97 3619.42 3679.10 79.67 10.91 MWD 66axis 159 10551.72 84.60 35.90 31.70 8985.15 3141.41 684.89 3638.79 3702.69 79.34 12,38 MWD 66axis 160 10583.56 84.15 33.40 31.90 8988.28 3172.37 711,01 3656,84 3725,32 79.00 7,93 MWD 66axis 161 10615.19 83.95 33.40 31,60 8991,55 3202.87 737.25 3674,14 3747.38 78.65 0.63 MWD 6-axis 162 10645.63 83,55 33,00 30.40 8994.86 3232,17 762.63 3690.69 3768.64 78.33 1.86 MWD 66axis 163 10677.04 83,20 32.70 31.40 8998.49 3262,36 788.75 3707.59 3790.56 77.99 1.69 MWD M 66axis 164 10709,19 83,10 32.70 32.20 9002.33 3293,27 815.68 3724,81 3813.08 77.65 0,31 IVNVD 66axis 165 10741.04 85,15 31.90 31.80 9005.58 3323,80 642.43 3741.69 3835.35 77.31 6,81 MWD 66axi$ 156 10773.24 64.95 32.30 32.20 9008.36 3354.75 689.61 3768.74 3858.02 76.97 1.38 MVVD 66axis 167 10805.20 65.00 32.30 32,00 9011,16 3385.63 896.65 3775,77 3&50.75 76.64 0,16 MWD 66axi$ 168 10836.93 ~6.90 32.70 31.70 9013.40 3416,08 923,24 3792,74 3903.49 76,32 6.07 MWD 66axis 169 10869,06 87.05 31,90 32.20 9015,10 3447.12 950.43 3809,89 3926.65 75,99 2,22 MWD 66axis 170 10901,47 86.95 32.70 32.40 9016.80 3478,35 977.80 3827.16 3950.09 75.67 2.18 MWD 66axis 171 10933.33 56.90 32,30 31.80 9018.50 3509.04 1004,59 3844.20 3973.29 75,35 0,96 MWD 66axis 172 10965.29 87,20 32,30 32.00 9020.15 3539,89 1031.60 3861.28 3996,71 75.04 0.94 MWD 66axis 173 10997,11 88.65 34.10 31.80 9021,30 3570.70 1058,19 3878.68 4020.43 74.74 7.27 MWD 66axis 174 11028,76 89,95 34.80 31.70 9021,69 3601,co0 1084.33 3896,61 4044.56 74,45 4.66 MWD M 66axis 175 11060.69 90.05 34,80 31.90 9021.69 3632,73 1110.63 3914.81 40~9.28 74.16 0.31 MWD 66axis 176 11092.65 90.15 33,70 32.00 9021,63 3663,89 1136.98 3932.82 4093.87 73.68 3.45 MWD 66axis 177 11124.29 90.15 31,90 31.60 9021.58 3694,47 1163.54 3949.94 4117.75 73.59 5,7 MWD 66axis 178 11156.43 90,20 32,70 32,10 9021.45 3725.46 1193.68 3967,07 4141.90 73.29 2.19 MWD 66axis 179 11188.63 8~,20 31.20 32,40 9021.91 3756,68 1218.19 39~4.19 4166,26 73.00 7.53 MWD 66axis 180 11221,07 86.20 29.40 32,30 9023,48 3787.52 1246.04 4000,46 4193,02 72.70 8,33 MWD 66axis 181 11263.36 86,10 29.40 32.30 9025,65 3818.17 1274,12 4016.28 4213,54 72.40 0.31 MWD 6.axis 182 11285,38 86.05 29.10 32.00 9027.64 3848.50 1301,98 4031.86 4236.87 72.10 1,26 MWD 66axis 163 11317.14 68,00 28.70 31,70 9030.04 3878,45 1329.68 4047.12 4259.95 71.81 0,95 MWD 6-axis 184 11348,97 86.35 28.3 31.9 9032,17 3908.6 1357,65 4062.3 4283,17 71.52 1,66 M1/VD 6-axis 185 11380.77 86.25 28.7 31.8 9034.22 3938.63 1385,54 4077.44 4306.42 71,23 1.29 MWD 6-axis 186 11413.04 86.25 28 32.2 9036.33 3969 1413.82 4092,7 4330.02 70.94 2.17 MWD 66axis 187 11444.76 86,35 28 31.8 9038,38 3998.94 1441.84 4107.6 4353.31 70.66 0,31 MWD 66axi$ 188 11476.61 86.4 30.5 31.8 9040,39 4029.1 1469.53 4123.11 4377.16 70.38 7,85 MWD 66axis 189 11507.91 86.7 33.4 31.3 9042,27 4059.21 1496.03 4139.64 4401,67 70.13 9,3 MWD 66axi$ 190 11558,44 85,6 39,5 50.5 9045,67 4108.66 1536.54 4169.56 4443.67 69.77 12.25 MWD 66axis 191 11590,95 86,45 38,1 32.6 9047.93 4140.81 1561.91 4189.91 4471.57 6~.56 5,28 MWD 6-axis 192 11623.45 89.4 37 32.5 9049.1 4172,8 1567.67 4209.68 4499,12 69,34 9,68 MWD 66axis 193 11654.96 92.55 35.9 31.5 9048.57 4203.72 1613 4228,39 4525.6 69.12 10,59 MWD 66axis 194 11687.04 96,35 34,5 32 9046.08 4234,9 1639.08 4246.76 4552.09 68.9 12,76 MWD 66axis 195 11718.54 98.05 31.2 31.5 9042.13 4265,14 1665.34 4263,68 4577.38 68.66 11,43 MWD 6~axi$ 196 11750,64 99 27.3 32 9037.39 4295.21 1692.95 4279.14 4501,~6 68,41 12,41 MWD 66axis 197 11782.13 99.1 22.6 31.6 9032.42 4324.04 1721.23 4292.3 4624,56 68,15 14,69 MWD 6-axis 198 11814.5 97.35 20 32,4 9027,78 4352,64 1751.11 4303.95 4646.54 67,86 9,6 MWD 66axi$ 199 11846.11 94.55 16.8 31.6 9024.5 4380.33 1780~2 4313.87 4667.03 67.57 13.41 MWD &.axis 200 11876.52 92.6 14.3 30.4 9022.61 4406,1 1810.15 4322 4685.76 67.27 10.42 MWD 66axis 201 11908.09 90.45 11.8 31.6 9021,77 4432.18 1840.92 4329.13 4704,29 68.95 10,43 MWD 6-axis 202 11940.14 90.6 8.2 32 9021,47 4457,61 1872.43 4334,69 4721,81 68.64 11,26 MWD 66axis 203 11971.9 90.95 3.5 31.8 9021.04 4481.4 1904.05 4337.93 ,4737.4 66,3 14.82 MVVD 66axis 204 12003,78 91,5 3,8 31.9 9020.36 4504,45 1935,58 4339,96 4752,14 65.96 1.96 MWD 6-axis 205 12035,81 91.6 3.8 32 9019.5 4527.62 1967.79 4342.08 4767.16 65.62 0.31 MWD 6-axis 206 12068.08 91.7 207 12100.05 91,9 208 12132.3 92 209 12163.88 92.2 210 12196.1 91.5 3.8 32.3 9018.57 4551.01 2000,01 4344.22 4782,49 66.28 0.31 MWD 66axis 3,5 31.9 9017.57 4574.05 2031,83 4346,25 4797,73 64.94 1,13 MWD 66axis 3.5 32.3 9016.47 4597.32 2064.05 4348.22 4813.24 64,61 0,31 MWD 66axis 3.1 31.6 9015.31 4620 2095.56 4350.03 4528,48 54.28 1.41 MWD 6-axis 2 32,2 9014,27 4642.83 2127.73 4351,47 4843.81 63,94 4,05 MWD 66axi$ 211 12228,~4 91.65 212 12260.11 91.$ 213 12293.03 91,85 1,3 32.1 9013.39 4665.23 2159.8 4352,39 4558,81 63,61 2.23MWD 66axi$ 2.4 31.9 9012.$1 4687.56 2191.67 4353.42 4873.98 63.28 3,451VNVD 66axis 1.7 32,9 9011,55 4710.68 2224.54 4354,6 4889.89 62.94 2,38MWD 66axis Page 4 Schlumberger ANADRILL Survey Report 30-MAY-97 Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DL$ Srvy Tool ~ Depth angle angle length depth section +N/S- +E/W- isplacernent (deg/ tool quality (fi) (de!~) (dec~) (fi) (ff1 (fi) (f~) (fi) (ft) (de~) 100f) t~ t~ 214 12324.26 89.95 0.6 31.3 9011,06 4732.33 2255.83 4355,22 4904,77 62.62 7,01 MWD 6-axis 215 12356.05 89,85 0,3 31.8 9011.11 4754.03 2287.62 4355.45 4919.67 62,29 1,3 MWD 6-axis 216 12388.05 89.8 0.3 217 12419.98 89.65 359.9 218 12451.52 89.85 359.9 219 12483.01 89.65 359.9 220 12515.02 89.8 359.9 32 90112.1 4775.78 2319.62 4355.56 4934.73 61,95 0.16 MWD 6-axis 31.9 9011,35 4797.4 2351.52 4355,58 4949,83 61.64 1.05 MWD 6-axis 31.5 5011,5 4818.69 2383.02 4355.53 4964.82 61.32 0.63 MWD 6-axis 31.5 9011.64 4839,98 2414.52 4355.47 4979.97 61 0.63 MWD 6-axis 32 9011.79 4861.6 2446,52 4355.42 4995.51 60.68 0,47 MWD 6-axi~ 221 12547.1 90.15 358.5 222 12578.83 91.25 359.2 223 12610.71 94.15 0,3 224 12642.19 94.7 359.9 225 12674.2 94.8 0.6 32.1 9011.81 4882.99 2478.62 4354,94 5010.9 60.35 4.8 MWD 6-axis 31.7 9011,42 4903,96 2510,31 4354.28 5026.07 60.04 4,29 MWD 6-axis 31.9 9009.92 4925,41 2542.17 4354.11 5041.92 59,72 9.61 MWD 6-axis 31.5 9007,49 4946.69 2573.56 4354.14 5057.65 59.41 1.99 MWD 6-axis 32 9004.84 4968.39 2605.46 4354.28 5074.27 59.11 2,2 MWD 6-axis 226 12705,17 94,8 0.6 227 12737.82 95.15 0,3 228 12769.59 95,15 0.6 229 12801,88 95.2 0.3 230 12833.16 94,05 358.5 32 9002,16 4990,23 2637.35 4354,61 5091 58.8 31.6 8999.42 5011.7 2668.63 4354,83 5107,56 58,5 31,8 8996.56 5033.31 2700.5 4355.05 5124.37 58.2 32.3 8993.65 5055.26 2732.67 4355.28 5141.59 57,89 31.3 8991.13 5076.1 2753.86 4354,9 5157.91 57,6 0 MWD 6-axis 1.68 MWD 6-axis 1.25 MWD 6-axis 1.24 MWD 6-axis 6,81 MWD 6-axis 231 12865.28 93,95 358,1 232 12895,93 93.95 358.8 233 12927.22 93.9 357.7 234 12959.24 94.5 357.7 235 12990.69 94,65 357 32.1 ~968.89 5097.05 2795.87 4353,92 5174.31 57,29 0.98MWD 6-axis 30.6 8986.78 5117.11 2826.39 4353,09 5190,17 57,01 2,28MWD 6-axis 31.3 8984.64 5137,54 2857,6 4352.14 5206.44 56,71 3,51MWD 6-axis 32 8982.29 5156.19 2889.49 4350.86 5222.94 56,41 1.87MWD 6-axis 31,5 8979.78 5178.36 2920.65 4349.41 5239.15 55.12 22.7MWD 6-axis 236 13021,51 94.35 356.3 30,8 8977.36 5197.8 2951.5 4347,61 5254,82 55,83 237 13054,61 94.4 355,6 33.1 8974,84 5218.37 2984.42 4345.28 6271.46 55,52 235 13086.15 94,65 355,9 31.5 8972.35 5237.87 3015,74 4342.95 5287,34 55,22 239 13117.81 94.55 354,9 31.7 8969.81 5257.31 3047.23 4340.39 5303.27 54,93 240 13147,72 94.5 354,5 29,9 8967,45 5275,36 3076.91 4337.61 5318.11 54.65 2,47 MWD 6-axis 2.11 MWD 6-axis 12.4 MWD 6-axis 3,47 MWD 6-axis 1.01 MWD 6-axis 241 13179,67 94.25 353.4 32 8965.01 5294.37 3105,64 4334.25 5333.79 54,35 3.52MWD 6-axis 242 13211.42 91.95 351,3 31.7 8953,29 5312.51 3140.01 4330.04 5348.73 54,05 9.82MWD 6-axis 243 13243.53 88,5 349.5 32.1 8963,17 5329.97 3171.65 4324.66 5353.02 53.74 12.27MWD 6-axis 244 13275,94 65.15 348,4 31,5 8964.91 5346.41 3202.51 4318,6 5376.48 53,44 11.1MWD 6-axis 245 13306.31 84.95 346,9 31.3 8967,61 5362,13 3232.97 4311.93 5389,33 53.14 4.82MWD 6-axis 246 13338.72 84.75 347,7 32.4 8970,52 5378.2 3264.44 4304.81 5402,59 52.83 247 13370,67 34.35 346,9 32 8973.56 5394.07 3295.51 4297.78 5415.84 52.52 248 13402.62 84.2 346,9 31.9 8976.74 5409.71 3326.42 4290,59 5429,02 52.21 249 13434.58 83.95 346,6 32 8980.05 5425.32 3357.41 4253,29 5442.31 51,91 250 13466.43 84,1 346.6 31.8 8983.36 5440.76 3388.17 4275,96 5455,6 51.61 2,24 MWD 6-axis 2,51 MWD 6-axis 0.47 MWD 6-axis 1.22 MWD 6-axis 0.47 MWD 6-axis 251 13498,41 84,15 346.9 32 8986.63 5456.37 3419,16 4268,67 5469.2 51.31 252 13530,65 85.4 348.4 32.3 8989,57 5472.56 3450,58 4261,79 5483.55 51 253 13562,25 85,3 348 31.5 8992.13 5488.67 3481.31 4255.37 5497.97 50.71 254 13594 85.3 347,7 31.8 8994.73 5504,71 3512.29 4248,67 5512,47 50.42 255 13526.14 84,9 347.7 32.1 8997.47 5520.81 3543.52 4241.8 5527.15 50.13 0.95 MWD 6-axis 6,03 MWD 6-axis 1.3 MWD 6-axis 12.5 MWD 6-axis 1.25 MWD 6-axis 256 13657,82 84,5 347,7 31.7 9000.4 5536.7 3574,35 4235.02 5541.79 49.84 257 13689,92 84.6 347.7 32.1 9003.45 5552.78 3605.56 4228.16 5556,75 49.54 258 13721.79 84,3 348 31.9 9006,54 5568.86 3636,59 4221.45 5571.65 49,26 259 13753.56 86.2 347.7 31.8 9009,17 5584,9 3667,57 4214.76 5587,05 48.97 260 13785.09 86,55 347,7 31.5 9011,16 5600.73 3698.27 4208.01 5602.19 48.69 1 2.6 MWD 6-axis 0.31 MWD 6-axis 1,55 MWD 6-axis 6.1 MWD 6-axis 1.11 MWD 6-axis 261 13817.42 86,45 348.7 262 13888.8 86.45 348.7 32.3 9013.13 5817,22 3729.82 4201.39 5618.12 48.4 71,4 9017.55 5654.26 3799.7 4187,42 5654.4 47.78 3.41 MWD 6-axis 0 M Projected Page 5 10/31/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11518 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape S-43 ~ ""~:::~'~"'-4..-/ 97471 CDR&ARC5 970530 1 S-43 ' 97471 I CDR ARC 5 (I ") 970530 1 1 s-43 97471 CD. ^nc 5 (2") ~0~0 ~ ~ S-43 97471 CDR ARC 5 (5") 970530 1 1 S-43 97471 CDR ARC 5 TVD 970530 I 1 .... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECE Vt:u NOV 5 1997 ~ 5S~)~IUv~ bFnrtg; rn aGtFoOnQa ~leA~Ip orr Road ~,,~7 7/31/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11206 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date ElL RF Sepia LIS Tape A- 26 WHIPSTOCK SE'I'I'ING RE~oRD 970604 .... 1 1 ,,, B-23A I PERFORATION RECORD 97061 9 I 1 .,. C-20 TUBING CUT RECORD 970616 I.. 1 1 D-06 A EZSV SET RECORD 970607 I I ,,, H- 15 PERFORATING REcoRD 97061 5 I 1 ..... , . : H - 30 LEAK DETECTION LOG 97061 7 I 1 J- 03 PERFORATE RECORD 970617 I I .... .,. P- 26 PRODUCTION PROFILE 970620 I 1 P-26 DIGITAL ENTRY FLUID TOOL 9 7062 0 1 1 Q-07 .. GAS ENTRY LOG 970609 I 1 .... R-28 GAS LIFT SURVEY 970603 I 1 R-28 PRODUCTION PROFILE 9 70603 1 1 .,, S- 43 PACKER SETTING RECORD 9 70603 1 I ,, , X-07 PRODUCTION LOG 97060 8 I 1 X-31 GAS LIFT SURVEY 970603 1 I .. .. Y-09 'EZSV SET RECORD 97061 0 I I .., ... ... , . ., PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASIO..~IL AND GAS CONSERVATION CO,wMISSION APPLICATION FOR SUNDRY APPROVAL il. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate ' [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Annular Pumping Request 2. Name of Operator BP Exploration (Alaska)Inc. i3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4211' NSL, 4503' WEL, SEC. 35, T12N, R12E, UPM At top of productive interval At effective depth At total depth 5. Type of well: I~ Development I--I Exploratory [] Stratigraphic F-I Service 12. Present well condition summary Datum Elevation (DF or KB) Plan KBE = 66.9' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-43 9. Permit Number 97-52 10. APl Number 50-029-22754 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 3940 feet 3846 feet feet feet Length 110' 3090' Size 20" 9-5/8" Plugs (measured) Junk (measured) 260 sx Arctic Set (Approx.) 150 sx CSIII, 505 sx 'G', 1550 sx CSlll 110' 110' 3121' 3065' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 0RI61NAL 13. Attachments [] Description summary of proposal [] Detailed operations program I--I BOP sketch 4. Estimated date for commencing operation May 13, 1997 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil F-I Gas E~ Suspended Service Name of approver Date approved Contact Engineer Name/Number: Davidl~ramura, 564-,8~06 17. I hereby certify that the fo~/in/~ ~s/t/'uCa~d correct to the best of my knowledge '-~ Signed (/,-,,. \~\( ~ ( ~ Paul K. Prince [ ~~ Title Senior Drilling Engineer Commission Use Only Prepared By Name/Number: Terrie Hubble, 564-4628 Date Conditions of Approval: Notify Commission so representative may witness [Approval No.~ Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity T. est Subsequent form required.10- ¢¢-~;~¢~(:~r Approved by order of the Commission 0rlglRai SIgRed 8y ~eto. ';-/~ ~ommissioner Date~--/ Form 10-403 Rev. 06/15/88 David W. Johnston Submit In Triplicate~' Request to AOGCC for Annular Pumping Approval For S-43 1. Approval is requested for Annular Pumping for well S-43 for disposal activities by AOGCC. . The Base of the Permafrost for all wells located in the PBU Unit is 1947' TVD. Aquifers in the Prudhoe Bay Field Western Operating Area (including K Pad) have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #1 as referenced in Area Injection Order #3. There are no domestic or industrial use water wells located within one mile of the project area. (PBU-WOA). . The receiving zone to which the fluids will migrate is identified as the Tertiary/Cretaceous Sands geological formation at between 3065' TVD to 3597'TVD. The confining layer is the overlying shales above the SV3, defined by the base of the permafrost to 2782'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7/24/95. , . . There are 44 wells on S Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. The drilling wastes to be disposed of during this operations can be defined as drilling mud and cuttings, rig wash~ ~/-"~' ~'' up and waste water, cement wash up water, brine, and formation fluids. The maximum volume to be disposed of in~/ the annulus is 35,000 bbls. The maximum fluid density is 17 ppg. The 9-5/8" casing shoe was set at 3121' MD ~065' T.VD} and cemented with 2205 sacks of cement - cement was brought to surface. This depth is below the base of the permafrost (1947' TVD) and into the SV3 formation which has a long established history of annular pumping at PBU. The break down pressure of the Ugnu formation is 13.5 ppg equivalent mud weight. . . . 10. 11. The burst rating (80%) for the 9-5/8", 40#, L-80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L-80 casing is 4328 psig. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 19,~20 psi for a 17 ppg fluid in this w~-~_ MASP -- 4328 psig - (~.9)~ 0.052~ X 9-5/8" Casing Shoe TVD) The maximum pressu~d atthe surface casir~g shoe is calculated according to the following equation and is 2710 psi for a 17 ppg fluid in this well. Maximum Pressure @ Surface Casing Shoe - Fluid density ppg X 0.052 X 9-5/8" Casing Shoe TVD Pumping into the hydrocarbon reservoir will not occur, l;') ~' Additional data supplied as needed. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. iAREA WELL PREV VOL INJECTED PERMITTED VOL PERMI'I-FED DATES (BBL) (BBL) PBU S-43 0 35000 Submitted for 1997 S-43/L1 Annular Injection Permit Information Page 1 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Johnst~ DATE: May 5, 1997 Chairman Blair Wondzell,'~'~v FILE NO: ainlegef, doc P. I. Supervisor FROM: John Spaulding, .~4A SUBJECT: Petroleum Insp.~''lOa BOPE Test Nabors 18E / BPX / PBU Well S- 4J PTD 97-52 Tuesday May 6, 1997: I traveled to BPX's well S-'q~to witness the BOPE Test on Nabors rig 18E. The AOGCC BOPE Test report is attached for reference. As noted on the Test Report, 1 failure was observed on the blind rams. These were rebuilt and retested, and passed. The rig and surrounding was quite clean and in very good shape. Access to the area is somewhat crowded but adequate. Summary: I witnessed the successful BOPE Test on Nabors 18E- Test time 3.5 hours, 1 failure Attachments: ainlegef, xls X Unclassified Confidential (Unclassified if document removed) Confidential AJ,D T' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Nabors Rig No. 18E PTD # BPX Rep.: s-43 Rig Rep.: Set @ 3,120'md Location: Sec. Weekly Other DATE: 5/6/97 97-52 Rig Ph.# 659-4608 John Raul Bill Bixby 35 T. 12N R. 12E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok · Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign ok Drl. Rig ok Hazard Sec. ok. Quan. Test Press. P/F I 30013,00O P I 500/5,000 P I 500/5,000 P 1 500/5,000 P* I 500/5,000 P 2 500/5,000 P 1 5O0/5,00O P NA MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P 1 500/5,000 P 1 500/5,000 P 1 500/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 500/5,000 P 42 500/5,000 P 2 P Func~oned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 @ 2100 avg 2,950 P 1,400 P minutes 30 sec. minutes 6 sec. yes Remote: yes Psig. TEST RESULTS Number of Failures: 1 ,Test Time: (3.5J Hours. Number of valves tested 27 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Bfind/shear rams failed, will be rebuilt and retested within 24 hours; very good test, rig in excellent shape Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev.12/94) AINLEGEF.XLS TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 27, 1997 Paul Prince Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit S-43 BP Exploration (Alaska) Inc. Permit No: 97-52 Sur. Loc.: 4211'NSL, 4503'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc: 2858'NSL, 229'WEL. Sec. 26, T12N, R12E, UM Dear Mr. Prince: Enclosed is the approved application for permit to drill the above referenced xvell. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance xvith 20 AAC 25.035. Sufficient notice (approximately 24 hours) 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 test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ma~ Marshburn Commissioner BY ORDER OF THE COMMISSION dltTenclosures cc: Department of Fish & Game, Habitat Section w/o enct Department of Envinomment Conservation ~io enci. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil '.la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 66.9' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type BOnd (See 20 AAC 25.025) 4211' NSL, 4503' WEL, SEC. 35, T12N, R12E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4797' NSL, 975' WEL, SEC. 35, T12N, R12E, UPM S-43 At total depth 9. Approximate spud date Amount $200,000.00 2858' NSL, 229' WEL, SEC. 26, T12N, R12E, UPM 04/11/97 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed dep{h (MD and TVD) ADL 047448, 2422'I S-44, 29' away at 1500' MD 2560 14082' MD / 9022' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 1500' Maximum Hole Angle 91.3 ° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-Mod 3120' Surface Surface 3120' 3067' 12osxcslll, 500sx'G', 1865sxCSIII 8-1/2" 7" 26# L-80 BTC-Mod 10216' Surface Surface 10216' 8996' 580 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-Mod/NSCT 4016' 10066' 8978' 14082' 9022' 225 SX Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production ~'% Liner - · 'l4 i997 Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/~umber: D~avid Nakamura, 564-5606 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th¢¢rego~in~g ift~e and correct to the best of my knowledge ~ Signed ~/~..~t ~.. Paul Prince .-~ ' --'----------- Title Senior Drilling Engineer Date - Commission Use Only Per,n~j,t. Number I APl Number I Approval Date I See cover letter ~- ,,~ 50- ¢__J '2~ ~ ~ 2 ,~,,~" ~ ~ ~ ~ ~ ,~;'y for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ~"Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 10M; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IS-43 / S-43L1 Well Plan Summary Type of Well (producer or injector): I Oil Producer Surface Location: 4211' FSL 4503' FEL Sec 35 T12N R12E Start of Horizontal Location: Sadlerochit Zone 4 (lower) Lateral 4797' FSL 975' FEL Sec 35 T12N R12E End of Horizontal Location: 2858' FSL 229' FEL Sec 26 T12N R12E Start of Horizontal Location: Sag River (upper) Lateral 4824' FSL 974' FEL Sec 35 T12N R12E End of Horizontal Location: 2858' FSL 229' FEL Sec 26 T12N R12E I AFE Number: I 4P0755 I Rig: I Nabors 18E Estimated Start Date: I April 11, 1997 I I Operatinll days to complete: I 45 IMD (LL): 14082' MD (UL): 14096' ITVD(LL): I9022' I IRT'GL 129'7' TVD (UL): 8877' I KBE: 66.9' Well Design (conventional, slimhole, etc.) IUltra Slimhole High Angle Multi-Lateral (targeting Sadlerochit Zone 4 and Sag River) Formation Markers: Formation Tops MD TVD (RKB) Base Permafrost 1801' 1800' SV3 2819' 2782' Ugnu 3689' 3607' West Sak 5040' 4887' Kuparuk 6997' 6742' LCU 7055' 6797' Kingak 7914' 7612' J-D 8604' 8264' J-B 9406' 8714' Sag River 9756' 8862' Shublik 9851' 8902' Sad leroc hit 10136' 8992' TD of Sadlerochit Lateral 14082' 9022' Sag Lateral Kickoff 9798' 8879' TD of Sag River Lateral 14096' 8877' S-43 / S-43L1 Permit Info Page I Casin¢l/Tubinq Proqram: Hole Size Csg/ Wt/Ft Grade Conn. Length Top Btm Tb~l O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' Surface 110'/110' 12-1/4" 9-5/8" 40# L-80 BTC- 3120' Surface 3120'/3067' MOD 8-1/2" 7" 26# L-80 BTC- 10216' Surface 10216'/8996' MOD Lower Lateral 6" 4-1/2" 12.6# L-80 I BT- 2193' 10066'/8978' 12259'/9041 ' MOD 6" 4-1/2" 12.6# L-80 NSCT 1823' 12259'/9041' 14082'/9022' Upper Lateral 6" I 4-1/2" 12.6#1 L-80 I NSCTI 4276' I 9820'/8888' I 14096'/8877' Tubin~l I I Logging Program: I Logs: 12-1/4" Hole 8-1/2" Hole 6" Sadlerochit 6" Sa~l River Cased Hole: MWD Directional MWD: GR/Directional MWD: G R/Resistivity/Directional MWD: G R/Resistivity/Directional Optional: CNL/CBT Directional: I KOP: I ~500' Maximum Hole An~lle: Tangent Angle Close Approach Well: 91.3° 30.0° S-44 (29' away at 1500' MD) and S-42 (32' away at 1400' MD) S-43 / S-43L1 Permit Info Page 2 Mud Program: Surface Mud PrOperties: I Surface hole section: SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 8.5 _+ 300 40-60 30-60 50-80 9-10 15-25 Final 9.5 200-300 25-50 15-25 25-40 9-10 15-25 Hazards/Concerns Due to light gravel expectations, no real concerns in surface hole. Intermediate Mud Properties: I Intermediate hole section: LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss Initial 8.8-9.0 35-40 8-12 3-6 8-10 9.0-9.5 8-12 Cretaceous 10.0 40-45 10-12 4-8 8-12 9.0-9.5 6-8 Final 10.0 45-50 12-15 4-8 8-12 9-10 <6 HTHP-13.0 Hazards/Concerns Cretaceous overpressure expected, MW to be at least 10.0 ppg. Utilize hi vis sweeps to assist hole cleaning Monitor LSYP and increase if problems occur trying to clean the hole. Potential high torque could need lubricants (EP MudLube) Reduce APl fluid loss to <6 cc before drilling Kingak Section. If high torque is encountered, respond with lubricants. Note: The Jurassic shales may be troublesome, so treat with 2 ppb Baratrol and 6 ppb Baranex. Sadlerochit Mud Properties: I Production hole section: QUCIKDRILn for Sadlerochit lateral Depth Density Marsh LSRV LSRYP pH (PPG) Viscosity Initial 8.7-8.9 50-65 >45,000 10-20 8.5-9.0 Final 8.8-9.0 50-60 30-40 15-20 8.5-9.0 Hazards/Concerns Lost Circulation a possibility due to overbalance in Sadlerochit. Differential sticking possible with overbalance situation. Perform/report daily checks on KCI concentrations in Xanvis KCI system. High torque may be experienced and should be countered with lubricants (LubeTex) Sag River Mud Pro )erties: I Production hole section: QUCIKDRILn for Sag River lateral Depth Density Marsh LSRV LSRYP pH (PPG) Viscosity Initial 8.7-8.9 50-65 >45,000 10-20 8.5-9.0 Final 8.8-9.0 50-60 30-40 15-20 8.5-9.0 Hazards/Concerns Lost Circulation a possibility due to overbalance in Sag River Differential sticking possible with overbalance situation. Perform/report daily checks on KCI concentrations in Xanvis KCI system. High torque may be experienced and should be countered with lubricants (LubeTex) Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with S-43 / S-43L1 Permit Info Page 3 . . . . . . 9. 10. 11. 12. 13. 14. 15. 16. 17. PROPOSED DRILLING AND COMPLETION PROGRAM WELL: S-43 / S-43L1 MIRU. NU diverter and function test same. Drill 12-1/4" hole to __3120' MD/3067' TVD. Run and cement 9-5/8" 40# L-80 BTC-MOD casing to surface with Halliburton ES Cementer (two stage surface cement job). Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. Test 9-5/8" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed when 20' of new hole has been drilled below the 9-5/8" shoe. Also, perform a well kill drill at this time. Directionally drill 8-1/2" hole to 7" casing point at_+10216' MD/8996' TVD. Run 7" 26# L-80 BTC-MOD casing string and cement with Class G cement to 500' MD above the Ugnu. Test casing to 3,500 psi. The annulus will be freeze protected with dead crude oil. Drill 20' of new 6" hole and test the formation to a minimum of 0.5 ppg over the mud weight to be used to drill the previous hole section. Displace mud system to QUICKDRILn mud system. Directionally drill high angle section with MWD/GR/Resistivity to TD at _+14082' MD/9022' TVD. RIH with 4-1/2", 12.6#, L-80 solid x slotted liner, 4-1/2" ECP, 4-1/2" ES Cementer and 7" x 4-1/2" packer/hanger spaced out for a 150' lap. Cement liner in place with the total cement volume based on 40% excess in open hole, 150' lap and 40' shoe volume. Bump plug. Set and test liner hanger/packer with 3500 psi. RIH with 3-3/4" bit to clean out cement in liner to TD. Displace to seawater. POOH. RIH with 2-3/4" drillpipe conveyed perf guns and perforate 4-1/2" solid liner. POOH and lay down guns. Set 7" x 4-1/2" permanent ML production packer (with 4-1/2" tubing tail) at +9815' MD/8887' TVD (17' MD below the planned top of whipstock). Set oriented, retrievable whipstock above permanent packer so the top of the whipstock window will be at _+9798' MD/8879' TVD. Displace well to QUICKDRILn mud system used to drill lower lateral. Mill window off whipstock at _+9798' MD and drill 29' window/new hole. POOH. RIH with 6" steerable assembly (MWD/GR/Resistivity). Finish kickoff and directionally drill in Sag River, drilling 6" horizontal hole to TD at _+14096' MD/8877' TVD. Run and set a 4-1/2", L-80 slotted liner. Top of liner will be at _+9820' MD/8888' TVD (10' below casing exit/base of whipstock). RIH and pull retrievable whipstock. Run 4-1/2", 12.6 # L-80 IBT-MOD tubing with SSSV, GLMs, and 7" packer assembly. Circulate around freeze protection fluid and corrosion inhibitor. Set packer and test tubing to 4,000 psi. Set TWC and test to 1000 psi. ND BOPE. NU tree and test to 5000 psi. Pull TWC. Test tubing x casing annulus to 3500 psi for 30 minutes. Secure well. Release rig. S-43 / S-43L1 Permit Info Page 4 Drilling Hazards Hydrocarbon-bearing zone in the Ugnu formation. Losses have been encountered drilling the Kingak, Sag RivedShublik and Sadlerochit formations on S Pad. Be prepared for losses near any faults and formation interfaces between the Kingak, Sag River/Shublik and Sadlerochit. A minimum of 10.0 ppg mud weight will be used to drill the Cretaceous injection interval. This will allow a 100 psi trip margin over the expected 9.4 ppg EMW @ 5000' TVDss. Disposal Cuttings Handling: Fluid Handling: Cuttings should be hauled to the ball mill at CC-2A. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cutting from drilling operations to CC- 2A for disposal, except the metal cuttings which will be sent to the North Slope Borough. S-43 / S-43L1 Permit Info Page 5 9-5/8" CASING CEMENT PROGRAM CASING SIZE: 9-5/8" CIRC. TEMP: 38°F FIRST STAGE CEMENT PREFLUSH: 75 bbls viscosified fresh water ahead of lead slurry. LEAD CEMENT TYPE: COLD SET III (accounts for any variance in depth of ES cementer) ADDITIVES: retarder WEIGHT: 12.2 ppg APPROX. # SACKS: 120 TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% A-7 +1 ghs FP-6L WEIGHT: 15.8 ppg APPROX. # SACKS: 500 YIELD: 1.92 ft3/sx MIX WATER: 10.53 gps THICKENING TIME: Greater than 4 hr. @ 50°F YIELD: 1.15 ft3/sx MIX WATER: 4.95 gps THICKENING TIME: Greater than 3-1/2 hr. @ 50°F SECOND STAGE CEMENT PREFLUSH: 75 bbls viscosified fresh water ahead of lead slurry. LEAD CEMENT TYPE: COLD SET III ADDITIVES: retarder - (Add 9 ppb Borax to first 30 bbls (90 sx) of Cold Set III lead cement in second stage) WEIGHT: 12.2 ppg YIELD: 1.92 ft3/sx MIX WATER' 10.53 gps APPROX. # SACKS: +1865 THICKENING TIME: Greater than 4 hr. @ 50°F TOP JOB CEMENT TYPE: COLD SET II (if necessary) ADDITIVES: WEIGHT: 14.5 ppg APPROX. # SACKS: 250 YIELD: 0.96 ft3/sx MIX WATER: 3.89 gps THICKENING TIME: Greater than 2 hr. @ 50°F CENTRALIZER PLACEMENT: 1. Run one (1) bow spring centralizer per joint for the first 15 joints. CEMENT VOLUME: 1. Lead slurry volumes estimated: a. Base of Permafrost to Conductor shoe with 400% excess b. Conductor x Surface Casing annulus (80' MD) c. Cement in surface casing to the ES Cementer at 1800' MD NOTE: With the two stage job, the actual lead cement volumes will be determined by the amount of cement necessary to get lead cement to surface. 2. Tail slurry volume from surface casing shoe to Base Permafrost with 30% excess plus the 80' shoe volume 3. Top job volume 250 sx (if necessary) S-43 / S-43L1 Permit Info Page 6 7" CASING CEMENT PROGRAM CASING SIZE: 7" CIRC. TEMP: 140°F PREFLUSH: 20 bbls fresh water SPACER: 50 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 3% A-2 + 0.4% FL-52 + 0.5% CD-32 + 1 ghs FP-6L WEIGHT: 11.0 ppg YIELD: 3.31 ft3/sx MIX WATER: 20.92 gps APPROX. # SACKS: 320 THICKENING TIME: 5 hrs FLUID LOSS: 150-250 cc/30 minutes FREE WATER: 0 cc TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.1% A-2 + 1.0 ghs FP-6L WEIGHT: 15.8 ppg YIELD: 1.14 ft3/sx MIX WATER: 4.85 gps APPROX. # SACKS: 260 THICKENING TIME: 3-1/2 to 4-1/2 hrs FLUID LOSS: 100-150 cc/30 minutes FREE WATER: 0 cc CENTRALIZER PLACEMENT: 1. Run 1 straight blade rigid centralizer per joint from TD to 500' MD above Sag River. 2. NO CENTRALIZERS TO BE PLACED ACROSS THE 3 STL JOINTS OF 7" CASING. 3. Run 1 straight blade rigid centralizer every joint 300' above and below the Ugnu. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix the lead and tail slurries on the fly. CEMENT VOLUME: 1. Lead slurry to 3189' MD (500' above Ugnu) with 50% excess 2. Tail slurry to 8756' MD (1000' above Sag River) with 50% excess 3. 80' MD 7" 26# capacity for float joints. Note: Hydrocarbon bearing zones are identified in the Ugnu and Sag River intervals. s-43 / S-43L1 Permit Info Page 7 4-1/2" PRODUCTION LINER (LOWER LATERAL) SOLID X SLOTTED CEMENT PROGRAM CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDss PREFLUSH' 20 bbls 2% KCI water SPACER: 50 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight with 2% KCI CEMENT TYPE: CLASS G with 2% KCI ADDITIVES: 175 ghs BA-86L + 2% A-9 + 0.6% CD-32 + 0.3% FL-33 + 0.2% A-2 + 0.5% gel + 1 ghs FP-6L WEIGHT: 15.7 ppg YIELD: 1.19 ft3/sx MIX WATER: 3.43 gps APPROX. # SACKS: 225 THICKENING TIME: 45 min. @ Surface + 3-4 hr. @ 140°F FLUID LOSS: less than 50 cc/30 minutes @ 140°F FREE WATER: 0 cc at 45° angle. CENTRALIZER PLACEMENT: 1. Run 2 right hand turbolators per joint in open hole, 2. Run 1 right hand turbulator per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 50 cc/30 min. or less. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: 1. Open hole (6" X 4-1/2") + 40% excess (adjust if a caliper log is run and it indicates severe washouts). 2. 4-1/2", 12.6# casing capacity below landing collar (80'). 3. 150' liner lap 4-1/2" PRODUCTION LINER (UPPER LATERAL) No cement necessary - slotted liner. S-43 / S-43L1 Permit Info Page 8 SHARED SERVICES DRILLING -- A b-45 tH VERTICAL SECTION VIEW Section at: 47.38 i TVD Sca]e · 1 inch = 1200 feet , Oep Scale · ~ inch = 1200 feet _ ~ ~ -_ ................... ~ ~. ~,~-~-~.~i. os~ -,~o Anadr ~ ] ] $ch ] umberger _L_ o Marker Identification MD BKB SECTN INCLN A) KB 0 0 0 O. O0 B) KOP BUILD ~/tO0 1300 1300 0 0.00 ..... sv3 ~7~ C) BUILD 1.5/~00 1400 1400 ~ 1.00 D) BUILD 2/100 1500 1500 3 2.50 E) END 2/t00 BUILD 1700 1699 14 6.50 F) CURVE 2.5/~00 1900 1898 30 6.50 G) END 2.5/100 CURVE 2383 2369 105 18.57 TO~,UGNU 3607 H) 9-5/8" SURFACE CSG 3120 3067 273 18.57 I) CURVE 8/100 6979 6725 1154 18.57 J) END 8/100 CURVE 7012 6757 1161 18.57 -- K) CURVE 10/I00 8514 8180 1451 18.57 L) END 10/100 CURVE 9018 8550 1737 65.00 i M) CURVE ~0/100 9934 8937 2528 65.00 i N) 7" CASING POINT 10216 8996 2796 90.71 f'~-~i~s' ~A~ 4-8~P O) END ~¢'/'*'* CURVE 10216 8996 2796 90.71 PI CURVE 10/100 10257 8996 2836 90.71 Q) END 10/100 CURVE 10415 8997 2993 88.36 R) TARGET START ~* 10415 8997 2993 88.36 S) CURVE ~0/100 11816 9037 4372 88.36 · T) END 10/~00 ~2259 9041 4738 90.60 U) 4-3/4" LINER POINT 14082 9022 5801 90.60 V) TO 14082 9022 5801 90.60 ~[f_r~Jf ~- r,7 ,:: :~ [, ................ ANA DRILL AKA-E PC ' ~a PPRC)VED I ~:OR PER~iT'tiNG -~.~,~-~ ~ ..... ON .Y r ~,,~r~ ?:F \.l~- c'~"~ '~o- -~s~- .......... ~"~F,~: :~ ..... i .......... :1- _. ~%'~ .... ~ ~'-'"-' '-' '- ' "-' -' ' -'" ~--' ~:""'"" ': :: .... :-I-: s--~:":' -~': ......... "'-": ~"--"~"-'= ~:'-- -' -' '- ' -' -' ' '- -' ' ' -' ............ .... __ 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Section Departure Anadri.l] S£hlumberger H PLAN VIEW CLOSURE · 5801 feet at Azimuth 47.38 DECLINAT SHARED SCALE DRAWN Marker A) KB B) KOP C) BUILD D) BUILD E) END F) CURVE G) END :H) 9-5, I) CURVE J) END K) CURVE L) END M) CURVE O) END P) CURVE O) END RI TARGET S) CURVE T) END U) 4-3/4 V) TO SERVICES DRILLING · ~ inch = 800 feet / ~.~ · 11 Mar ~997 ~- ' ' -- Identification MD N/S E/W ..... ~,~ - o ON oE BUILD 1/~O0 ~300 0 N 0 E~~ LO ~.5/~00 1400 0 S 1E ~,~.,~ LD 2/~00 ~500 0 S ~ E 2/100 BUILD 1700 1S 20 E VE 2.5/100 1900 I S 42 E 2.5/~00 CURVE 2383 4 S 147 E /8" SURFACE CSG 3~20 11S 38~ E ,_ ~E 8/100 6979 45 S 1610 E 8/100 CURVE 7012 46 S 162~ E rE ~0/100 8514 129 S 209~ E 10/100 CURVE 9018 41S 2393 E , rE 10/100 9934 310 N 3150 E - ;ASING POINT 10216 452 N 3383 E 10/100 CURVE 10216 452 N 3383 E ~E 10/100 ~0257 476 N 34~5 E ~0/100 6URVE 10415 587 N 3527 E ~ ~ .... ~ET START ******* ~0415 587 N 3527 E Tu¢ Poin~ (Point) /E ~0/100 ~18~6 ~70~ N 4376 E /4" LINER POINT 14082 3928 N 4268 E 14082 3928 N 4268 E ~ . ,= 400 0 400 800 1200 ~600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 <- WEST' EAST -> (Anadr]]] (c)97 S43P~2 3.0C 2:00 ~M P) ' Wel]i ......... : S-43 (P12) Field ........ : Prudhoe Bay, S-Pad Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.35514443 N Surface Long.: 149.03417336 W Anadrilt Schlumberger Alaska District 1111 East. 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Prepared ..... : 11 Mar 1997 Vert sect az.: 47.38 KB elevation.: 66.90 ft Magnetic Dcln: +28.337 (E) Scale Factor.: 0.99991607 Convergence..: +0.90962002 Legal Description Surface ...... : 4211 FSL 4503 FEL S35 T12N R12E UM Target Start.: 4797 FSL 975 FEL S35 T12N R12E UM Turn Point...: 631 FSL 124 FEL S26 T12N R12E UM BHL.~.TGT End: 2858 FSL 229 FEL S26 T12N R12E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 618929.89 5980414.71 622447.00 5981058.00 623278.00 5982185.00 623135.00 5984410.00 ANADRILL AKA-DPC APPROVED FOR, PERMITTING ONLY PROPOSED WELL PROFILE PLAN , STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM AI~ASKA Zone 4 TOOL DL/ IDENTIFICATION DEPTH ANGLE AZIMUTH TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 ~B 0.00 0.00 0.00 0.00 -66.90 0.00 0.00 ~ 0.00 E 61892~.89 5980414'.71 92R 0.00 KOP BUILD 1/100 1300.00 0.00 91.60 1300.00 1233.10 0.00 0.00 N 0.00 E 618929.89 5980414.71 92R 0.00 BUILD 1.5/100 1400.00 1.00 91.60 1399.99 1333.09 0.63 0.02 S 0.87 E 618930.76 5980414.70 92R 1.00 BUILD 2/100 1500.00 2.50 91.60 1499.95 1433.05 2.81 0.11 S 3.92 E 618933.82 5980414.66 92R 1.50 1600.00 4.50 91.60 1599.75 1532.85 7.19 0.28 S 10.03 E 618939.92 5980414.59 92R 2.00 END 2/100 BUILD EST BASE PERMAFROST CURVE 2.5/100 1700.00 6.50 91.60 1699.29 1632.39 14.06 0.55 S 19.61 E 618949.50 5980414.47 HS 2.00 1801.36 6.50 91.60 1800.00 1733.10 22.28 0.87 S 31.08 E 618960.97 5980414.34 HS 0.00 1900.00 6.50 91.60 1898.00 1831.10 30.28 1.18 S 42.24 E 618972.14 5980414.20 HS 0.00 2000.00 9.00 91.60 1997.08 1930.18 39.94 1.56 S 55.72 E 618985.62 5980414.04 HS 2.50 2100.00 11.50 91.60 2095.48 2028.58 52.69 2.05 S 73.50 E 619003.41 5980413.82 HS 2.50 2200.00 14.00 91.60 2193.00 2126.10 68.51 2.67 S 95.56 E 619025.48 5980413.56 HS 2.50 (Anadrill (c)97 S43P12 3.0C 1:57 PM P) S-43 (P12) 11 Mar 1997 Page 2 PROPOSED WELL PROFILE STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE 2300.00 16.50 END 2.5/100 CURVE 2382.88 18.57 SV3 2818.99 18.57 9-5/8" SURFACE CSG 3119.65 18.57 TOP UGNU 3689.31 18.57 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 91.60 2289.48 2222.58 91.60 2368.50 2301.60 91.60 2781.90 2715.00 91.60 3066.90 3000.00 91.60 3606.90 3540.00 SECTION DEPART 87.36 105.25 204.78 273.40 403.42 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 3.40 S 121.85 E 619051.77 5980413.24 HS 2.50 4.10 S 146.82 E 619076.74 5980412.94 HS 2.50 7.98 S 285.66 E 619215.62 5980411.26 HS 0.00 10.66 S 381.38 E 619311.36 5980410.11 HS 0.00 15.73 S 562.75 E 619492.77 5980407.92 HS 0.00 TOP WEST SAK CURVE 8/100 KUPARUK SAlgDSTONE END 8/100 CURVE 5039.63 18.57 6978.71 18.57 6996.54 18.52 7000.00 18.53 7012.20 18.57 91.60 4886.90 4820.00 711.61 91.60 6725.00 6658,.10 1154.17 96.08 6741.90 6675.00 1158,08 96.95 6745.18 6678.28 1158.80 100.02 6756.75 6689.85 1161.23 27.74 S 992.65 E 619922.77 5980402.73 HS 0.00 45.00 S 1610.00 E 620540.27 5980395.28 94R 0.00 45.38 S 1615.65 E 620545.92 5980394.99 90R 8.00 45.50 S 1616.75 E 620547.02 5980394.88 89R 8.00 46.08 S 1620.58 E 620550.86 5980394.37 HS 8.00 LCU KINGAK CURVE 10/100 TJD 7054.55 18.57 791~.30 18.57 8513.66 18.57 8600.00 25.59 8604.25 25.96 100.02 6796.90 6730.00 1169.41 100.02 7611.90 7545.00 1335.52 100.02 8180.06 8113.16 1451.31 86.46 8260.08 8193.18 1474.17 85.97 8263.90 8197.00 1475.60 48.42 S 1633.86 E 620564.18 5980392.23 HS 0.00 96.05 S 1903.44 E 620834.45 5980348.90 HS 0.00 129.25 S 2091.36 E 621022.87 5980318.68 42L 0.00 130.49 S 2123.57 E 621055,09 5980317.95 30L 10.00 130.37 S 2125.41 E 621056.93 5980318,11 29L 10.00 END 10/100 CURVE CURRRENT GOC TJB SAG RIVER SHUBLIK CURVE 10/100 8700.00 34.60 8800.00 44.00 8900.00 53.58 9000.00 63.25 9018.01 65.00 9235.74 65.00 9406.11 65.00 9756.31 65.00 '9850.95 65.00 9934.01 65.00 77.71 8346.55 8279.65 1515.54 72.28 8423.87 8356.97 1571.69 68.45 8489.70 8422.80 1640.90 65.48 8542.02 8475.12 1721.09 65.00 8549.88 8482.98 1736.51 65.00 8641.90 8575.00 65.00 8713,90 8647.00 65.00 8861.90 8795.00 65.00 8901.90 8835.00 65.00 8937.00 8870.10 1924.58 2071.74 2374.22 2455.98 2527.72 123.09 S 2172.99 E 621104.38 5980326.14 22L 10.00 106.44 S 2233.97 E 621165.08 5980343.76 18L 10.00 81.03 S 2304.65 E 621235.34 5980370.28 15L 10.00 47.63 S 2382.89 E 621313.04 5980404.91 14L 10.00 40.85 S 2397.60 E 621327.64 5980411.93 HS 10.00 42.55 N 2576.45 E 621505.12 5980498.15 HS 0.00 107.80 N 2716.39 E 621644.00 5980565.61 HS 0.00 ' 241.94 N 3004.04 E 621929.46 5980704.28 HS 0.00 278.19 N 3081.78 E 622006.61 5980741.76 HS 0.00 310.00 N 3150,00 E 622074.31 5980774.65 26L 0.00 TSAD / TZ4B 10000.00 70.95 10100.00 80.06 10135.59 83.31 (Anadrill (c)97 S43P12 3.0C 1:57 PM P) 61.93 8961.74 8894.84 2586.47 57.65 8986.75 8919.85 2680.92 56.19 8991.90 8925.00 2715.64 337.35 N 3204.68 E 622128.55 5980802.86 25L 10.00 386.07 N 3288.20 E 622211.27 5980852.89 24L 10.00 405.29 N_3317.70 E 622240.46 5980872.58 24L 10.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN #/z ..... S-43 (P12) 11 Mar 1997 Page 3 STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE 10200.00 89.21 7" CASING POINT 10216.30 90.71 END 10/100 CURVE 10216.30 90.71 CURVE 10/100 10256.55 90.71 10300.00 90.06 END 10/100 CURVE TARGET START ******* CURVE 10/100 END 10/100 4-3/4" LINER POINT TD TZ4A TOP HEAVY OIL/TAR CURRENT OWC TZ3 10400.00 88.58 10414.69 88.36 10414.69 88.36 11815.62 88.36 11815.63 88.36 11900.00 88.75 12000.00 89.25 12100.00 89.77 12200.00 90.30 12258.83 90.60 14082.38 90.60 14082.38 90.60 (Anadrill (c)97 S43P12 3.0C 1:57 PM P) PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 52.95 8996.11 8929.21 52.95 8996.11 8929.21 52.95 8995.61 8928.71 48.66 8995.32 8928.42 SECTION DEPART 2779.33 2795.54 2795.54 2835.60 2878.96 COORDINATES-FROM WELLHEAD 442.23 N 3370.26 E 451.97 N 3383.32 E 451.97 N 3383.32 E 476.22 N 3415.45 E 503.67 N 3449.11 E 38.77 8996.51 8929.61 2978.62 575.86 N 3518.12 E 37,31 8996.90 8930.00 2993.11 587.42 N 3527.17 E 37.31 8996.90 8930.00 2993.11 587.42 N 3527.17 E 37.31 9036.90 8970.00 4371.93 1701.18 N 4376.03 E 37.31 9036.90 8970.00 4371.94 1701.18 N 4376.03 E 28.88 9039.03 8972.13 4453.60 1771.78 N 4422.05 E 18.89 9040.77 8973.87 4545.19 1863.08 N 4462.48 E 8.91 9041.63 8974.73 4628.49 1960.03 N 4486.47 E 358.92 9041.57 8974.67 4700.98 2059.67 N 4493.29 E 353.04 9041.11 8974,21 4737.67 2118.32 N 4489.17 E 9021.90 8955.00 9021,90 8955.00 9041.90 8975.00 9056,90 8990.00 9086.90 9020.00 353.04 353.04 5800.94 5800.94 9161.90 9095.00 3928.35 N 4268.36 E 3928.35 N 4268.36 E ALASKA Zone 4 X Y 622292.42 5980910.34 622305.33 5980920,29 622305.33 5980920.29 622337.06 5980945.05 622370.28 5980973.03 622438.14 5981046.29 622447.00 5981058.00 622447.00 5981058.00 623278.00 5982185.00 623278.00 5982185.00 623322.89 5982256.31 623361.86 5982348.24 623384.31 5982445.55 623389.54 5982545.27 623384.49 5982603.85 623135.00 5984410.00 623135.00 5984410.00 ANADRILL AKA-DPC APPROVED FOR 'PERMITTING ONLY PLAN #_ TOOL DL/ FACE 100 24L 10.00 HS 10.00 HS 10.00 99L 0.00 99L 10.00 98L 10.00 HS 10.00 HS 10.00 HS 0.00 87L 0.00 87L 10.00 87L 10.00 87L 10.00 87L 10.00 HS 10.00 0.00 0.00 WELL PERMIT CHECKLISToo. ,ELD, OOL ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait. ...... iN N N N N N N N N N N N N ENGINEERING ~'----' ~3 PROGRAM: exp[] de~redrln servn wellbore segn ann dtsp para.reqQ GEOL ~A ~;~?,~ u~# //~_C',~ , O./o~F SHORE O,~/ REMARKS 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ,~--~tt 22. Adequate wellbore separation proposed. /~ N 23. If diverter required, is it adequate. .'-'-'-'-'-'-'-'-'k~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. ROPEs adequate ..................... Y~ N 26. BOPE press rating adequate; test to ~O(~ psig. Y N 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 .... Y N/ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: . mom Comments/Instructions: HOWldlf - A:\FORMS\cheklist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. -% To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . *****~****~**~**************~. . ............................ * ....... SCHLUMBERGER ....... . ............................ COMPANY NAME : B.P. EXPLORATION WELL NAME : S-43 FIELD NA2VlE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 50-029-22754-00 REFERENCE NO : 97547 Date_O/- 03- OI * ALASKA COMPUTING CENTER * ....... SCHLUFIBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : S-43 FIELD NAlVlE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22754-00 REFERENCE NO : 97547 LIS Tape Verific~ _mn Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/12/ 2 ORIGIN : FLIC REEL lVAME : 97471 CONTINUATION # : PREVIOUS REEL COMIVlEIVT : B.P. E~iPLORATION, PRUDHOE BAY S-43, API #50-029-22754-00 **** TAPE HEADER **** SERVICE NAFIE : EDIT DATE : 97/12/ 2 ORIGIN : FLIC TAPE NA~E : 97471 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : B.P. EXPLORATION, PRUDHOE BAY S-43, API #50-029-22754-00 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NU~IBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 97471 BROWN WHITELY WELL CASING RECORD 1ST STRING 2ND STRING S-43 500292275400 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 30-0CT-97 BIT RUN 2 BIT RUN 3 35 12N 12E 68.10 66.60 37.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3121.0 6.000 7.000 10196.0 LIS Tape Verific~ 3n Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 3RD STRING PRODUCTION STRING THIS DATA IS FROM THE ORIGINAL HOLE DRILLED ON S-43 BEFORE THE LATERAL. THE WELL WAS DRILLED FROM 10-MAY TO 30-MAY-97 IN 7 BIT RUNS. RUNS 1 & 2 WERE WITH CDR, AND RUNS 3 TO 7 WERE WITH ARCS. NO DEPTH SHIFTS WERE MADE AS PER TROY WEISS. THE RP CURVE IN THE EDITED FILE CONSISTS OF THE CDR PSR AND THE ARC5 P28H SPLICED TOGETHER. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER : 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMEI~T : 0.5000 FILE SU~VARY LDWG TOOL CODE START DEPTH STOP DEPTH I4WD 8411 o 0 13888.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD ....... BIT RUN NO. MERGE TOP MERGE BASE 1 8411.0 1 9420.0 3 10167.0 4 10326.0 5 11534.0 6 11976.0 7 13155.0 11976.0 13155 0 10361 0 11568 0 12012 0 13188 0 13888 5 LIS Tape Verific= -un Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: REMARKS: THIS IS THE MERGED CLIPPED DATA FROM THIS WELL. THE FIRST TWO RUNS WERE WITH CDR, AND RUNS 3 - 7 WERE WITH ARCS. NO DEPTH SHIFTS WERE MADE TO THIS DATA AS PER TROY WEISS OF BP. THIS FILE CONTAINS BOTH THE PHASE SHIFT AND ATTENUATION CURVES FROM THE ARC5 USING THE LDWG F~UEMONICS AS SUPPLIED BY DAVE DOUGLAS. THE RP CURVE IN THIS FILE IS ACTUALLY THE CDR PSR AND THE ARC5 P28H CURVE MERGED TO ONE CONTINUOUS CURVE AS PER DAVE DOUGLAS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ~Ft~4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELAT~ CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 ROP M!WD F/HR O0 000 O0 0 1 1 ! 4 68 0000000000 FET ~WD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR ~WD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RP ~gW-D 0H~94 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~4~ O0 000 O0 0 1 1 1 4 68 0000000000 RPX3fMWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OH~4 O0 000 00 0 1 1 1 4 68 0000000000 RPS MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verific~ .3n Listing Schlumberger Alaska Computing Ce~uter 2-DEC-1997 09:21 PAGE: 4 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) RPD MWD OHI~I O0 000 O0 0 1 1 1 4 68 0000000000 RAXXMWD Ot{F~I O0 000 O0 0 1 1 1 4 68 0000000000 RAX ~fWD O}~I O0 000 O0 0 1 1 1 4 68 0000000000 RAS MWD OHM~ O0 000 O0 0 1 1 1 4 68 0000000000 RAM MWD OP~4~I O0 000 O0 0 1 1 1 4 68 0000000000 RAD MWD O~ O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13888.500 ROP.MWD 159.292 FET.MWD -999.250 GR.MWD -999.250 RP.MWD -999.250 RA.MWD -999.250 RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM.MWD -999.250 RPD.MWD -999.250 RAXX.MWD -999.250 RAX.MWD -999.250 RAS.MWD -999.250 RAM. MWD -999.250 RAD.MWD -999.250 DEPT. 13000.000 ROP.MWD 45.687 FET.MWD 0.908 GR.MWD 37.092 RP.MWD 10.820 RA.MWD -999.250 RPX~.MWD 7.531 RPX.MWD 9.470 RPS.MWD 10.693 RPM. MWD 10.820 RPD.MWD 10.695 RAX~.MWD 4.510 RAX.MWD 8.967 RAS.MWD 12.806 RAM. MWD 11.519 RAD.MWD 9.682 DEPT. 12000.000 ROP.MWD 180.021 FET.MWD 0.122 GR.MWD 18.547 RP.MWD 9.440 RA.MWD -999.250 RPXX.MWD 5.791 RPX.MWD 7.301 RPS.MWD 8.651 RPM. MWD 9.440 RPD.MWD 9.891 RAXX.~ 4.343 RAX.MWD 7.951 RAS.MWD 10.310 RAM.f4WD 9.374 RAD.MWD 8.235 DEPT. 11000.000 ROP.MWD 189.567 FET.MWD 0.694 GR.MWD 28.751 RP.MWD 4.316 RA.MWD -999.250 RP}Of. MWD 3.524 RPX.MWD 3.966 RPS.MWD 4.259 RPM. MWD 4.316 RPD.MWD 4.291 RAIOf. MWD 2.870 RAX.MWD 4.250 RAS.MWD 4.904 RAM.MWD 4.767 RAD.MWD 4.466 DEPT. 10000.000 ROP.MWD 16.187 FET.MWD -999.250 GR.MWD 168.065 RP.MWD 378.558 RA.MWD 46.308 RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD -999.250 RPD.MWD -999.250 RAXX.MWD -999.250 RAX.~ -999.250 RAS.MWD -999.250 RAM.MWD -999.250 RAD.MWD -999.250 DEPT. 9000.000 ROP.MWD 31.306 FET.MWD -999.250 GR.MWD 109.030 RP.MWD 3.793 RA.~WD 2.825 RP~.MWD -999.250 RPX.MWD -999.250 RPS.~'~ -999.250 RPM. MWD -999.250 RPD.MWD -999.250 RAXX.MIWD -999.250 tLn~.!~ -999.250 RAS.~FD -999.250 RAM.I,~D -999.250 RAD.~TD -999.250 DEPT. 8411.000 ROP.MWD -999.250 FET.MI'~ -999.250 GR.MWD 116.066 RP.~KTD -999.250 RA.AKTD -999.250 RPXX.~'~ -999.250 RPX.MI, FD -999.250 RPS.MWD -999.250 RPM.;~WD -999.250 RPD.~D -999.250 RAXX.MWD -999.250 RAX.MWD -999.250 RAS.MWD -999.250 RAM.~'~ -999.250 RAD.MI~D -999.250 ** END OF DATA ** LIS Tape Verific~ ~on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lVUFIBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMFL%RY VENDOR TOOL CODE START DEPTH STOP DEPTH 8410.5 9459.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINI~FJM ANGLE: MAXI~FUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ 30-MAY-97 V5 R24 _ 5.OB MEMORY 13888.0 8410.5 13888.0 20.0 65.0 TOOL NUMBER CDR-7027 LIS Tape Verific~__on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : 8.500 3121.0 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 I~EASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TE~IPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 8.80 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: CDR RUN ON RUNS 1,2 ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG @ 13888' CDR RUN IN 8.5" HOLE ARC5 RUN IN 6" HOLE WELL IS ORIGINAL COMPLETION DATA AIERGED IN FIELD DATA FROM DOWNHOLE ~EMORY, V5. OB SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 7 TYPE REPR CODE VALUE 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~ O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~iM O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9459.000 ROPS.LW1 ATR.LW1 -999.250 DEPT. 9000. 000 ROPS.LW1 ATR. LW1 2. 825 DEPT. 841 O. 500 ROPS. LW1 ATR. LW1 1. 251 14. 354 GR. LW1 31.306 GR.LW1 -999.250 GR.LW1 -999.250 PSR.LW1 -999.250 109.030 PSR. LW1 3 . 793 115.206 PSR.LW1 1.174 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O0!CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: **** FILE HEADER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPIBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUFIBER: 2 DEPTH INCRE~IENT: 0.5000 FILE SD?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9420.0 10207.0 LOG HEADER DATA DATE LOGGED: 30-MAY-97 SOFTWARE: SURFACE SOFTWARE VERSION: V5 R24 DOWNHOLE SOFTWARE VERSION: 5. OB DATA TYPE (FIEMORY or REAL-TIM~) : MEMORY Ti) DRILLER (FT): 13888.0 TOP LOG INTERVAL (FT) : 8410.5 BOTTOM LOG INTERVAL (FT) : 13888.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: 20. 0 MAXIMUM ANGLE: 65.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE ~VD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE COALITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : TOOL NUMBER CDR-7027 8.500 3121.0 LSND 8.80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE FLUID LOSS (C3): RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF): MUD AT M~ASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: CDR RUN ON RUNS 1,2 ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG ® 13888' CDR RUN IN 8.5" HOLE ARC5 RUN IN 6" HOLE WELL IS ORIGINAL COMPLETION DATA M~RGED IN FIELD DATA FROM DOWNHOLE ~EMORY, VS. OB SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 10 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUPIB NTJM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELb~4 CODE (HEX) DEPT FT O0 000 O0 0 3 i 1 4 68 0000000000 ROP5 LW2 F/I{R O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OHI~ O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHIO4 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10207.000 ROPS.LW2 49.600 GR.LW2 -999.250 PSR.LW2 ATR. LW2 - 999. 250 DEPT. 10000. 000 ROPS.LW2 16.187 GR.LW2 168. 065 PSR.LW2 ATR. LW2 46. 308 DEPT. 9420. 000 ROPS.LW2 -999. 250 GR.LW2 130. 600 PSR.LW2 ATR. LW2 - 999. 250 -999.250 378.558 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01COi DATE : 97/12/ 2 F~tXREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE hi]FiBER 4 RAW MWD Curves and log header data for each bit run in separate files. LIS Tape Verificau~.on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 11 BIT RUN NUlV~ER: 3 DEPTH INCREMFJV~: 0.5000 FILE SUf4MARY VENDOR TOOL CODE START DEPTH MWD 10167.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or ~-TIFIE) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10361.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OA~V~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT ~%X CiRCULATIONG T~4PERATURE : ~%qID FILTP~ATE AT (MT): ~.FUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) REMARKS: CDR RUN ON RUNS 1,2 30-MAY-97 V5 R24 _ 5.OB MEMORY 13888.0 8410.5 13888.0 20.0 65.0 TOOL N73M~ER ARC5 - 63 8.500 3121.0 LSND 8.80 20000 LIS Tape Verifica_~-mn Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 12 ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG @ 13888' CDR RUN IN 8.5" HOLE ARC5 RUN IN 6" HOLE WELL IS ORIGINAL COMPLETION DATA ~RGED IN FIELD DATA FROM DOWNHOLE M~4ORY, VS.0B SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 1i 66 18 12 68 13 66 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 ROP5 L~ F/HR O0 000 O0 0 4 1 1 4 68 0000000000 TABR LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 PiOH LW3 OP2~4 O0 000 O0 0 4 1 1 4 68 0000000000 P16H LW3 0P24~l O0 000 O0 0 4 1 1 4 68 0000000000 P22H LW3 0_%743~ O0 000 O0 0 4 1 1 4 68 0000000000 P28H LW3 0P24~I O0 000 O0 0 4 1 1 4 68 0000000000 P34H LW3 OH~ O0 000 O0 0 4 1 1 4 68 0000000000 AiOH LW3 OH~ O0 000 O0 0 4 1 1 4 68 0000000000 A16H LW3 OH~I O0 000 O0 0 4 1 1 4 68 0000000000 A22H LW3 0P24~ O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verifica~_on Listing Schlumberger Alaska Computing Center 2-DEC-I997 09:21 PAGE: 13 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE (HEX) A28H LW3 OP~f O0 000 O0 0 4 1 1 4 68 0000000000 A34H LW3 OH~ O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10361.000 ROP5.LW3 24.510 TABR.LW3 -999.250 GR.LW3 PiOH. LW3 -999.250 P16H. LW3 -999.250 P22H. LW3 -999.250 P28H.LW3 P34H.LW3 -999.250 AiOH. LW3 -999.250 A16H. LW3 -999.250 A22H. LW3 A28H. LW3 -999.250 A34H. LW3 -999.250 DEPT. 10167. 000 ROP5.LW3 -999.250 TABR.LW3 -999.250 GR.LW3 PiOH.LW3 -999.250 P16H. LW3 -999.250 P22H.LW3 -999.250 P28H.LW3 P34H. LW3 -999.250 AIOH. LW3 -999.250 A16H. LW3 -999.250 A22H. LW3 A28H. LW3 - 999. 250 A34H. LW3 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE ~H3~,IBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREFIENT : 0.5000 LIS Tape Verifica~_~n Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 14 FILE SD?4FLARY VENDOR TOOL CODE START DEPTH MWD 10326.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (f4E~ORY or REAL-TIllS): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11568.0 30-MAY-97 V5 R24 _ 5. OB MEMORY 13888.0 8410. 5 13888.0 20.0 65.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... ARC5 RESIST./GR $ TOOL NUMBER ........... ARC5 - 63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 3121.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPlV~4) AT TEMPERATURE (DEGF): MUD AT MEAS~ TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): ~JD CAKE AT (MT): LSND 8.80 NEUTRON TOOL MATRIX: ~4ATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): E~ FREQUENCY (HZ): 20000 REMARKS CDR RUN ON RUNS 1,2 ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG @ 13888' CDR RUN IN 8.5" HOLE LIS Tape Verifica~_on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 15 ARC5 RUN IN 6" HOLE WELL IS ORIGINAL COMPLETION DATA ~ERGED IN FIELD DATA FROM DOWN-HOLE MEMORY, V5. OB SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUMB AUtC4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 ROP5 LW4 F/HR O0 000 O0 0 5 1 1 4 68 0000000000 TABR LW4 HR O0 000 O0 0 5 1 1 4 68 0000000000 GR LW4 GAPI O0 000 O0 0 5 1 1 4 68 0000000000 PlOH LW4 OH~f O0 000 O0 0 5 1 1 4 68 0000000000 P16H LW4 OH~4 O0 000 O0 0 5 1 1 4 68 0000000000 P22H Lrw4 Ot~W24 O0 000 O0 0 5 1 1 4 68 0000000000 P28H LW4 OH~4~f O0 000 O0 0 5 1 ! 4 68 0000000000 P34H LW4 Oh2VE~ O0 000 O0 0 5 1 1 4 68 0000000000 AiOH LW4 0P2~4 O0 000 O0 0 5 1 1 4 68 0000000000 A16H LW4 OH~ff4 O0 000 O0 0 5 1 1 4 68 0000000000 A22H LW4 OPk~J O0 000 O0 0 5 1 1 4 68 0000000000 A28H LW4 OH~I O0 000 O0 0 5 1 1 4 68 0000000000 A34H LW4 OHI~I O0 000 O0 0 $ 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 16 ** DATA ** DEPT. 11568. 000 ROP5.LW4 94. 858 TABR.LW4 -999.250 GR.LW4 P1 OH. LW4 -999 . 250 P16H. LW4 -999 . 250 P22H. LW4 -999 . 250 P28H. LW4 P34H. LW4 -999.250 AIOH.LW4 -999c250 A16H.LW4 -999.250 A22H.LW4 A28H. LW4 -999.250 A34H. LW4 -999.250 DEPT. 11000. 000 ROP5.LW4 189. 567 TABR.LW4 O. 694 GR.LW4 PIOH. LW4 3.524 P16H.LW4 3.966 P22H. LW4 4.259 P28H. LW4 P34H.LW4 4.291 AiOH.LW4 2. 870 A16H. LW4 4.250 A22H.LW4 A28H.LW4 4. 767 A34H. LW4 4. 466 DEPT. 10326. 000 ROPS. LW4 -999. 250 TABR. LW4 -999. 250 GR. LW4 PIOH.LW4 -999.250 P16H. LW4 -999.250 P22H. LW4 -999.250 P28H. LW4 P34H. LW4 -999.250 AiOH. LW4 -999.250 A16H. LW4 -999.250 A22H.LW4 A28H. LW4 -999.250 A34H.LW4 -999.250 -999.250 -999.250 -999.250 28.751 4.316 4.904 23.204 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NO?4BER 6 RAW~KWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMYzARY LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 17 LOG HEADER DATA VENDOR TOOL CODE START DEPTH ........................... 11534.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (31EblORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH .......... 12012.0 30-MAY-97 V5 R24 5. OB lVlE~ORY 13888.0 8410.5 13888.0 20.0 65.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ TOOL NUMBER ARC5 - 63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 3121.0 BOREHOLE COArDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHb~l) AT TEblPERATURE (DEGF): MUD AT MEASURED TEbIPERATURE (MT): MUD AT MAX CIRCULJ~TIONG TEblPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 8.80 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST~¥DOFF (IN): Er~R FREQUENCY (HZ): 20000 RE2~KS : CDR RUN ON RUNS 1,2 ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG @ 13888' CDR RUN IN 8.5" HOLE ARC5 RUN IN 6" HOLE LIS Tape Verificau=on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 18 WELL IS ORIGINAL COMPLETION DATA FIERGED IN FIELD DATA FROM DOWNHOLE MEMORY, VS. OB SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 6 1 1 4 68 0000000000 ROP5 LW$ F/HR O0 000 O0 0 6 1 1 4 68 0000000000 TABR LW5 HR O0 000 O0 0 6 1 1 4 68 0000000000 GR LW5 GAPI O0 000 O0 0 6 t 1 4 68 0000000000 PiOH LW5 OPh~2~ O0 000 O0 0 6 1 ! 4 68 0000000000 P!6H LW5 OH~4 O0 000 O0 0 6 1 i 4 68 0000000000 P22H LW5 OP~ O0 000 O0 0 6 1 1 4 68 0000000000 P28H LW5 OPH4M O0 000 O0 0 6 1 1 4 68 O00000000O P34H LW5 OP~4~ O0 000 O0 0 6 1 1 4 68 0000000000 AIOH LW5 OHMM O0 000 O0 0 6 1 1 4 68 0000000000 A16H LW5 OH~M O0 000 O0 0 6 1 1 4 68 0000000000 A22H LW5 OH~I O0 000 O0 0 6 1 1 4 68 0000000000 A28H LW5 0~4~I O0 000 O0 0 6 1 1 4 68 0000000000 A34H LW5 OHT~I O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape VerificatiOn Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 19 ** DATA ** DEPT. 12012.000 ROPS.LW5 PiOH. LW5 -999.250 P16H. LW5 P34H. LW5 -999.250 AIOH.LW5 A28H. LW5 -999.250 A34H.LW5 DEPT. 12000.000 ROPS.LW5 PIOH. LW5 -999.250 P16H.LW5 P34H. LW5 -999.250 AiOH.LW5 A28H. LW5 -999.250 A34H. LW5 DEPT. 11534.000 ROPS.LW5 PiOH. LW5 -999.250 P16H.LW5 P34H. LW5 -999.250 AIOH.LW5 A28H.LW5 -999.250 A34H. LW5 237.586 TABR.LW5 -999.250 P22H. LW5 -999.250 A16H. LW5 -999.250 180. 021 TABR. LW5 -999. 250 P22H. LW5 -999 ~ 250 A16H. LW5 -999.250 -999.250 TABR.LW5 -999~250 P22H. LW5 -999.250 A16H.LW5 -999.250 -999.250 GR.LW5 -999.250 P28H. LW5 -999.250 A22H.LW5 -999.250 GR.LW5 -999.250 P28H.LW5 -999.250 A22H. LW5 -999.250 GR.LW5 -999.250 P28H.LW5 -999.250 A22H. LW5 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 18.812 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVt~BER 7 RAW ~K~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11976.0 13188.0 LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 2-DBC-1997 09:21 PAGE 2O $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIM~) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 'TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RF3~iARKS : 30-MAY-97 V5 R24 _ 5. OB MEMORY 13888.0 8410.5 13888.0 20.0 65.0 TOOL NUF~ER ........... ARC5 - 63 8.500 3121.0 LSND 8.80 20000 CDR RUN ON RUlqS 1,2 ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG @ 13888' CDR RUN IN 8.5" HOLE ARC5 RUN IN 6" HOLE WELL IS ORIGINAL COMPLETION DATA f4ERGED IN FIELD DATA FROM DOWNHOLE FZEMORY, VS. OB SOFTWARE LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 21 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP EL~ CODE (HEX) ....................................................................................... O0 000 O0 0 7 1 1 4 68 0000000000 DEPT FT ROP5 LW6 F/HR O0 000 O0 0 7 1 1 4 68 0000000000 TABR LW6 HR O0 000 O0 0 7 1 1 4 68 0000000000 GR LW6 GAPI O0 000 O0 0 7 1 1 4 68 0000000000 PiOH LW6 OH~M O0 000 O0 0 7 1 1 4 68 0000000000 P16H LW6 OHM~ O0 000 O0 0 7 1 1 4 68 0000000000 P22H LW6 0~4 O0 000 O0 0 7 1 i 4 68 0000000000 P28H LW6 OI-Dgvl O0 000 O0 0 7 1 1 4 68 0000000000 P34H LW6 0~,~4 O0 000 O0 0 7 1 1 4 68 0000000000 AiOH LW6 OHlVl~ O0 000 O0 0 7 1 ! 4 68 0000000000 A!6H LW6 O~l O0 000 O0 0 7 1 2 4 68 0000000000 A22H LW6 0~2~4 O0 000 O0 0 7 ! 1 4 68 0000000000 A28H LW6 0~%1i4 O0 000 O0 0 7 ! 1 4 68 0000000000 A34H LW6 OH~I O0 000 O0 0 7 1 ! 4 68 0000000000 ** DATA ** LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 22 DEPT. 13188.000 ROP5.LW6 PIOH. LW6 -999.250 P16H. LW6 P34H. LW6 -999.250 AIOH. LW6 A28H. LW6 -999.250 A34H. LW6 DEPT. 13000.000 ROP5.LW6 PiOH~LW6 7.531 P16H. LW6 P34H.LW6 10.695 AiOH. LW6 A28H. LW6 11.519 A34H.LW6 DEPT. 12000.000 ROPS.LW6 PiOH. LW6 5.791 P16H. LW6 P34H. LW6 9.891 AiOH. LW6 A28H. LW6 9.374 A34H. LW6 DEPT. 11976.000 ROPS.LW6 PiOH. LW6 -999.250 P16H. LW6 P34H. LW6 -999.250 AiOH. LW6 A28H. LW6 -999.250 A34H. LW6 37.896 TABR.LW6 -999.250 P22H.LW6 -999.250 A16H. LW6 -999.250 45.687 TABR.LW6 9.470 P22H. LW6 4.510 A16H. LW6 9.682 -999.250 TABR.LW6 7.301 P22H.LW6 4.343 A16H.LW6 8.235 -999.250 TABR.LW6 -999.250 P22H. LW6 -999.250 A16H. LW6 -999.250 -999.250 GR.LW6 -999.250 P28H.LW6 -999.250 A22H.LW6 0.908 GR.LW6 10.693 P28H.LW6 8.967 A22H. LW6 0.122 GR.LW6 8.651 P28H.LW6 7.951 A22H.LW6 -999.250 GR.LW6 -999.250 P28H. LW6 -999.250 A22H. LW6 -999.250 -999.250 -999.250 37. 092 10. 820 12.806 18.547 9.440 10.310 14.423 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 8 RAW ~ Curves and log header data for each bit run in separate files. BIT RUN NUM~ER: 7 DEPTH INCREMENT: 0.5000 LIS Tape Verificau~on Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 23 FILE SUMFiARY VENDOR TOOL CODE START DEPTH MWD 13155.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (BiEMORY or REAL-TIF~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13888.5 30-MAY-97 V5 R24 _ 5. OB MEMORY 13888.0 8410.5 13888.0 20.0 65.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ TOOL NUMBER ARC5 - 63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 3121.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 8.80 NEUTRON TOOL ;<ATRIX : ~,iATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA~,~OFF (IN) EWR FREQUENCY (HZ) 20000 R~4ARKS : CDR RUN ON RUNS 1,2. ARC5 RUN ON RUNS 3 - 7 HOLE ANGLE AT TD = 99.1 DEG @ 13888' CDR RUN IN 8.5" HOLE LIS Tape VerificaLxon Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 24 ARC5 RUN IN 6" HOLE WELL IS ORIGINAL COMPLETION DATA lViERGED IN FIELD DATA FROM DOWNHOLE MEMORY, VS.0B SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O.S 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 8 1 1 4 68 0000000000 ROP5 LW7 F/HR O0 000 O0 0 8 1 1 4 68 0000000000 TABR LW7 HR O0 000 O0 0 8 1 1 4 68 0000000000 GR LW7 GAPI O0 000 O0 0 8 i 1 4 68 0000000000 PIOH LW7 OP~4~ O0 000 O0 0 8 1 1 4 68 0000000000 P16H LW7 OHIViM O0 000 O0 0 8 1 1 4 68 0000000000 P22H LW7 OH~®~ O0 000 O0 0 ~ 1 1 4 68 O00OO00000 P28H LW7 0I-~,~I4 O0 000 O0 0 8 1 1 4 68 0000000000 P34H LW7 OB3¢k4 O0 000 O0 0 8 1 ! 4 68 0000000000 AIOH LW7 OH~,I O0 000 O0 0 8 ! 1 4 68 0000000000 A16H LW7 0H3~4 O0 000 O0 0 8 1 ! 4 68 0000000000 A22H LW7 OH~4M ..... O0 000 O0 0 8 1 1 4 68 0000000000 A28H LW7 OPllvlM O0 000 O0 0 8 1 1 4 68 0000000000 A34H LW7 OI{lVl~ O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape VerificaLxon Listing Schlumberger Alaska Computing Center 2-DEC-1997 09:21 PAGE: 25 ** DATA ** DEPT. 13888.500 ROP5.LW7 159.292 TABR.LW7 -999.250 GR.LW7 PiOH.LW7 -999.250 P16H. LW7 -999.250 P22H. LW7 -999.250 P28H.LW7 P34H. LW7 -999.250 AIOH.LW7 -999.250 A16H.LW7 -999.250 A22H.LW7 A28H. LW7 -999.250 A34H. LW7 -999.250 DEPT. 13155.000 ROP5.LW7 -999.250 TABR.LW7 -999.250 GR.LW7 PIOH.LW7 -999.250 P16H. LW7 -999.250 P22H. LW7 -999.250 P28H.LW7 P34H. LW7 -999.250 AIOH. LW7 -999.250 A16H.LW7 -999.250 A22H.LW7 A28H. LW7 -999.250 A34H. LW7 -999.250 -999.250 -999.250 -999.250 23.432 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAi~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAFiE : EDIT DATE : 97/12/ 2 ORIGIN : FLIC TAPE NAlVlE : 97471 CONTINUATION # : 1 PREVIOUS TAPE : COI~4~2TT : B.P. EXPLORATION, PRUDHOE BAY S-43, API #50-029-22754-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE ' 97/12/ 2 ORIGIN : FLIC REEL i,i~4E · 97471 CONTINUATION # : PREVIOUS REEL : CONk,'IENT · B.P. EXPLORATION, PRUDHOE BAY S-43, API #50-029-22754-00