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Home My WebLink About204-0717. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-14A Renew Well Suspension Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-071 50-029-20804-01-00 ADL 0028257 12658 Conductor Surface Intermediate Liner Liner 8828 77 2646 10036 503 2859 8871 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 7732 31 - 108 31 - 2676 29 - 10064 9795 - 10298 9799 - 12658 31 - 108 31 - 2676 29 - 8555 8368 - 8719 8371 - 8828 9733 650 2670 4760 5410 10530 8871, 8990 1650 5380 6870 7240 10160 12380 - 12580 4-1/2" 12.6# L-80 26 - 2064; 9719 - 98568778 - 8802 Structural 5-1/2" Baker S3 Packer No SSSV Installed 9719, 8317 Date: Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com (907) 564 4891 PRUDHOE BAY 11/12/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:28 pm, Oct 29, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.29 14:37:27 - 08'00' Torin Roschinger (4662) 325-670 Well was reentered and work performed (Sundry 325-530) to meet suspension requirements making it a re-suspension not a renewal. The 10-407 for the subsequent work (Sundry 325-530) can be combined with the 10-407 for this re-suspension (Sundry 325-670). SFD 10/30/2025 XX DSR-10/30/25 DSR-10/30/25 10/31/2030 10-407 J.Lau 10/31/25JLC 10/31/2025 10/31/25 Hilcorp North Slope, LLC Torin Roschinger, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 10/29/2025 Commissioners Jessie Chmielowski, Greg Wilson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Well S-14A (PTD #204071) Application for Renewal of Existing Suspension (10-403) Dear Commissioner Chmielowski and Commissioner Wilson, An AOGCC witnessed suspended well inspection of Prudhoe well S-14A was conducted on 07/04/2025 (20 AAC 25.110 (h)). The submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for temporary renewal of suspension. Specific attachments include: Suspended Well Site Inspection form documenting the pressures and site condition. Wellbore diagram illustrating the current configuration of the well. Prudhoe well S-14A was suspended on 12/18/2007 and has future utility as an up hole recomplete development well. The strata through which the well was drilled is neither abnormally geopressured nor depleted. Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) for the renewal with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, Hilcorp believes Prudhoe Well S-14A is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 406-570-9630 or Oliver Sternicki at 907-564-4891. Sincerely, Torin Roschinger PBW Operations Manager Attachments Technical Justification 2025 Suspended Well Site Inspection Form Wellbore Schematic Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.29 13:45:40 - 08'00' Torin Roschinger (4662) suspended on 12/18/2007 and has future utility as an up hole recomplete development well. Prudhoe Well S-14A (PTD #204071) Technical Justification for Temporary Renewal of Suspended Status 10/29/2025 Well History and Status S-14 (PTD# 182129) was originally completed in September 1982 as a WAG injector. S-14A (PTD# 204071) was a CTD sidetrack drilled as a WAG injector in September 2004. During the liner lap test post CTD sidetrack, TxIA communication was noted. While performing a subsequent MIT-IA, the 5-1/2 tubing collapsed and drifts could not pass 9366' SLM. A RWO was performed in September 2005 to replace the completion. After pulling tubing the rig ended up leaving a 62.4 fish consisting of a mill, bit sub, and two drill collars in hole at the top of the liner. They made attempts to recover the fish but were unsuccessful. A RTTS packer was set at 9705' MD and the 9-5/8 casing passed a pressure test to 4000 psi. The RTTS packer was then released and a USIT log was run to confirm good cement behind pipe. The rig then suspended operations and set a FasDrill bridge plug at 8,990 MD which is 729 above the top of the liner hanger and 743 above top of fish. 68 (5 bbls) of cement was placed on top of the FasDrill bridge plug at 8990 MD on 9/20/2005 and the plug passed a MIT-T to 1000 psi. The well was suspended on 12/18/2007. On 10/1/2025 work was completed under sundry #325-530 to dump bail an additional 15 of cement on top of the plug at 8990 MD. This plug passed a AOGCC witnessed MIT-T (4-1/2 kill string and 9-5/8 casing) to 2678 psi and slickline tagged TOC at 8871 SLM on 10/10/2025. S-14A has future utility as an up hole recomplete development well. Condition of the Wellhead and Surface Location Prudhoe well S-14A is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O (Date= 07/04/2025) = 1/ 0/ 0 psi. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for S-14A. S-14A has future utility as an up hole recomplete development well. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:17:06 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:35 Township:12N Range:12E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:12658 Lease No.:ADL 0028257 Operator Rep:Suspend:X Conductor:20"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2676 Feet Csg Cut@ Feet Intermediate:9 5/8"O.D. Shoe@ 9821 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 10293 Feet Csg Cut@ Feet Liner2:3 1/2 x 3 3/16 x 2 7/8 O.D. Shoe@ 12658 Feet Csg Cut@ Feet Tubing:4.5 O.D. Tail@ 9856 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 8990 ft 8871 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2752 2710 2679 2657 IA 95 95 95 95 OA 0 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2756 2714 2693 2678 IA 70 70 70 70 OA 0 0 0 0 Remarks: Attachments: Anthony Knowels P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Cement was tagged with a 2" bailer. The sample looked like contaminated cement with chunks of cured cement. MIT failed first attempt, passed second test. October 10, 2025 Bob Noble Well Bore Plug & Abandonment PBU S-14A Hilcorp North Slope LLC PTD 2040710; Sundry 325-530 none Test Data: F Casing Removal: rev. 3-24-2022 2025-1010_Plug_Verification_PBU_S-14A_bn                           7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-14A Reservoir Abandonment Compliance Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-071 50-029-20804-01-00 ADL 0028257 12658 Conductor Surface Intermediate Liner Liner 8828 77 2645 10035 501 2859 8922 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16"x 2-7/8" 7768 31 - 108 31 - 2676 29 - 9871 9792 - 10293 9799 - 12658 31 - 108 31 - 2676 29 - 8420 8366 - 8716 8371 - 8828 9733 650 2670 4760 5410 10530 8990 1650 5380 6870 7240 10160 12380 - 12580 4-1/2" 12.6# L80 26 - 2064, 9719 - 98568778 - 8802 Structural 5-1/2" Baker S3 Packer No SSSV Installed 9719, 8317 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY 9/11/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 2520 By Grace Christianson at 9:09 am, Aug 29, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.28 16:57:07 - 08'00' Torin Roschinger (4662) 325-530 X 10-407 AOGCC witnessed tag TOC and MITT or CMIT-TxIA. X A.Dewhurst 04SEP25 Revised 04 SEP 2025 with updated schematic and mechanical integrity DSR-9/9/25 Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement with lateral plug in confining zone. JJL 9/4/25 June 1, 2026 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 08:53:20 -08'00'09/10/25 RBDMS JSB 091125 Reservoir Abandonment Well: S-14A PTD: 204-071 API: 50-029-20804-01 Well Name: S-14A Permit to Drill: 204-071 Current Status: Suspended API Number: 50-029-20804-01 Estimated Start Date: 9/11/2025 Estimated Duration: 1 day Regulatory Contact: Abbie Barker Service Lines: SL First Call Engineer: Hunter Gates (215) 498-7274 (M) (907) 777-8326 (O) Second Call Engineer: Tyson Shriver (406) 690-6385 (M) Suspension Extension: Due to well interventions staffing constraints, we are unable to complete work to get required reservoir plugs in place in E-18B, Y-25A, S-14A and W-09A prior to the required suspension renewal submission date of 8/28/25. Due to this we are requesting a temporary extension of the existing suspensions on the condition that we can show we are progressing this work by the suspension renewal submission due date of 8/28/25. To comply with this requirement, we are planning to have Sundries for this work submitted prior to 8/28/25. Brief Well Summary: S-14A was a suspended rig workover that occurred in September 2005. The rig ended up leaving a 62.4’ fish consisting of a mill, bit sub, and two drill collars in hole at the top of the liner. They made attempts to recover the fish but were unsuccessful. Returns were not lost during fishing operations indicating low injectivity past the fish as well as competent casing. The rig then suspended operations and set a FasDrill bridge plug at 8,990’ MD which is 729’ above the top of the liner hanger and 743’ above top of fish. There was 68’ (5 bbls) of cement placed on top of the FasDrill bridge plug. As per a USIT log run during the workover, the well has adequate cement across the 9-5/8” casing and past where the plug and cement are set. Current Status: Shut-In – Not Operable, Suspended Pressure/Integrity History 10/1/2004 - MIT-IA Failed w/ LLR 0.3 BPM at 2500 psi. LDL showed damaged GLM at 9401’. 8/27/2005 - LIB showed collapsed tubing at 9378’ SLM. 9/2005 – Performed RWO to fixed integrity issues when encountered a tight spot in liner at 9744’ MD. Lost mill, bit sub and drill collars in hole (62’). Set FasDrill Bridge Plug at 8990’ and pumped 5 bbls (68’) of cement on top. WOC. Displaced seawater at 9 BPM at 1500 psi and experienced no contaminated cement in bottoms up. Monitored well and well remained static. 2064’ of kill string left in well. Variance Request: 20 AAC 25.112 (c)(1)(C), (D) and (E) on well plugging requirements state the following: (c) Plugging of cased portions of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are confined to their respective indigenous strata and are prevented from migrating into other strata or to the surface. The minimum requirements for plugging cased portions of a wellbore are as follows: (1) perforated intervals must be plugged by one of the following methods: (C) by the displacement method, a cement plug placed from the well's plugged-back total depth to 100 feet above the top of the perforated interval, if all hydrocarbon-bearing, abnormally geo-pressured, and freshwater strata below are isolated; however, the commission will approve plugging from the top of fill or the top of junk instead of from the plugged-back total depth, if the commission determines that the objectives of this subsection will be met; Reservoir Abandonment Well: S-14A PTD: 204-071 API: 50-029-20804-01 (D) by the downsqueeze method using a cement retainer or production packer set no less than 50 feet but no more than 500 feet above the perforated interval, a volume of cement pumped through the retainer or packer sufficient to fill the wellbore from 100 feet below the base of the perforated interval to the retainer or packer; (E) if the perforations are isolated from open hole below, a mechanical bridge plug set no more than 50 feet above the top of the perforated interval, and either a minimum of 75 feet of cement placed on top of the plug by the displacement method or a minimum of 25 feet of cement placed on top of the plug with a dump bailer; Section D Variance Since we do not have the ability to downsqueeze past the fish to cover our perfs, we are requesting a variance to plug above junk. The current plug, however, is set 743’ above the top of fish. Therefore, we are requesting a variance to this order to leave the current bridge plug with cement cap in place acting as a sufficient reservoir abandonment plug. The top perforation in the Ivishak is at 12,380’ MD and with a fish/junk lost in hole at 9,733’ MD preventing us from accessing those perforations. Considering we have a USIT log confirming TOC behind the 9-5/8” casing is well above where our current plug/cement is set at, along with the fact that it is set across the non-permeable Kingak Silt, we are confident that this suffices as a competent plug for our reservoir abandonment of the Ivishak pool. The depths are listed below. x Perforations are located from 12,380’-12,580’ MD (8,778’-8,802’ TVD) x Top of Sag/Ivishak Pool is 10,108’ MD (8,586’ TVD, also acts as our base of confining layer above the Sag Pool Top) x 62’ fish left in hole by rig, unable to pull completely through X-nipple, TOF at 9,733’ MD (8,327’ TVD) x Liner top at 9,719’ MD (8,317’ TVD) x Fasdrill BP + Cement Cap at 8,922’ MD (7,768’ TVD) x Kuparuk (next shallowest pool) Base at 7,635’ MD (6,839’ TVD) x In between Sag/Ivishak pools and Kuparuk Base is non-permeable Kingak Silt x We have a USIT confirming good cement across top of pool and past our Fasdrill Bridge Plug and Cement Cap at 8,922’ MD (7,768’ TVD) Addressing Section E Since the rig did not pump 75’ of cement on top of the bridge plug, we plan to enter the hole with slickline and tag current top of cement. From here, we will dump bail 15’ of cement on top of the current 68’ of cement to bring that total above the required 75’. Procedure Slickline 1. MIRU SL. RIH w/ gauge ring for a drift run to verify current top of cement. 2. Once verified, make up dump bailer and RIH to dump 15’ of cement on top of existing cement cap (5 runs in 9-5/8” casing) 3. WOC for 3-4 days. 4. Return to well for AOGCC witnessed tag for top of cement. Verify that total cement plug is at least 75’. 5. Perform MIT to 2500 psi to ensure plug is holding and providing adequate isolation. 6. Secure well. RDMO MIT to be AOGCC witnessed - JJL Reservoir Abandonment Well: S-14A PTD: 204-071 API: 50-029-20804-01 Attachments: x Current Wellbore Schematic x Proposed Wellbore Schematic x Sundry Change Form Reservoir Abandonment Well: S-14A PTD: 204-071 API: 50-029-20804-01 Current Wellbore Schematic: 8,922’ MD – current TOC plug Reservoir Abandonment Well: S-14A PTD: 204-071 API: 50-029-20804-01 Proposed Wellbore Schematic: 8,922’ MD – current TOC plug 8,907’ MD – proposed new TOC plug Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: August 28, 2025Subject: Changes to Approved Sundry Procedure for Well S-14ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 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 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y- 25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) Date:Wednesday, August 20, 2025 2:28:33 PM From: Lau, Jack J (OGC) Sent: Wednesday, August 20, 2025 11:05 AM To: Torin Roschinger <torin.roschinger@hilcorp.com>; dave.roby@alska.gov; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y-25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) Good day Torin, Hilcorp’s request to extend the completion of the reservoir abandonments for the suspended wells listed below until June 1, 2026, is approved. The AOGCC appreciates Hilcorp’s effort to progress this activity before the June 1, 2025 date. E-18B (PTD#204139) Y-25A (PTD#208140) S-14A (PTD#204071) W-09A (PTD#204102) Jack From: Torin Roschinger <torin.roschinger@hilcorp.com> Sent: Wednesday, August 20, 2025 6:04 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; dave.roby@alska.gov; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y-25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) is safe. Good morning Jack, Earlier this summer Hilcorp requested permission from the AOGCC to move the following suspended well’s reservoir abandonments out to Q1/Q2 2026 due to the high rig activity and the inability to add well trained and competent crews to keep up with the work. The AOGCC granted permission, but we didn’t land on a specific date. I would like to propose that these wells all be completed by June 1, 2026 to allow time in Q2 should Q1 have similar inclement weather as it was 2 years ago and very little work was able to get executed January-March. Please note that while Hilcorp is requesting permission to extend these reservoir abandonments until June 1, 2026, it is our full intention to continue working with our service vendors this Fall to obtain crews/equipment to execute this work well before the requested extension date of June 1st. Please let me know if you approve this request. Suspended Wells under this request for Reservoir Abandonment extension: E-18B (PTD#204139) Y-25A (PTD#208140) S-14A (PTD#204071) W-09A (PTD#204102) Please let me know if you have any question. Thank you, Torin Roschinger Hilcorp Energy Alaska Prudhoe Bay West - Operations Manager c. 406 570 9630 Torin.roschinger@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 you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. PBU S-14A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-071 50-029-20804-01-00 12658 8828 77 2645 10035 501 2859 8990 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16"x 2-7/8" 7817 31 - 108 31 - 2676 29 - 9871 9792 - 10293 9799 - 12658 31 - 108 31 - 2676 29 - 8420 8366 - 8716 8371 - 8828 9733 8990 1650 5380 6870 7240 10160 12380 - 12580 4-1/2" 12.6# L80 26 - 2064, 9719 - 9856 8778 - 8802 5-1/2" Baker S-3 Packer 9719 8317 Torin Roschinger Operations Manager Andrew Ogg andrew.ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL ADL 0028257 26 - 2064, 8317 - 8410 N/A N/A 0 0 0 0 0 0 0 0 0 1 N/A PRUDHOE OIL No SSSV Installed 9719, 8317 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.10 20:35:19 - 08'00' Torin Roschinger (4662) By Grace Christianson at 8:36 am, Jul 11, 2025 JJL 7/21/25 DSR-7/21/25 RBDMS JSB 071725 S-14A S-14A Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 InspectNo:susGDC250704070327 Well Pressures (psi): Date Inspected:7/4/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:12/18/2007 #307-327 Tubing:1 IA:0 OA:0 Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:6/27/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT S-14A Permit Number:2040710 Wellhead Condition The wellhead is old and rusty but appears to be in good shape. Surrounding Surface Condition Good clean gravel pad. Wood/debris and some signs are behind the wellhouse. Condition of Cellar The cellar was free of debris with no water or hydrocarbon to be seen. Comments The well location was verified by well pad map. Supervisor Comments Photos (9) Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, August 5, 2025          jbr 2025-0704_Suspend_PBU_S-14A_photos_gc Page 1 of 5 Suspended Well Inspection – PBU S-14A PTD 2040710 AOGCC Inspection Rpt # susGDC250704070327 Photos by AOGCC Inspector G. Cook 7/4/2025 2025-0704_Suspend_PBU_S-14A_photos_gc Page 2 of 5 2025-0704_Suspend_PBU_S-14A_photos_gc Page 3 of 5 2025-0704_Suspend_PBU_S-14A_photos_gc Page 4 of 5 Tubing Pressure Gauge IA Pressure Gauge 2025-0704_Suspend_PBU_S-14A_photos_gc Page 5 of 5 OA Pressure Gauge Suspended WellInspection Review Report in�pectNo: susKXFHI00803065830 Date Inspected: 8/2/202O ' � | I nis pector: Matt Herrera Type of Inspection | Well Name: PRUDHOEBAY UNIT S-l4A _ ' l PennhNumber: 2040710 ' —=l Suspension Approval: Sundry # 307-327 � Suspension uatz: Iz/Imzou/ Location Verified? F/ if Verified, How? GPS Offshore? 1-1 � Subsequent Date AOG[CNcti0ed: 7/31/2020 _ Operator: Hi|oo/p North Slope, LLC Operator Rep: E/icDickerman Wellbore Diagram Avail? E/1 Photos Taken? W Well Pressures (psi): Tubing: O ' Fluid in Cellar? El r----' |A: | ---- U DPV|nstaUed? [] r-- OA: 0 VRP|ug(s)|nstaUe6? E] VVeUhemdCondition Wellhead in good shape; no leaks; valves and gauges all operational. SSV still installed in closed position. " Condition ofCellar �~ Good. Clean; nuwater and nostains o/subsidence Surrounding Sudmce[ondition Well house still over the well. Sunounding gravel clean; no evidence of leakage stains or subsidence. Laterals disconnected — and blinded off atthe header. [omments - -- Supemisor[ommenLs Photos(3)attached. 1�J�- Thursday, August 20, 2020 Suspended Well Inspection — PBU S -14A PTD 2040710 AOGCC Inspection # susMFH2O0803065830 Photos by AOGCC Inspector M. Herrera 8/2/2020 11111111111111111!!1111L ffl�- -r" WELL: S -14A 0. V OWNER Prudhoe Bay Unit i OPERATOR 1lilcurli >ut Ih tilnpc. 1.1.1 . API NUMBER 50-029-20804_01-00 SOR LOCATION NW 1 4. Sec. 35, T12N. R12E DRILLING PERMIT 204-071 fA 2020-0802_Suspend_PBU_S-14A_mh.docx Page 1 of 2 2020-0802_Suspend_PBU_S-14A_mh.docx Page 2 of 2 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-071 6.50-029-20804-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12658 8990 7816 9719 9733 8990 8317 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 77 20" 31 - 108 31 - 108 1650 650 Surface 2645 13-3/8" 31 - 2676 31 - 2676 5380 2670 Intermediate 10035 9-5/8" 29 - 9871 29 - 8420 6870 4760 Liner 501 7" 9792 - 10293 8366 - 8716 7240 5410 Perforation Depth: Measured depth: 12380 - 12580 feet True vertical depth:8778 - 8802 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L80 26 - 2064, 8317 - 8410 9719 8317Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker Packer Liner 2859 9799 - 12658 8371 - 8828 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Andy Ogg PBFieldWellIntegrity@hilcorp.co Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone: Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8828 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0385193 PBU S-14A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 2-7/8" x 3-3/16" x 3-1/2" 26 - 2064, 9719 - 9856 m (907)659-5102 By Samantha Carlisle at 12:16 pm, Aug 24, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.24 11:52:24 - 08'00' Stan Golis RBDMS HEW 8/26/2020 DSR-8/24/2020MGR04SEP2020 SFD 8/31/2020 SFD 8/31/2020028257 ACTIVITY DATE SUMMARY 8/2/2020 T/I/O = 0/0/0. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU S-14A Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:S-14A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD):2040710 API Number: Operator:Hilcorp North Slope LLC Date Suspended: 12/18/2007 Surface Location:Section: 35 Twsp: 12N Range: 12E Nearest active pad or road:S Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good. Pad or location surface: Good. Location cleanup needed: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: No. Discoloration, Sheens on pad, pits or water: No. Samples taken: None. Access road condition: Access road and pad in good condition. Photographs taken (# and description): No. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Tree- Swab, Flow cross with Wing, Surface Safety, Master Wellhead - TBG spool with 2 casing valves, Starting head with 1 casing valve. Cellar description, condition, fluids: Snow/Ice Melt. Clean Water. Level below lowermost casing valve. Rat Hole: N/A. Wellhouse or protective barriers: Yes, wellhouse. Well identification sign: Yes. Tubing Pressure (or casing if no tubing): 0 psi. Annulus pressures: IA / OA = 0 psi / 0 psi. Wellhead Photos taken (# and description): Yes, (1) wellhouse and sign (1) wellhead and tree Work Required: None. Operator Rep (name and signature):Eric Dickerman AOGCC Inspector: Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 10:45am Time of Departure: 11:00am Site access method: Truck/Walk. 500292080401 Re-Inspection S-14A STATE OF ALASKA .ALASKA OIL AND GAS CONSERVATION COMMIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other:Sus Well Inspection Rpt Pi 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 204-071 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20804-01-00 7. Property Designation(Lease Number): ADL 0385193 8. Well Name and Number: PBU S-14A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: i E �-` Total Depth: measured 12658 feet Plugs measured 8990 feet NOV�j `� n 8� true vertical 8828 feet Junk measured 9733 feet 4 7 U l b Effective Depth: measured 8990 feet Packer measured 9721 feet true vertical 7816 feet Packer true vertical 8318 feet AO LI CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 77 20"101.1#H-40 31-108 31-108 1650 650 Surface 2646 13-3/8"72#L-80 31-2676 31-2676 4930 2670 Intermediate 10036 9-5/8"47#L-80 29-10064 29-8555 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12380-12580 feet True vertical depth: 8778-8802 feet feet CA$NFMAR 3 S Tubing(size,grade,measured and true vertical depth) See Attachment 4l See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"Baker S-3 Packer 9721 8318 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 �`� ��" C RBDiVi. / i A!iiy„[ ��.j Submit Original Only Ai /(b/i7 vV IiiU Y ( 1 • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Pad S No 14A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD) 2040710 API Number: 500292080401 Operator: BP EXPLORATION (ALASKA) INC Date Suspended. 12/18/2007 Surface Location: Section: 35 Twsp: 12N Range: 12E Nearest active pad or road: Spine Road Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good condition, some misc. wood on pad Pad or location surface: Good level gravel pad Location cleanup needed Flowline piping and misc. parts laying behind wellhouse, recommend picking up wood Pits condition: Good - Frozen Water, No sheen Surrounding area condition: Some trash and wood Water/fluids on pad. Frozen puddles Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Gravel Road Photographs taken (#and description). 3 Photos, wellhouse, flowline, wood debris Condition of Wellhead AOGCC requires 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition, Good Condition, production tree, no flowline, blinded Cellar description, condition, fluids: Gravel Cellar, no visible hydrocarbons or fluids Rat Hole: No rat hole Wellhouse or protective barriers: Yes-wellhouse good condition Well identification sign: Yes Tubing Pressure (or casing if no tubing) SSV Closed on Hydraulics Annulus pressures: OA= Opsi, IA=Opsi Wellhead Photos taken (#and description)- 1 Photo, Partial wellhead, camera malfunction prevented more pictures Work Required: None Operator Rep(name and signature): Joshua Stephens �. AOGCC Inspector: Jeff Jones Other Observers: Inspection Date: 10/10/2016 AOGCC Notice Date 10/9/2016 Time of arrival: 2:56pm Time of Departure: 3:05pm Site access method: Pickup Truck • 10 0 bp0.2 0.1 0 0.2 Miles R-20A 'S-09APBI S S-HOB _-A 5:4 ^5-3E --- Legend Pipelines(General) - Vb, (FI,,il.l rs-:_ -10Aliu110d '9-SOAPS) R-5lA s-to 09PB1 Pipelines(Detailed) e R-41 S - —Ull 'R.25 Cuss :(S-14 R-t5A 15-05APB1 .M-19B eR30 * —Etl (S-37 _.M-14 -"-Wl'.16 5-123 15-05 5-37APB 1 5-26 t S-I It: --ll'eter .1.1-20A --Relief u 5-05A >9M-26 M-06A —Ulinty i;M OE „I.7OAPBi t�nl[n �L77 ct-=6n Selected Pipeline. :5-:_m r. .. yS-37A `,:S-11A R-IIA R-14A \IIIIIII\ \'.. ti-30 12A R-39AL1 111111111/4 '‘b. 1!,-13A \ r., 06 3 5-1_e Author: `'.., n M-32 SAO u S 40 S-13 ..t1-18B 14 November,2016 BP1\catrg 1 0 BP Exploration(Alaska)Inc.All rights reserved.This map Is Informational in nature and Is presented without representations or warrants.as to accuracyy,completeness or sae for any purpose Product of BPXA Atlas Enterprise GIS. alaska gis.bpweb.bp.com IItLE= 6-3/8"CPN WELLHEAD McEVOY • S 14A NOTES:H2S READINGS AVERAGE 125 ACTOKBl1ATOR aTIS BB Suspended RW O ,�';s�AX DOGLEG:39"@ p 7p*_* TI BB ppm OKB.ELEV 67.8' BF.ELEV= 39.07' ' Max = 3200' ZiMAngle= 99°@ 10763' i t Datum MO= 10365 20"X30"INSULATED 109' 2064' —14-1/2"WLEG,D=3,958"(KILL STRING) Datum TVD 8700'SS CONDUCTOR, 2591' 4-1J2"TBG, 12.6#,L-80 TCS,.0152 bpf,D=3.958" —I 2064' 95/8^DV PKR 13-3/8"CSG,72#,L-80 BUTT,D=12.347" H 2676" Minimum ID =2.37" @ 10541' 3-3/16" X 2-7/8" LNR XO RSH @^9733'-—9795' (09/19105)- 1111110.--.041 8990' —9-5/80 FASDRLL BRIDGE RUG 3.687" OD MILL: L= 1.35'! BIT SUB: 3.375" OD, 1.87'L, w/5 bbl CMT CAP TO-8922(09/20/05) 2 X3-3/8" DRILL COLLARS: 3.375" OD, 591 ID= 1.00"-TOTAL LENGTH= 62,40'. PRIOR TO LEAVING FISH OH, JUNK WAS MILLED-9795 9719' -H9-5/8"BAKER A(R D=4.75" UNABLE TO PULL THROUGH X NIP @ 9774'. M ABLE TO ROTATE & MOVE DH. FISH FELL OH 9726' --�M LOUTEXiB�ISION D=6.00" WHEN THE DC CONNECTION PULLED IN TWO 9733' -�5 1/2'x 4-1/2"XO,D= 3.95$" 9774' HI4-1/2"OTIS X IsN3,D=3.813" TOP OF 7"LNR —I 9792' 9799' --13.70"BKR DEPLOY SLV,D=3.000' I 9815' —4-1/2*OTIS XN NP,MLLED D=3.80' (BEHIND LNR) 1 g 9838' --13-1/2"FES X NP,D=2.813" 4-1/2'TBG,12.6#,L-80,.0152 bpf,D=3.958" — 9856' •.11 k1, 11 1 1 11 1 9856' H4-112'WD LEG, =3.958"(B&NND LNR) 3-1/2"LNR,8.81#,L-80 STL,.0087 bpf,D=2.990" -I 9871' •4 •, 11 �4. X11 9871' H3-1/2"X 3-3/16"XO,0=2.786" 9-5/8"CSG.47#,L-80 BUTT,D=D8.68r --i= � 9871' 111 X11 1111 0111 10121' —I ROLE N 7"LNR(POST C I U 9/19/04) 7"WHPSTOCK(XX/XX/XX) —I 10293' .41�11.� ,� X • MLLOUT WINDOW (S-14A)10293'-10298' 7"LM,26#,L-80 1,14S,.0383 bpf,D=6.276" H —10293 / *,F ,;71,0 •1.1.1.1.1.1.1.1 105417H 3-3/16"X 2-7/8"XO,0=2.440" a PERFORATION SUMMARY YA,AIIITATAT.,AT: REF LOG:CNUGR ON 09/18/04 ANGLE AT TOP SERF:84°@ 12380' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/16"LNR,6.2#,L-80 TC1, -- 10541' 1 PBTD — 12621' 2" 6 12380- 12580 0 09/18/04 09/19/04 .0076 bpf,D=2.800" 2-7/8"LNR,6.16#,L-80 STL, —{ 12658' `;�. - .0058 bpf,D=2.441" DATE REV BY COMMENTS DATE REV BY COp 4 NNS .. PRUDHOE BAY MU 09/16182 N22E ORIGINAL COMPLETION WELL S-14A 09/19/04 JLM/TLI CTD SIDETRACK(S-14A) PERNIT Nb:"1040710 09/21/05 Bartel Suspended Fishing Operations. AR No: 50-029-20804-01 01/18/12 TM41.1MD ADDED112S SAFETY NOTE SEC 35,112N,T12E, 1651'FM_&2185'FWL 07/30115 PJC UPDATE PER SUSPENSION 1 BP Exploration(Alaska) • • • p• O p p C o p ca �n � � r app CONv � � N- U iLo0o � Logo 3 CO OM) co� N CD CO 'Cr CDN- CO CO co CO Cf) O) O N- CO O) N C() .- N CO N O r- CO Cl) N- CO O N CO CO CO CO CO N CO H co — 07 C) N- N CO f- CO CO N CO C'7 NY N- N CO CO CO CO CO CO "Cl" COr CO CO CO 07 CC) O in N- CO O O O N r r V p CU C I I I I I I I Q Lo c) co O) O) d) ti M co N I� CO c N _ O) O) O) 0) M Ca aO O O O C) O 00 O co 00 J CO CO CY) "-� J 00 J J J = d 4* N4 J N CL, co cc NCb co N N CO U O M N °° N N co i r Cr) r V- C OCO co N "Zr Z01 CO N- C I� CO O O I� (oh- J N O C N N � W 0)O C H W W ' U co D O O LL h a Z Z Z E W W W W W m m Q D H Z_ _Z Z _Z D D 0) Z J J J J F • O >- E a) i 2 z ' O N O m 6.o a Q. a) U Q. U) C 0 _ a) a) a- E -0 d a) U) a) 5 Q O U) Z CD W N Q O >- O to 5 m I- U • • • • ^m< x, mow+... .. .�`Po` u"�Y<- • li ; •• ''. , : y . ',' , , , „ .. , . k' , , . ,, , ,4, , , , •••,..,'„•‘., .. , . . • ..... .. .. . „, ,, •, . . . • ,,,,•, ; , , . ,.. ... - ,... . i • . „., • , . . . . . . ..... ..... . . . . .. . . . . . „ ... , .. , . . . . .. „ 4. _. ...... .. . ”„ ! ... , . ... ... ..t , .. . .........., .. .._ .. • . . . . . . .. • , . . . ..., . . •,... , ..,.. . , . a w a , A•. y b of ( r M C M I ' 4, , ' , '4: 1 ,..' ,- e i : .� r - 1 s r • " a ' \' :0 ° ' y ' ,#'. ;..M` r,.,*= a;, M w � n 'r4 "" : -y r 'd�a 'ury tai,_ 41 . i s y,�k, ,a p �' J) S r „,,,4.7,,,,;,,,,,, , L;” Mbu a m� r,J d .. a4 Oi ifg=. • v.. • yr X "y4s' •xv ' d"IS 1 = , ¥ .. Aktrifirtftst s 4 • L - _ _ L of #J- ,,,:•;.:,:.4..,:;,,:-4:: :*.''','_,'..:;:..T''''' '7:4:1:1. .:„.„.?+4. • • .2 =1 Y • / 1 1 -41" Notslakfoi.. f , ...,,,07,.- 1' ' .„.„_._ tt .......„,.„____---°"*.i , ,,, , 11,..„ .., t t.... ''''T`N 1—........".......6..: y :e „„d.,, ti Yxi 1 8 i i It i AM - r �i ,mak',.''''',4'."-. t'`. z4' i y .,, z y .. y 4 ro I. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU S-14A Oper.Rep: J.Stephens PTD No.: 2040710 Oper.Phone: 659-5766 Location Verified? Yes Oper. Email: ioshua.steohensCcDbo.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 12/18/07 Date AOGCC Notified: 10/09/16 Sundry No.: 307-327 Type of Inspection: Subsequent - Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA 0 - OA 0 Condition of Wellhead: Good condition,wing valve,master valve,SSV closed&hydraulics disconnected.Outlet is blinded. Condition of Surrounding Surface Level gravel pad with some frozen puddles&road access,no visible hydrocarbon residue.Some wood,trash,piping&metal parts. Location: Wellhouse in good condition. Follow Up Actions Needed: Clean up wood,trash,piping&metal parts. Comments: Well identified by pad map and well sign permanently attached to wellhouse.Mr.Stephens took photos at my direction and they are attached to his report. Attachments: none REVIEWED BY: to�Insp.Supry ,;�� tl � i40 Comm SCANNED JUN 0 820 PLB 12/2015 2016-1010_Suspend_PBU_S-14Ajj.xlsx ti O F 7,4_ THE E STAT• • Alaska Oil and Gas ��►-s�i�� of e0 Conservation Commission ALSIcAWitt 333 West Seventh Avenue e, Alaska 99501-3572 Anchorage, ,,.vr,�t, � GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS.0' Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity& Compliance Team Leader BP Exploration(Alaska), Inc. D P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU S-14A Sundry Number: 315-585 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this of October, 2015 Encl. RBDMS Ply 012015 411 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ON • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend 2 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑7LJ' Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0/.. .perenZn' iri, fr 7_ fiva i 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-071 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612Stratigraphic 0 Service 0 6. API Number: 50-029-20804-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No m Will planned perforations require a spacing exception? PBU S-14A •• RE IV E D 9. Property Designation(Lease Number): 10. Field/Pools: P ADL 0385193 • PRUDHOE BAY,PRESENT WELL CONDITION SUMMARY RUDHOE OIL• bj. 2 5 0 6 11. 015 j Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): JukkOraCC 12658 • 8828 . 8990 7816 8990 9733 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 20"101.1#H-40 31 -108 31-108 1650 650 Surface 2646 13-3/8"72#L-80 31 -2676 31 -2676 4930 2670 Intermediate 10036 9-5/8"47#L-80 29-10064 29-8555 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12380-12580 8778-8802 See Attachment See Attachment See Attachment Packers and SSSV Type: 5-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 9721, 8318.77 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program ❑ Exploratory 0 Stratigraphic 0 Development 0 Service El ' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended m • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true a.d c• rect to the best of my knowledge. Contact Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader a c- Signature �� Phone +1 907 564 5430 Date Pp /J' 70 if-- ..100.11. - COMMISSION � COMMISSION USE ONLY C Conditions of approval:Notify Commission so that a representative may witness Sundry Number: -216--65?6 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Apps r%4 / /5 ,q 1-- -,-A-1yr ] <G g ,--1- 1-,n f e n e ie vz 1 e`,�.vh rn f 4 f a_ P ti A- p14 for ,fvspenc/ccr i v-e II vv th >Zo FVr C'-vrc. v 1-1 i1 whcG I') brti” S' thrcc tvc/1S C/vfer>`o a ba v,c1ok-7 rv1ti-i p r7?,,-- /-o p4 a c/r?vr .-,-t, fS /o ,.-,ii-i /2M/f lan fa hedtlrelo loped ' k1a.pprovied /--i,-ovc/ !1 1-hc edi-+,•,-, essicir, 8( • 1z 3//i4 _ F4 17 1.1, 7a c ov% ,10 hi wi /15 rev.i)-C'-ii,- ,/' t,-, i`11 i`-jVc j ` J Spacing Exception Required? Yes 0 No Subsequent Form Required:/lane ,r- d 'e P-115 `w g%6• `(• ag7 APPROVED BYTHE Approved by: p4(....,044.__77_, COMMISSIONER COMMISSION Date:/ .. _!S t_ 10/24,/15- --1.6a/24,/I RBDMS Novo 2 ZOMS ORtGtNAL /2e4- Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. �� /v•2G.if- • • m ct.N O O O OO O M c- co OLO LC) • (fl N U 0 0 0 0 0 Lo M r-- `ZrLo CO CO • CO CZ CO O N O CO CO co CO LO 0) O N- 00 O) N O I� LO N- N CO N LOti 00 O N CO CO CO CO CO N CO i I I I i F- CO N- • 0) CO N CO M CO N CO CO N- N CO CO 00 CO CO CO I. C co — CO 00CO O CO Lo O O N CO CO co • N O O O N c..4O C.) o i I I I I I i a rn co - C) 0) rn N r-- C57C) ' CO CO N N- N- CO N N- V/ O) 0) O) C O_ 6) � m Q. OCOaOo 000oo ooO000000 2 J 000 J J _, J J • d *k C N •44. CO CO . N (.# 00 (0 (Ni U _ co co N N O MM r N .- CO N V 'C t (C) r O M M .- N O 0 O N - O J N O O N N C C 0 U W W U o LL CCCCCt � i Z_ Z Z a W W W W W m Q D H Z_ Z_ Z_ Z_ J D U u) Z J J J J F- I Fit= 6318"can/ S 14 A NOTES:H2S READINGS AVERAGE 125 V ELU-EAD McEVOY K °'� Suspended RWO ,121WHEN AX�,a :39°@ 0570'0 i OKB.ELEV' 67.8' �• f,. ii BF.ELEV= 39.07' ' KOP 3200' Max Angle= 99'©10763' Vii 1 Datum MD= 10365 20'X 30"NSIJLATED — 109' 2064' —4-1/2"WLEG,D=3.958"(KILL STRNG) Datum TVD, 8700'SS CONDUCTOR, 2591' '-{9-5/8"DV FKR 4-1/2'TBG, 12.6#,L-80 TCII,.0152 bpf.D=3.958" J— 2064' 13-3/8"CSG,724,L-80 BUTT,I)=12.347' — 2676• J A Minimum ID =2.37" @ 10541' 3-3/16" X 2-7/8" LNR XO RSH @-9733'--9795' (09119/05)- 8990' —9-5/8"FASDRLL BRIDGE PLUG 3.687" OD MILL: L= 1.35/ BIT SUB: 3.375" OD, 1.87'L, w/5 bbl CMF CAP TO-8922'(0920/05) 2 X 3-3/8" DRILL COLLARS: 3.375" OD, 591 ID= 1.00" -TOTAL LENGTH= 62.40'. PRIOR TO LEAVING FISH DH, JUNK WAS MILLED -9795 9719• gyg•E3AKER p}CR D=4.75" UNABLE TO PULL THROUGH X NIP @ 9774'. ~ ABLE TO ROTATE & MOVE DH. FISH FELL DH 9726' —IMLL OUT EXTENS N,D=6.00" WHEN THE DC CONNECTION PULLED IN TWO 9733' —5 1/2"x 4-1/2"XO,D= 3.958' ft' 9774' H4-12"OTIS X NP,D=3.813" I TOP OF 7'1342 H 9792' 1 9799' —3.70'BKR DEPLOY SLV,D=3.000" 9815' —4-12"OTIS XN NP,AAL LED D=3.80' ( MI LNR) 9838' —31/2"I-ES X NP,D=2.813" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" — 9856' 01 p'.. 3-1/2"LI,8.81#,L-80 STL,.0087 bpf,ID=2.990" — 9871' .4.1 I'�04 9888' —4-1l2'VVLCG,D=3.958"( NO LPA ••• ••• 9871' H3-1/7 X 3-3/16"XO,D=2.786" 9-5/8"CSG.47#,L-80 BUTT,D=D=8.681" H 9871' $vt$$ f4 '44 44', 10121' HOLE E N 7"LNR(POST CID 9119/04) 7'wCI-IPSTOK(XX/XX/XX) — 10293' 444. � . MILLOUT WINDOW (S-14A)10293'-10298' 7"LNR,26#,L-80 LAS,.0383 bpf,D=6.276" — -10293 ,4.�4A* 4f•f•f•4•c1148. I 10541' H3-3/16"X 2-7/8"X0,D=2.440' PERFORATION SUMMARY REF LOG:C3`IJGR ON 09/18/04 ANGLE AT TOP I :84°C± 12380' Nate:Refer to Production DB for historical perf data SIZE SW NTERVAL Opn/Sqz SHOT SQZ 3-3/16"LNR,6.24,L-80 TCL — 10541' PBTD 1— 12621' 2" 6 12380- 12580 0 09/18/04 09/19/04 ' 0076 bpf,D=2.800" (2-7/8'LNR,6.16#,L-80 STL, — 12658' �;=. .0058 bpf,D=2.441' BATE REV BY COMMENTS DATE REV BY COMENTS PRUDFDEBAY lilT 09/16182 N22E ORIGINAL COMPLETION WELL: S-14A 09/19/04 JLM!TU CTD SIDETRACK(S-14A) PERMfT Pb.'2040710 0921/05 Bartel Suspended Fishing Operations. AR No: 50-029-20804-01 01/18/12'TMV/JMD ALOE)Ii2S SAFE/Y NOTE SEC 35,T12N,T12E, 1651'FN..8 2185'FVWL 07/30/15 PJC UPDATE FER SUSPENSION BP Exploration(Alaska) BP Exploration(Alaska) Inc. 6,` `. Douglas A. Cismoski, P.E., BPXA Wells49, Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 August 28, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well S-14A (PTD # 2040710) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well S-14A on 5/30/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition Prudhoe Bay Unit well S-14A was suspended on 12/18/2007. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is secured with a bridge plug - capped with cement in the 9-5/8" casing. The well is mechanically sound as proven by a pressure test after the plug was set and cement placed. Based on these conditions and the inspection on 05/30/2014 Prudhoe Bay Unit well S-14A meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay well S-14A is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. Sincerely, • • Dougla A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • • Prudhoe Bay Well S-14A (PTD 2040710) Technical Justification for Renewal of Suspended Status August 28, 2015 Well History and Status Prudhoe Bay Unit well S-14A (PTD 2040710) was suspended effective 12/18/2007 after a failed rig workover attempt. The well is secured with a bridge plug in the 9-5/8" casing at 8990' MD with a cement cap to —8922'. The well was displaced with 8.5 ppg seawater, a kill string run to 2064' MD and the well freeze protected. The well is mechanically sound as proven by a pressure test after the plug was set and cement placed. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Prudhoe Bay Unit well S-14A is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= NA/0/0 psi recorded on 5/30/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for S-14A. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness 10 Year Well Name: Drillpad S NO 14A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit 0(PTD): 2040710 API Number. 500292080401 Operator: BP EXPLORATION(ALASKA)INC Date Suspended 12/18/2007 Surface Location: Section: 35 Twsp 12N Range 12E Nearest active pad or road Spine Road Take to Location Digital camera Map showing well location/Aerial photos Brief welt history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges,fittings,tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location,including discoloration,fluids or sheens visible on the ground or in any nearby water, 2)photographs showing the condition of the location surrounding the well General location condition: Clean,active pad Pad or location surface level gravel pad,rt front of S Pad Location cleanup needed. none Pits condition: N/A Surrounding area condition: clean Water/fluids on pad snow melt Discoloration,Sheens on pad,pits or water none Samples taken: none Access road condition: good Photographs taken (#and description) Yes,wellhouse and behind house Condition of Wellhead AOGCC requires' 1)a description of the condition of the wellhead,2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description,condition. CIW WH, McEvoy tree,with SSV(closed)clean and intact Cellar description,condition, fluids snow/ice Rat Hole, N/A Wellhouse or protective barriers. Yes,house Well identification sign: Yes Tubing Pressure(or casing if no tubing) N/A SSV closed Annulus pressures IA-0 psi OA-0 psi Wellhead Photos taken(*and description) Yes, surface casing,WH,tree,and cellar Work Required none Operator Rep(name and signature): Laune Clime__r�� .�._ AOGCC Inspector: Qtrser Observers Ryan Hayes Inspection Date: 5/30/2014 AOGCC Notice Date: 5/29/2014 Time of arrival: 1:50pm Time of Departure 2:05pm truck,AOGCC inspector(John Crisp)unable to cross river to inspect,BPXA was early and Site access method: inspected before bridge closed • 410 THEE= 6-3f8"CIA/ Walt-FAD McEVOY I. S 14A SAFETY NOTES:1-12S READINGS AVERAGE 125 OKACB EL V 01 �' Suspended RWO ,1216 WHEN MI—WELL'ANGLE570'*** OKB EiEv 67.0 BP.acv= 39.0? 1 KOP- 3200" 2 Max Angle=99°12 10763i1. Datum 1,0= 10365 20"X30"MLL SATED -1 109' I 4 D 112'WLB3, =3.958'(K L STRING)Datum ND, 8700'SS; CX)NJUCTOR, I I� I4-112"TBG,12-60,L-80 ICI, 0157 bpi,In=3 4511- H am- 2591' -9-&a.'ay PlCF2 L13-3,8'C313,l'24,L-08 euiT,e.-ti_a41 ,_[....L 26761 i Minimum ID;=2.37" r•+ 10541' 34116"X 2-718"LNR XO ASH ji--9733 --•9795 019119!05; I 8990' 1--9-518'E'ASi>01._BRIDGE Ft I Ka 3.687'OD MILL L= 135/BIT SUB:3.375'OD, 1.87'L, w f 5 bbl GMT CAP TO-8927(09/20/05)1 2 X3-3/8"DRILL COLLARS' 3 375'OD,591.. ID=1.00"-TOTAL LENGTH=62.40'. PRIOR TO LEAVING FISH DH,JUNK WAS MILLED—9795 UNABLE TO PULL THROUGH X NIP 9774'. I� 9719' -9 5/8"ElAK13PKR ID=4-75" ABLE TO ROTATE:&MOVE DH. FISH FELL DH t, 9726' L. LL OUTEJC1H'V51ON,D=6.00" WHEN THE DC CONNECTION PULLED IN TWO 9733' w -5 ifz'x 4-1/3"xo o=3.9511'] { 9774' H4-1/2"OTs x Nr,13=3.813' TOP OF 7'LNi_I 9792' t;" -"--'" , 9799' ]-{3 70'SKR DEPLOY SLV 10=3,001'_I ' I 9815'.....I-"4 1/2'OTIS XN NIP Mt i F1''In 1 80' ' I (11ii4iN)1 NFl) I I 9838' ---31/2"I-LsXNP',D-2313^ b-7.+2'TBG,12.80,1-80,-0152 bpf,13=3-958- f- 98 ' 16 n!�`----r- 9856' f--14-1IP 1ALEG.[D-3 558'IBHtiNfi LW)] [3-1/2"t NR,8 810 1-100 S11, 0081 No k)_7 450* J--I 9871' I At. Al At. --`, 9871'.. -{3-12"X 3-3/16"XO,D=2 756' I9-516"CSG 471,L-80 BUTT,ID=I0=8.681' H 9871' IIII O I. I 10121' --11-4)(1- IN 7 I Net(POST CTD 9/19/04) I — 4 r wtitti16 (X cXXixX) ,{ 10293' .. (! MLOuA*xv(18.14A)10293' 10298" '1 Ifti !"I ' l 1 C 145 0383 bp, 6 276- •� -10293 ''`i 'kV Mil kV 10541' -I3-3/16"X 2-718'XO,D-2 440' I ....--- PERFORATION S I'PERFORATX)NSUMMARY vire,a„r4, REF LOG:CMIGR ON 09/18/04 ANGLE ATTOPn[8 @ 1ri 380 alp Mile Fleler to Production CB for historical pert data SIZE SFF INTERNAL f Opl qz SHOT SOZ 3-3.'16”LNR 8.21,L-80 TCA, - 10541' I 187'0 - 12621' 2' 6 12380-12580 0 09118/04 09/19/04 :13 i 6 bpf,D 2.800' i 7-718"1 Mi,6 160,I.-RD S71, 1- 12658' I •1 . 1.0058 bpf 13=2.441- DATE REV BY COMMENTS I DATE REV BY COONENTS RXAI-DE BAY LHT 09/16/82 N22E 'ORIGINAL COMPLETION WELL: S-14A 09119/04 JLM dTLN CTD SIDETRACK(S-14A 1 PBWT Nb:'2040710 09/21105 BartelSuspended Fishing Operations A I No: 54029-20804-01 01/18112 T1,TNJMD ACDED I-ES SA FET/NDTE SEC 35,T12K T12E 1651'FI.8 218.5'FVJI_ 07/30/15 PJC UPDATE PDR SLJSFB6CN - i i I BP P ploeation(Alaska) • • • Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp, Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells,of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally,as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options(wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [ nailto:victoria.loepp©alaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo alaska.gov 1 • • Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [mailto:Ryan.Daniei ; ] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L(ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities) and still in the very early scoping stage. They are not funded or approved yet,and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim,and the Suspended well renewal applications submitted by Oliver are also separate (discrete and unrelated)activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [ nailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • • • From: Sternicki, Oliver R [rnailto:Oliver.Sternicki@bp.com] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki WO 1006•1 Vaal 01.1111111410001 Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickiabp.corn From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory, development, or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • State of Alaska • Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victorialoem@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.Sternicki@bp.com] Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory, development,or service well; no wells meet the (B) criteria. Regards, Oliver Sternicki WO Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(a)bp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me,or come and discuss if we have an issue. Thanks Ryan 3 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling;or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A) and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeaa@alaska.gov 4 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ a 4= - CJ '1 J Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ¢biskettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: Date \11~/Ob o Other:: BY: ~ 151 \Mf 11111111111111 "III ï\1P Project Proofing BY: ~ Date uJ{? J 0 þ ()_ {p 0 Date: 0 ~ 151 BY: + \ 3 = TOTAL PAGES r-¡::3 (Count does not include cove~ 151 Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: !J-.1=b- (Count does inc7v", sheet) Page Count Matches Number in Scanning Preparation: YES BY: ~ Date: t t I ß" jDfo 1111111111111111111 NO 151 Vtif Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: 151 11111111111I11 ,,11/ Scanning is complete at this point unless rescanning is required. ReScanned III "111I11111 ,,11/ BY: Maria Date: 151 Comments about this file: Quality Checked 11111111I111 II 1111I 10/6/2005 Well History File Cover Page.doc ■ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU S -14A Oper. Rep: Jack Winslow PTD No.: 2040710 - Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 12/18/07 - Date AOGCC Notified: Sundry No.: 307 -327 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing SSV closed ` Photos Taken? Yes IA vac by Operator OA 0+ Condition of Wellhead: Well house in place, full tree with closed SSV, flow line removed and blinded. Condition of OK Surrounding Surface Location: Follow Up Actions none Needed: Attachments: None - REVIEWED BY: Insp. Supry J 1 0 1 / 6( Comm PLB 08/2010 2010- 0911_Suspend_PBU_S- 14A_cs.xls • -~,... =.~---, ~.;. ~~ . It ~ ~ ~ 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFicheiC~rPgs_InsertslMicrafilm_Marker. doc STATE OF ALASKA ~~"'`~~ ALASKA OIL AND GAS CONSERVATION CONSIGN .~+ ~ ~1 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~Is~a q~l{ ~ ~~ ~~>CEn` 1*t..l>;t~l"~i0li 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®~uspended zoAAC zs.~os zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions One 1 b. Well Class: ' ~' ^ Development ^ Exploratory ®Service ~ ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp usp. or Aban ~~s a?-/ ~~ 12. Permit to Drill Number 204-071 ~ 307-327 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/10/2004 13. API Number 50-029-20804-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/16/2004 14. Well Name and Number: PBU S-14A 1651 EWL, SEC. 35, T12N, R12E, UM SNL, 2185 Top of Productive Horizon: 1721' SNL, 1278' EWL, SEC. 36, T12N, R12E, UM 8. KB (ft above MSL): 67.8' ' Ground (ft MSL): 37.57' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1503' SNL, 3524' EWL, SEC. 36, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) 8922 7775 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 620347 y- 5979855 Zone- ASP4 10. Total Depth (MD+TVD) 12658 - 8835 - 16. Property Designation: i ADL 385193 TPI: x- 624721 y- 5979857 Zone- ASP4 Total Depth: x- 626962 y- 5980112 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^ Yes ^ No Submit electronic and rinted information er 20 C 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR / EWR, MGR I CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM ' TOR BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2676' Surface 2676' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 10064' Surface 8562' 12-1/4" 1415 cu ft Class'G' 130 cu ft AS I 7" 26# L-80 9792' 1 2 8373' 8723' 8-1/2" 438 cu ft Class'G' a-vz" x 3-3/16" x 2-7/8" 8.81# / 6.2# 16.16 L-80 9799' 12658' 8378' 8835' 4-118" x 3314" 225 cu ft Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top $ Bottom; Pe nterval open rforation Size and Number): .SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 Kill String 2064' , MD TVD MD TVD 4-1/2", 12.6#, L-80 9719' - 9857' 9719' 12380' - 12580' H7S5' - 8509' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ~~ ~kN `~ ~ ~~~~ -9733' Top of Fish (See Diagram) 8990' Set FasDrill Bridge Plug -8922' Place 5 Bbls Class'G' Cmt on top of Bridge Plug 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULAreD 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.0 1. ~.T~ None ,,. , ~°~.- ,t~fV ~ ~ 100i Form 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE ~'~ 28. 4~EOLOGIC MARKERS {LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Test ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Sadlerochit 10300' 8728' None Top Sadlerochit {Inverted) 11980' 8749' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. _ f Signed Terrie Hubble Title Drilling Technologist Date ' ~ ~/Q~ PBU S-14A 204-071 307-327 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. DnllingEngineer: Danielle Ohms, 564-5759 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval. reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box_ Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • Well History Well Date Summary S-14A 10/17/2004 LEAK DETECT LOG FROM SURFACE TO 9800 BASE PASS, PUH, LOG PUMPING PASS DOWN TO 9401', TOOLS STOPPED IN GLM. INITIAL LEAK RATE .3 BPM, WHILE PUMPING TO 3000 PSI ON IA RATE INCREASED & IA PRESSURE DROPPED TO 600 PSI. SUSPECT DAMAGE TO GLM 9401'. WELL SHUT IN. S-14A 10/17/2004 T/I/0=70/50/0 Assist e-line w/ LDL Log -Pump 107 bbls crude down IA taking returns up tubing to flowline of well 13 to asist w/ LDL, Freeze protect jumper line w/ 5 bbls diesel. Final WHP=200/400/0 S-14A 10/22/2004 WELL SHUT IN PRIOR TO ARRIVAL. D28MASTER AND SSV FROZEN -THAW OUT. RIH W/DECENT., 4.0" LIB TO STA #2 @ 9381' SLM. MARK SHOWS RA LATCH. JOB IN PROGRESS. S-14A 10/23/2004 JOB CONTINUED FROM 10-22-04. RAN 3.5" ROLLER DOG GRAPPLE -UNSUCCESSFUL. ATTEMPTED TO RUN 1.7" LIB TO STA #2, COULD NOT PASS OBSTRUCTION, SAT DOWN @ 9378' SLM. RAN 3.6" BELL GUIDE & PULLING TOOL TO 9371'SLM, COULD NOT MAKE ANY MORE HOLE. RAN 2.25 LIB SET DOWN @ 9356' SLM -ONE SMALL IMPRESSION -INCONCLUSIVE. RAN 2.25" PUMP BAILER -APPEARS BAILER BTM GOT ALONG SIDE OF FISH -SMALL AMOUNT OF PLASTIC COATING IN BAILER. RAN 3.5" DE-CENT & 3.35" LIB SET DOWN @ 9371'SLM -IMPRESSION ON LIB @ 3:00 & SQUEEZE MARK ON SIDE OF LIB @ 9:00. RAN 2.5" DE-CENT & 2.55" LIB SET DOWN @ 9370' SLM -SAME IMPRESSIONS -LOOKS LIKE BREECHED TBG. RAN 3.5" DE-CENT & 4.00" LIB SET DOWN @ 9371 'SLM - SAME AS 3.35" LIB. RAN, OC, 2.7" LIB, 10' OF 1.5" STEM & 1.75" LIB. SET DOWN @ 9366' SLM, COULD NOT MAKE ANY HOLE. IMPRESSION ON BLK -INCONCLUSIVE. RDMO. SSV BACK TO WELL, CAP TESTED & PAD OP NOTIFIED. S-14A 8/27/2005 WELL SI ON ARRIVAL, MASTER FOUND CLOSED. DRIFT W/ 4 1/2 CENT, SAMPLE BAILER TO COLLAPSED TUBING @ 9378' SLM. LEFT WELL SI. S-14A 8/28/2005 CORRELATED TO TUBING TALLY DATED 14-SEP-1982. TAGGED COLLAPSE AT 9394 FT. CUT 5-1/2" TBG AT 9327 FT WITH 4-7/16" CUTTER. S-14A 8/30/2005 T/I/O=0/0/0 Circ out TxIA (Rig prep) -Pump 5 bbls meth & 235 bbls 1 %KCI water down tubing taking returns up IA to flowline of Well S-13. Continued on 08-31-05 WSR. S-14A 8/31/2005 T/IA/OA= 0/200/0 Pre- Rig well head MIT PPPOT-T {passed } PPPOT-IC {failed } Cycle LDS on tubing spool { 8 }that were unable to move .Test tubing hanger to 5000 psi for 30 minutes test good. Cycle all LDS on casing spool all LDS moved free no sign of any bent or broken LDS. Test void would not bleed off, interne) check leaking by, unable to test IC hanger. Should be changed out during RWO operations. S-14A 8/31/2005 Continued from 08-30-05 WSR. Circ out TxTA, Attempt MIT OA to 2000 psi, FAILED (Rig prep) -Pump 997 bbls 1 %KCI water (total) & 175 bbls diesel down tubing taking returns up IA to flowline of Well #13, U-tube TxIA to put freeze protect in place. Attempt to pressure OA to 2000 psi w/ diesel, OAP @ 200 psi wl 10 bbls away fluid started coming out of conductor pipe into cellar, Bled OAP to control relese, Notified spill response & Co. Reps. Freeze protect Jumper line &flowline of S-13 w/ 7 bbls neat meth and 103 bbls crude per. WOA procedure. Final WHP's=0/0/0. • BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start: 9!212005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ' Task Code i ', NPT ' Phase Description of Operations 9/2/2005 00:00 - 01:00 1.00 MOB P PRE PJSM. Move Rig off Z-31 and move to middle of pad. 01:00 - 01:30 0.50 MOB P PRE PJSM. Unpinned and L / D Derrick. 01:30 - 03:30 2.00 MOB P PRE Remove BOPE Stack from cellar and place on pedestal. Install front and rear booster wheels. 03:30 - 10:30 7.00 MOB P PRE Move rig off Z-Pad and travel to S-Pad. 10:30 - 13:00 2.50 MOB P PRE Remove Front and Rear Booster Wheels. Remove BOPE from Transport Carrier and position on Cellar Pedestal. Inspect and raise Derrick. 13:00 - 15:00 2.00 MOB P PRE Center Rig over well and level up Rig. 15:00 - 16:00 1.00 WHSUR P DECOMP Checked IA Pressures, 50 psi, and bleed off. Installed Secondary Annulus Valve on IA. R/U Circulating Lines to Cellar Circulating Manifold and Tree to Displace Freeze Protection. Spot Slop Tank. Spot first truckload of 120 F seawater. Rig accepted ~ 1600 hours. 16:00 - 19:00 3.00 WHSUR P DECOMP Wait on 2 of 3 truckloads of 120 F seawater. 19:00 - 20:00 1.00 WHSUR P DECOMP R/U DSM Lubricator and Pull BPV. R/D and L/D Lubricator. Tubing on vac. 20:00 - 23:30 .3.50 KILL P DECOMP Vac Trucks on location. PJSM with rig crew and drivers on circ out procedures. Test lines to 2500 psi. Circulate out diesel freeze protect with 765 bbls 120 deg F seawater at 7.0 bpm at 530 psi. Had numerous slow downs in circulating rate to let vac trucks catch up on slop tank. Small leak from 13-3/8" by conductor annulus noticed after 75% of circulation completed. Approximately 2 qts leaked from annulus. Spill responce notified. 23:30 - 00:00 0.50 KILL P DECOMP Shut down and monitor well to confirm dead. Well on vac. 9/3/2005 00:00 - 01:30 1.50 WHSUR P DECOMP Blow down and rig down circulating {fines. Set TWC and pressure test to 1000 psi. 01:30 - 02:30 1.00 WHSUR P DECOMP Unable to get a good test on TWC. Check surface equipment for leaks. Surface equipment good. Pressure test again to 1000 psi, still leaking by. Consult with Cameron. Check and tighten all LDS and retest to 1000 psi. Good pressure test. 02:30 - 04:00 1.50 W HSUR P DECOMP N / D tree and adapter. 04:00 - 07:00 3.00 WHSUR P DECOMP Cycle all LDS. Initally 8 stuck prior to rig moving on well. Able to turn 7 free, sheared off neck on 8th, but removed and replaced it. 07:00 - 08:30 1.50 BOPSU P DECOMP Chase threads on BOP studs and change out the rented 13-5/8" Spacer Spool with new spool that will stay with Doyon 16. 08:30 - 12:00 3.50 BOPSU P DECOMP N/U BOP Stack, connect lines and prepare for BOPE Tests. 12:00 - 16:30 4.50 BOPSU P DECOMP PJSM; Test BOPE's: Test #1-Blind Rams, Choke Manifold valves 12, 13, and 14, and Kill HCR, 250 psi low / 4,000 psi high. Test #2- C/M valves 7, 9, 10, and 11, Kill Manual, 250 / 4,000. Test #3- C/M valves 2, 5, and 8. Test #4- C/M valves 3, 4, and 6, 250 / 4,000. Test #5- Upper IBOP, Choke HCR, 250 / 4,000. Test #6- Lower IBOP, Choke Manual, 250 / 4,000. Test #7- C/M valve #1, Dart valve, 250 / 4,000. Test #8- Lower Pipe Rams, TIW valve, 250 / 4,000. Test #9- Hydril, 250 / 3,500. All Tests held and recorded for 5 min. each. AOGCC Rep. Chuck Scheve waived witness of tests. Tests witnessed by BP Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To i Hours Task 'Code 9/3/2005 12:00 - 16:30 4.50 BOPSU~ P 16:30 - 17:00 0.50 BOPSU P 17:00 - 17:30 0.50 BOPSUFj P 17:30 - 18:00 0.50 PULL P 9/4/2005 9/5/2005 18:00 - 19:30 I 1.501 PULL I P 19:30 - 21:00 I 1.501 PULL I P 21:00 - 21:30 0.50 PULL P 21:30 - 00:00 2.50 PULL P 00:00 - 09:30 I 9.501 PULL I P 09:30 - 14:00 I 4.501 PULL I P 14:00 - 22:00 I 8.001 PULL I P 22:00 - 23:30 ~ 1.50 ~ PULL ~ P 23:30 - 00:00 I 0.501 PULL I P 00:00 - 01:00 1.00 PULL P 01:00 - 01:30 0.50 PULL P 01:30 - 07:00 5.50 PULL P 07:00 - 09:30 2.501 PULL P Page 2 of 14 Spud Date: 8/22/1982 Start : 9/2/2005 End: Rig Release: 9/21/2005 Rig Number: N1 NPT Phase ~ Description of Operations DECOMP Drilling Supervisor and Doyon Tool Pusher. DECOMP Drain Stack, clear and clean Rig Floor, prepare for POH w/ 5-1/2" string. DECOMP P/U DSM Lubricator, pull TWC, and R/ D DSM Lubricator. DECOMP M/U Baker Spear for 5-1/2" tbg onto joint of DP. Pick up, RIH, and engage tubing. DECOMP PJSM on pulling and laying down tubing hanger and tubing.. BOLDS and POOH with hanger and spear. Hanger pulled free with 220,000 lbs. Terminate control lines. B/O and UD tubing spear, DP, and tubing hanger. DECOMP R/U circulating equipment. Circulate bottoms up with 408 bbls, 8 bpm at 750 psi. Rig Up Camco spooling unit. Energize 9-5/8" pack-off and test to 3,800 psi for 30 minutes -good test. Function all LDS. DECOMP R/D circulating equipment. R/U to lay down tubing. DECOMP PJSM on laying down tubing. POOH and UD 5-1/2" L-80 tubing. DECOMP POOH and L / D 5-1/2" tbg. 1 SSSV, 2 x 1/4" Contol Lines, 25 bands and 3 clamps, and the 20.34' cut joint. The bottom -2,000' of tubing was covered with an 1/8" +/- layer of scale, and numerous corrosion pits. The cut is a typical, good quality Chemical cut. DECOMP M/U BHA: 8-1/S" FS 150 O/S w/ 5-1/2" Grapple, Bumper Sub, Super Jar, XO, 12-ea 6-1/4" DCs, XO, Intensifier Jar. Total Length = 412.97' DECOMP RIH w/ 8-1/8" O/S BHA on 4" DP. P/U DP from pipe shed and RIH 1x1, 279 jts. DECOMP Establish parameters; Up Weight = 200,000 Ibs, Down Weight = 150,000 Ibs, Rotating Weight = 175,000 Ibs @ 50 rpm's and 7,500 ft-Ibs torque. Establish Circulation, 3.4 bpm @ 280 psi. Rotate and wash down at 20 rpm's and 3.4 bpm. Pump pressure increase to 450 psi at 14' in on jt # 297 (9324'). Shut down pump and rotatary. Set down another 3' to swallow stub and engage O/S Grapple. P / U to jar, found not latched onto fish. Wash and rotate back down hole. Pump pressure increased, shut down pumps and rotary and tag up 18' in on #297 (9328'). P / U to jar, latched onto fish. Start w/jar licks at 250,000 Ibs with straight pulls to 300,000 Ibs. Work up to jar licks of 350,000 Ibs and straight pulls of 400,000 Ibs. DECOMP Pull free. Up Weight slightly higher, -205,000 Ibs. Hard to tell if grapple came free or pulled fish free. RIH and try to re-engage grapple. POH, still free. Up Weight still slightly higher. Try to establish circulation, pressured up immediantly, unable to circulate down tubing. Have fish. DECOMP Monitor well and inspect Derrick. DECOMP Service Top Drive and Rig. DECOMP B / O and B / D Top Drive. POOH and stand back DP and DCs in Derrick. DECOMP B/O and UD fish: 22.85' Cut joint, one full joint, one collapsed pup joint, GLM #2, and 2' of the Pup Joint below the GLM. Top of Collapsed Tubing Stub is 9,414'. The tubing parted circumferentially, but in a fully collapsed section, making 90-degree cross-section. Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ', From - To 9/5/2005 09:30 - 10:30 10:30 - 12:30 12:30 - 16:00 16:00 - 18:00 18:00 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 9/6/2005 00:00 - 01:00 01:00 - 02:00 02:00 - 06:30 06:30 - 09:30 S-14 S-14 WORKOVER Start: 9/2/2005 NORDIC CALISTA Rig Release: 9/21/2005 NORDIC 1 Rig Number: N1 Hours I~, Task Code ~ NPT Phase Page 3 of 14 Spud Date: 8/22/1982 End: Description of Operations 1.00 PULL P ~ DECOMP Clear and clean Rig Floor, B/O and UD Overshot and fish. 2.00 PULL P DECOMP M/U BHA:8-1/8" O/S w/ 6-1/8" Grapple, 4-ea Extensions, Bumper Sub, Oil Jars, 12-ea DCs, Intensifier Jar. 3.50 PULL P DECOMP RIH on DP from Derrick and tag ~ -9,410', RKB. 2.00 PULL P DECOMP Parameters: P/U wt 200K, S/O wt 154K, Rot wt 175K, 20 RPM, 30 SPM, 240 psi. Slowly lower and slip over Stub. See Torque Wrap-up to 25K and begin to stall out, then release. Repeat and gain 3-4' of swallow. P/U and set-off jars w/ 250K, lose fish. Repeat this cycle several times and make same headway and lose fish @ 250k to 270K, each time. Call Town, decide to POOH. 4.00 PULL P DECOMP POOH with 4" DP and stand back in derrick. Stand back jars and DC's. 0.50 PULL P DECOMP Break Out Overshot. Found lip of Overshot curled under and cracked. 1.00 PULL P DECOMP Clean and Clear Rig Floor. 0.50 PULL P DECOMP Service Top Drive. Wait on BOT Fishing Tools. 1.00 PULL P DECOMP Wait on Baker Fishing Tools to arrive from Deadhorse. PJSM on M/U BHA. 1.00 PULL P DECOMP M/U BHA #4. 8-1/4" x 6-1/4" Burn Shoe> 3 jts of Wash Pipe Extensions, Boot Basket, Oil Jar, 12-Jts 6-1/4" DC's. Total BHA Length = 406.46' Can Swallow 16.46'. 4.50 PULL P DECOMP RIH w/ BHA #4 on 4" DP from derrick. 3.00 FISH P DECOMP Mill Parameters: Top of Fish @ 9408', WOM 1,600 Lbs, 60 RPM, 60 SPM, 820 psi. Mil{ with iow WOM. Milled -8' that appeared to be cutting metal, did not observe Burn Shoe over collar or pipe below. The Shoe ID = 6-1/4" and the Collar OD = 6-3/16". Picked Up with 20,000# overpull, lost overpull. RIH did not observe Mills stacking out on fish. Repeated 5-more times with same results. Pumped two 20-Bbl Sweeps: @ 0730 hrs and 0830 hrs. Did not see any cuttings over Shakers. Milled from 9,408' to 9,416'. 09:30 - 11:30 2.00 FISH P DECOMP Pump 40 Bbls Hi-Vis Sweep 11:30 - 12:00 0.50 EVAL P DECOMP Monitor well; dead. Blow Down Top Drive. 12:00 - 15:00 3.00 FISH P DECOMP POH w/ 4" DP 15:00 - 16:30 1.50 FISH P DECOMP POH w/ BHA #4; Standback 12 x 6-1/4" DC's; UD 8-1/4" x 6-1/4" Burn Shoe 16:30 - 18:00 1.50 FISH P DECOMP M/U BHA #5; 8-1/8" x 6-1/4" Overshot w/ 6-1/8" Grapple, 4 x 8-1/8" Overshot Extensions, Overshot Top Sub, Bumper Sub, Oil Jar, XO, 12 x 6-1/4" DC's, XO, Intensifier Jar, XO. Total BHA Length = 423.76' 18:00 - 21:00 3.00 FISH P DECOMP RIH w/ 4" DP to Top of Fish at 9,416' 21:00 - 22:00 1.00 FISH P DECOMP M/U Top Drive, Obtain Parameters, String Weight Up 203,000#, String Weight Down 157,000#, Rotating Weight.175,000#, Rotary 30 RPM w/ 5000 fUlbs Torque., 30 SPM w/ 220 psi. Rotate down over top of fish at 9,416'. Observed Intermittent 14,000 ft/Ibs Torque when Rotating Down. No Pump Pressure Increase Observed. S!O to 125,000#, P/U to 205,000#; Slipped off fish, Rotate down to 125,000#, P/U to 250,000#, S/O to 120,000#, P/U to 260,000#, Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ;Code NPT Phase j Description of Operations 9/6/2005 21:00 - 22:00 1.00 FISH P DECOMP 22:00 - 00:00 2.00 FISH P DECOMP 9/7/2005 00:00 - 01:30 1.50 FISH P DECOMP 01:30 - 03:00 1.50 FISH P DECOMP 03:00 - 03:30 0.50 FISH P DECOMP 03:30 - 05:30 2.00 FISH P DECOMP 05:30 - 10:30 5.00 FISH P DECOMP j 10:30 - 11:30 1.00 FISH P I DECOMP 11:30 - 12:30 1.00 FISH P DECOMP 12:30 - 13:30 1.00 FISH P ~ DECOMP 13:30 - 14:30 1.00 FISH P DECOMP 14:30 - 17:00 2.50 FISH P DECOMP 17:00 - 18:00 1.00 FISH P DECOMP 18:00 - 20:00 2.00 FISH P DECOMP 20:00 - 00:00 4.00 FISH P ' DECOMP 9/8/2005 00:00 - 01:30 1.50 FISH P DECOMP 01:30 - 03:30 2.00 FISH P DECOMP Jar, O/S slipped off. Work down to 125,000# multiple times, would not latch onto fish. Monitor Well-Static. Blew Down Top Drive POH w/ Overshot BHA on 4" DP POOH w/ 4" DP. POOH w/ 8-1/8" x 6-1/4" Overshot /Grapple BHA; Stood back 12 x 6-114" DC's, B ! O Overshot Shoe and Grapple Extension. Recovered 4' Piece of Collapsed 5-1/2" Tubing. Cleaned and Cleared Rig Floor. Held PJSM. M / U 8-1/4" X 6-1/4" Burn Shoe Mill Dresssing BHA: Washover Shoe, 3 Joints 8-1/8" Washover Pipe, Drive Sub/ Boot Basket, Bumper Sub, Bowen Super Jar, XO, 12 x 6 1/4" Drill Collars, XO. BHA Total Length = 492.04'. RIH w/ Dressing BHA on 4" DP to 9,330'. Established Parameters: String Weight Up 205,000#, String Weight Down 150,000#. RIH to 9,416'. M / U Top Drive, Engaged Pump, 4 bpm, 350 psi. Washed Down to 9,471', Mill Took Weight at 9,471', Stacked 3,000# on Mill. P / U to 9,421', Engaged Rotary, 30 rpm, Torque 5,000 ft /Ibs, Rotating Weight 175,000#. Washed and Reamed Down from 9,421' to 9,513'. From 9,471' to 9,500' Mill Took Intermittent Weight, 3,000# - 4,000#, w/ 8,000 - 10,000 ft /Ibs Torque. Pumped and Circulated Around 40 bbl Hi-Vis Sweep. 10 bpm, 1,650 psi. Shut Down Pump, Monitored Well, Static. Blew Down Top Drive. POOH w/ 4" DP to 8,550'. Held PJSM. Slipped and Cut Drilling Line. POOH w/ 4" DP to 492' POOH w/ 8 1/4" x 6 1/4"" Burn Shoe Mill, Stand back 12 x 6 1/4" DC's, B!O and L/D Jars, Bumper Sub, Boot Basket onto Skate. C/O elevators to Washpipe style. POOH w/ Washpipe and B/0 Burn Shoe. Held PJSM. M/U 8 1/8" Outside Cutter, 3 Joints 8 1/8" Washover Pipe, Drive Sub /Boot Basket, Bumper Sub, Bowen Super Jar, XO, 12 x 6 1/4" DC's, XO. BHA Total Length = 494.63' RIH w/ Outside Cutter BHA on 4" DP U 6446' RIH w/ 8-1/8" Outside Cutter BHA on 4" DP U 9,425' M / U Top Drive; Established Parameters; String Weight Up 197,000#, String Weight Down 152,000#, Rotary String Weight 175,000#, Pump 3.5 bpm, 160 psi, Rotary 35 rpm, Torque 5,000 ft /Ibs. Washed and Rotated Down t/ 9,425' - U 9,515'. P / U to 9,509'. Observed Torque Increase to 7,500 fUlbs. Allowed Torque to Level Back Off to 5,000 ft /Ibs. Increased Overpull to 2,000#, Torque Increased to 7,500 ft /Ibs. Keep Torque at 7,500 ft /Ibs by Increasing Overpull to 5,000#, Depth 9,506'. No Indication of Cutting Tubing, No Torque Reduction or Weight Loss. S / O to 9,509', Allowed Torque to Stablize at 5,000 ft/Ibs. Increased Rotary to 45 rpm, P / U t/ 9,506', Increased Overpull to 10,000#, Torque Increased to 10,000 ft / lbs. No Torque Reduction or Weight Loss. Decision Made to POOH and Inspect Cutter. Monitored Well, Static. 81ew Down Printed: 9/26/2005 9:40:20 AM r~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 WORKOVER NORDIC CALISTA NORDIC 1 Date i From - To I Hours Task ~ Code' NPT 9/8/2005 01:30 - 03:30 2.00 FISH P 03:30 - 07:00 3.50 FISH P 07:00 - 08:30 1.50 FISH P 08:30 - 09:30 1.00 FISH P 09:30 - 11:00 1.50 FISH P 11:00 - 16:00 16:00 - 18:00 5.00 FISH P 2.00 FISH P 18:00 - 21:00 21:00 - 22:00 22:00 - 00:00 9/9/2005 00:00 - 00:30 00:30 - 01:00 01:00 - 01:30 01:30 - 04:30 04:30 - 05:00 05:00 - 08:30 08:30 - 10:00 10:00 - 10:30 10:30 - 12:00 3.00 FISH P 1.00 FISH P 2.00 FISH P 0.50 FISH P 0.50 FISH P 0.50 FISH P 3.00 FISH P 0.50 FISH P 3.50 FISH P 1.50 FISH P 0.50 FISH P 1.50 FISH P Page 5 of 14 Spud Date: 8/22/1982 Start: 9/2/2005 End: Rig Release: 9/21/2005 Rig Number: N1 Phase '' Description of Operations DECOMP Top Drive. DECOMP POOH w/ 4" DP. DECOMP POOH w/ BHA. B / O and L / D Jars and Bumper Sub. R / U 8-1/8" Wash Pipe Handling Equipment. POOH w/ Wash Pipe, Inspected Outside Cutter, All Knives Broken and / or Missing. DECOMP Cleared and Cleaned Rig Floor. DECOMP Held PJSM. M / U BHA: New 8 1/8" x 5-7/8" Outside Cutter, 3 Joints 8 1/8" Washover Pipe, Drive Sub /Boot Basket, XO, 12 x 6 1/4" DC's, XO. BHA Total Length = 475.06'. DECOMP RIH w/ Cutter BHA on 4" DP to 9,404'. DECOMP M / U Top Drive; Established Parameters; String Weight Up 195,000#, String Weight Down 155,000#, Rotary String Weight 173,000#, Pump 4 bpm, 310 psi, Rotary 30 rpm, Torque 4,000 ft / lbs. Washed Down f/ 9,404' - t/ 9,514'. P / U to 9,513'. Engaged Rotary 35 rpm, Torque 4,500 ft / lbs. P / U t/ 9,506' w/ 2,500# Overpull. Torque 6,500 - 7,500 ft / lbs. P/ U w/ 5,000# Overpull, Torque 7,500 - 8,000 ft / lbs. P / U to 9,000# Overpull, Torque 9,000 ft / lbs. Increased Rotary to 60 rpm, Torque 9,000 - 10,500 ft / lbs. No Indication of Cut Being Made. Decision was Made to POOH. Monitored Well, Static. Blew Down Top Drive DECOMP POOH w/ 4" DP DECOMP POOH w/ Outside CUtter BHA; Standback 12 x 6-14" DC's, B/O and UD Jars and Bumper Sub and Drive Sub /Boot Basket, Observed 5-1/2" Tubing in Washpipe. DECOMP PJSM-Removing Tubing Fish from Washpipe; POH w/ 1st Joint of Washpipe, B/O and UD Top Joint of 5-1/2" Tubing w/ Tugger. Remove Bottom Tubing Joint from Washpipe and UD Same, UD Washpipe and Outside Cutter, All Knives Broken. Length of Recovered Tubing, 1.55' Tubing Stub, 42.94' Jt., 40.48' Jt., 3.00' Cut Off Joint. Total Recovered = 87.97'. DECOMP P / U Bumper Sub and Jars from Pipeshed, B / O and UD Same. P / U, B / O and L / D Grapple and Washpipe Assy. DECOMP Cleared and Cleaned Rig Floor. DECOMP Strapped and Tallied 2-7/8" Motor, DP, and XO's. R / U 2-7/8" Handling Equipment and Tongs. DECOMP Held PJSM. M / U 2-7/8" Motor Inside Cutter BHA: Inside Tubing Cutter Motor Assy, 5 x 2-7/8" PAC DP, XO, XO. Total BHA Length =185.13'. DECOMP R / D 2-7/8" Handling Equipment, C / O Elevators, Cleared Floor of Excess Tools. DECOMP RIH w/ Inside Tubing Cutter BHA on 4 " DP to 9,505'. DECOMP M / U Top Drive, Established Parameters: String Weight Up 175,000#, String Weight Down 145,000#. RIH to 9,590', Broke Circulation, 2.4 bpm, 350 psi. Shut Down Pump, Broke Out Connection, Dropped By-Pass Sub Ball, M / U Connection and RIH to Cut Depth of 9,665'. Pumped Ball Down on Seat, 1 bpm, 60 psi. Pressured up to 1,230 psi and Shut By-Pass Sub. DECOMP Inside Tubing Cutter at 9,665', Engaged Pump Initial Rate 0.50 bpm, 600 psi, Final Rate 1.5 bpm, 3,400 psi. Cut Tubing, Shut Down Pump. P / U on Drill String, No Overpull or Drag. DECOMP B / O Top Drive, Dropped Circulating Sub Ball, M / U Top Drive and Set Cutter Back on Depth at 9,665'. Pumped Ball on Seat, Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: S-14 Common W ell Name: S-14 Spud Date: 8/22/1982 Event Nam e: WORKO VER Start : 9/2/2005 End: Contractor Name: NORDIC CALIST A Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To 'I Hours Task + Code NPT ~ Phase Description of Operations - - - -- _ _ -- - - -- -- 9/9/2005 10:30 - 12:00 1.50 FISH P DECOMP 1 bpm, 2,150 psi. Pressured Up to 3,100 psi, Opened Circulating Sub. Circulated Bottoms Up, 10 bpm, 2,350 psi. Shut Down Pump, Monitored Well, Static. Blew Down Top Drive. 12:00 - 15:30 3.50 FISH P DECOMP POOH w14" DP. 15:30 - 16:00 0.50 FISH P DECOMP R / U 2-7/8" Handling Equipment, C / O Elevators 16:00 - 17:30 1.50 FISH P DECOMP Held PJSM, L / D 2-7/8" PAC DP, and 2-7/8" Inside Cutter Motor Assembly. 1 Knife Broken, 2 Slightly Worn. B/O and UD 8-1/8" Cut Lip Guide and Overshot Guide Washpipe Extensions. 17:30 - 18:00 0.50 FISH P DECOMP Cleared and Cleaned Rig Floor 18:00 - 19:00 1.00 FISH P DECOMP PJSM-P/U and M/U 5-1/2" Grapple Fishing BHA; Overshot, Bumper Sub, Oil Jar, XO, 12 x 6-1/4" DC's, XO, Intensifier Jar, XO. Total BHA Length = 412.97' 19:00 - 21:30 2.50 FISH P DECOMP RIH w/ Fishing BHA on 4" DP t/ 9,150' 21:30 - 22:30 1.00 FISH P DECOMP Slip and Cut Drilling Line 22:30 - 00:00 1.50 FISH P DECOMP RIH U 9,450'. M/U Top Drive, Established Parameters, String Weight Up 200,000#, String Weight Down 151,000#, Rotary String Weight 175,000#, Pump 2.5 gpm, 130 psi, Rotary 20 rpm, 3,500 ft/Ibs Torque. Rotate Down U 9,505 w/ 20 rpm, 4,000 ft/Ibs. Observed Pressure Increase to 475 psi, Torque Increased to 5,000 ft/bs, Shut Down Pump and Bleed Down Pressure. Continue to Rotate Down t/ 9,507. Shutbown Rotary, S/O to 130,000#, P/U to 250,000#, Set Off Jars, Straight Pull to 275,000#. Continue to Jar Increasing Up Weight By 25,000# Increments Until Jar Up weight was 350,000# with 375,000# Straight Pull. Engage Pump and Pressure Up to 750 psi with 50 psi Bleed Down. Bled Off Pressure and Continue to Jar with 350,000# Jar Up Weight , 375,000# Straight Pull. Decision was Made to Recut Tubing. Released Grapple, Monitor Well-Static. Blew Down Top Drive. 9/10/2005 00:00 - 04:00 4.00 FISH P DECOMP POOH w / 5-1/2" Grapple Fishing BHA on 4" DP 04:00 - 05:30 1.50 FISH P DECOMP PJSM-POOH w! BHA; Bi0 and UD 6 x 6-1/4" DC's, Stand Back 6 x 6-1/4" DC's, B/O and UD Bumper Sub, Oil Jars and 8-1/8" Overshot w/ 5-1/2" Grapple 05:30 - 06:30 1.00 FISH P DECOMP Cleared and Cleaned Rig Floor. Performed Derrick Inspection. 06:30 - 08:30 2.00 FISH P DECOMP Held PJSM. M / U Inside Cutter BHA: Inside Tubing Cutter, 3-5/8" Xtreme Motor, By-Pass Sub, Circulating Sub, Double Pin Sub, Shear Guide, 5 x 2-7/8" PAC DP, XO, XO. Total BHA Length =182.10'. 08:30 - 09:00 0.50 FISH P DECOMP R / D 2-7/8" Handling Equipment, C / O Elevators, Cleared Floor of Excess Tools. 09:00 - 11:30 2.50 FISH P DECOMP Repaired Hydraulic Line on Top Drive. 11:30 - 14:30 3.00 FISH P DECOMP RIH w/ Inside Tubing Cutter BHA on 4 " DP to 9,400'. 14:30 - 17:00 2.50 FISH P DECOMP M / U Top Drive, Established Parameters: String Weight Up 175,000#, String Weight Down 150,000#, Rotating Weight 157,000, RPM 20, Torque 2,500 ft / lbs. RIH to 9,590', Broke Circulation, 1.5 bpm, 80 psi. Shut Down Pump, Broke Out Connection, Dropped By-Pass Sub Ball, M / U Connection and RIH to Cut Depth of 9,668'. Pumped Ball Down on Seat, 1 bpm, 70 psi. Observed Ball on Seat Pressure Increased to 4,000 psi, No Drop in Pressure. Shut Down Pump, Bled Off Pressure. Engaged Pump Rate 0.50 bpm, Pressure Increased Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ~' Task Code ~i NPT Phase II Description of Operations __ --- - 9/10/2005 14:30 - 17:00 2.50 FISH P DECOMP to 4,000 psi, Shut Down Pump, Bled Off Pressure. Engaged Pump Rate 0.75 bpm, Pressure Increased to 4,000 psi. Shut Down Pump, Bled Off Pressure. Engaged Pump Rate 1.0 bpm, Pressure Increased to 4,000 psi. Shut Down Pump, Bled Off Pressure. Engaged Pump Rate 1.50 bpm, Pressure Increased to 4,000 psi. Shut Down Pump, Bled Off Pressure. Engaged Rotary, 20 rpm, Torque 2,500 ft /Ibs, Engaged Pump Rate 0.75 bpm, Torque Increased 3,500 - 4,000 ft /Ibs, Pressure Increased to 3,650 psi. Continued to Rotate Drill String, Torque Decreased to 3,000 ft /Ibs. Pressure Decreased to 3,510 psi. Continued to Rotate at 20 rpm, Torque 3,500 ft /Ibs, Pump Pressure 3,550 - 3,600 psi. Shut Down Pump, P / U on Drill String, No Overpull or Drag. 17:00 - 18:30 1.50 FISH P DECOMP B / O Top Drive, Dropped Circulating Sub Ball, M / U Top Drive and Set Cutter Back on Depth at 9,668'. Pumped Ball on Seat, 1 bpm, 2,150 psi. Pressured Up to 3,220 psi, Opened Circulating Sub. Holding 3,220 psi at 2.8 bpm. Suspect Restriction in Pump Out Sub. Pump DP Volume, 104 bbls, at 2.8 bpm. Shut Down Pump, Monitored Well, Static. Blew Down Top Drive. 18:30 - 21:30 3.00 FISH P DECOMP POOH w/ Inside Cutter on 4" DP 21:30 - 23:30 2.00 FISH P DECOMP PJSM-POOH w/ BHA; B/O and L/D 5 x 2-7/8" PAC DP, L/D 2-7/8" Motor and Inside Cutter, All Knives and Wear Pads Worn. B/O and L/D Washpipe Guide. 23:30 - 00:00 0.50 FISH P DECOMP Cleared and Cleaned Rig Floor. Remove All Excess Tools and Excess Handling Equipment from Rig Floor 9/11/2005 00:00 - 00:30 0.50 FISH P DECOMP P/U Test Joint, Remove Wear Ring and Install Test Plug, R/U BOPE Test Equipment 00:30 - 03:30 3.00 FISH P DECOMP Test BOPE's; Test # 1-C/M Valves 12,13 and 14, 250 psi low / 4,000 psi high Test # 2-C/M Valves 9 and 11, 250 psi low / 4,000 psi high Test # 3-C/M Valves 5, 8 and 10, 250 psi low / 4,000 psi high Test # 4-C/M Valves 4, 6 and 7, 250 psi low / 4,000 psi high Test # 5-C/M Valve 2, 250 psi low / 4,000 psi high Test # 6-C/M Valve 3, 250 psi low / 4,000 psi high Test # 7-Hydril, 250 psi low / 3,500 psi high Test # 8-Lower IBOP, Dart and Pipe Rams, 250 psi low / 4,000 psi Test # 9-Upper IBOP, Floor Safety Valve, 250 psi low / 4,000 psi high Test # 10-Blind Rams and Kill HCR, 250 psi low / 4,000 psi high Test # 11-Manual Kill, 250 psi low / 4,000 psi high Test # 12-C/M 1, 250 psi low / 4,000 psi high Test # 13-Choke HCR, 250 psi low / 4,000 psi high Test # 14-Manual Choke, 250 psi low / 4,000 psi high Tests Held f/ 5 Min. All Pressure Tests Held w/ No Leaks or Pressure Loss. Witness of Test Waived by AOGCC Rep. Lou Gramaldi. All Tests Witnessed BP Drilling Supervisor and Doyon Tool Pusher. 03:30 - 04:00 0.50 FISH P DECOMP Pulled Test Plug, Installed Wear Bushing, L / D Test Joint and R / D Test Equipment. Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 Date 'From - To 9/11/2005 104:00-05:30 Hours I Task ' Code I NPT Phase Description of Operations 05:30 - 08:30 08:30 - 11:30 11:30 - 13:30 13:30 - 19:00 19:00 - 19:30 19:30 - 21:30 21:30 - 22:00 22:00 - 23:00 23:00 - 00:00 9/12/2005 00:00 - 02:30 02:30 - 05:30 05:30 - 09:00 1.50 FISH P DECOMP Held PJSM-P / U and M / U BHA: 8-1/8" Overshot w/ 5-1/2" Grapple, Bumper Sub, Oil Jar, XO, 6 x 6-1/4" DC's, XO, Intensifier Jars, XO. Total BHA Length = 229.11'. 3.00 FISH P DECOMP RIH w/ Overshot BHA on 4" DP to 9,444'. 3.00 FISH P DECOMP M / U Top Drive, Established Parameters: String Weight Up 190,000#, String Weight Down 150,000#, String Weight Rotating 167,000#, RPM 20, Torque 3,500 ft /Ibs, Pump Rate 4 bpm, 350 psi. RIH, Washed Down to 9,506', Tagged Top of Tubing Stub at 9,506'. RIH, Swallowed Tubing Stub, Stacked 20,000# on Tubing to Ensure Grapples Engaged. P / U to 250,000#, No Movement. Jarred on Tubing w/ 160,000# Overpull and Straight Pull w/ 210,000# Overpull, No Movement. Continued Jarring f/ 60 Minutes w/ No Movement. Engaged Pump 2.5 bpm, 2,600 psi. Attempted to Release from Fish. Jarred Down to Release Grapples, Rotated and P / U on Drill String to Release from Fish. P / U to 9,474' w/ 40,000# Drag and 10,000 to 15,000 ft /Ibs of Torque. Engaged Pump, 4 bpm, 2,130 psi. With Pump Engaged, Torque Increased and Stalled Rotary. Shut Down Pump and Bled Off Pressure, Regained Rotary w/ 10,000 - 15,000 ft /Ibs of Torque.Continued to Rotate and P / U on Drill String to 9,444', 20 rpm, Torque 5,000 - 15,000 ft /Ibs. Engaged Pump 3 bpm, 270 psi. Increased Pump Rate, 5 bpm, 620 psi, 7 bpm, 1,030 psi. 2.00 FISH P DECOMP Circulated 1-1/2 x Bottoms Up. 10 bpm, 2,050 psi. Circulated Up Small Amount of Gas w/ Large Amount of Control Line Rubber and Fine Sand. Continued to Circulate Until Returns Cleaned Up. Note: When Gas was Observed at Surface, Driller Shut Down Pump and Closed Annular w/ 0 psi on DP and 0 psi on Casing. Opened Choke w/ No Flow. Opened Annular, No Flow, Slight Gas Perculation. Engaged Pump and Finished Circulating Bottoms Up. Notified AOGCC. 5.50 FISH P DECOMP POOH w/ 4" DP, Average Drag 20,000# - 25,000#. Experienced Intermittent Overpull of 50,000#, M / U Top Drive, Rotated and P / U on Drill String to POOH Past Overpull. 0.50 FISH P DECOMP POOH w/ Overshot BHA; Standback 6 x 6-1/4" DC"s, B/O and UD Bumper Sub, Oil Jars. 2.00 FISH P DECOMP PJSM-R/U 5-1/2" Power Tongs, UD Grapple Assy. and Cut Off Joint. C/O DP Elevators to 5-1/2" Tubing Elevators. POH w/ Tubing Fish. Recovered 1 Cut Off 5-1/2"Jt Tubing, 2 x 5-1/2" Jts. Tubing, 1 GLM, 1 Sliding Sleeve and SBR w/ K-Anchor Attached. Recovered 210.60' Total, not Counting K-Anchor 0.50 FISH P DECOMP Cleaned and Cleared Rig Floor 1.00 FISH P DECOMP PJSM-P/U Grapple Assy. and Cut Joint, B/O and UD same 1.00 CLEAN P CLEAN Stock Rig Floor With BHA Clean Out Tools, Strap and Tally Same 2.50 CLEAN P CLEAN PJSM-P/U and M/U Clean Out BHA; 2-7/8" Mule Shoe, 8-1/2" Rotary Shoe, Drive Sub /Boot Basket, XO, 9-5/8" Scraper, 2 x 7" Boot Baskets, XO, Bumper Sub, Oil Jar, XO, 6 x 6-1/4" DC's, XO, Intensifier Jar, XO. Total BHA Length = 253.20' 3.00 CLEAN P CLEAN RIH w/ Clean Out BHA on 4" DP U 9,662' 3.50 CLEAN P CLEAN M / U Top Drive and Established Parameters; String Weight Up 192,000#, String Weight Down 153,000#, Rotary String Weight Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 i, Date I From - To Hours ~, Task Code NPT 9/12/2005 ~ 05:30 - 09:00 3.50 ~ CLEAN ~ P 09:00 - 10:00 1.00 ~ CLEAN P 10:00 - 14:00 4.00 CLEAN P 14:00 - 16:30 2.50 CLEAN P 16:30 - 18:00 1.50 EVAL P 18:00 - 23:30 I 5.50 I EVAL I P 23:30 - 00:00 I 0.501 EVAL I P 9/13/2005 ~ 00:00 - 00:30 ~ 0.50 ~ EVAL P Phase '; Description of Operations CLEAN_ -._ - -- --- - - -- 170 000# Pump 5 bpm 630 psi. Rotary 20 rpm 4 000 ft /Ibs CLEAN CLEAN CLEAN DECOMP DECOMP DECOMP DECOMP 00:30 - 01:00 0.50 EVAL P DECOMP 01:00 - 01:30 0.50 EVAL P DECOMP 01:30 - 06:30 5.00 EVAL P DECOMP 06:30 - 08:30 2.00 EVAL P DECOMP 08:30 - 17:30 9.00 EVAL P DECOMP 17:30 - 18:00 0.50 EVAL P DECOMP 18:00 - 19:30 1.50 EVAL P DECOMP 19:30 - 00:00 I 4.501 EVAL I P I I DECOMP Torque. Rotated and Washed Down from 9,662' w/ 40 rpm, 5,000 fUlbs Torque, Tagged Packer at 9,718' Observed Torque Increase to 7,500 ft /Ibs, No Pressure Increase, P / U U 9,710'. Rotated Back Down to Confirm Packer Depth at 9,718'. Torqued Increased to 10,000 ftlbs. P / U to 9,715' and Increased Pump Rate to 10 bpm at 2,250 psi. Pumped and Circulated Around 40 bbl Hi-Vis Sweep at 10 bpm, 2,250 psi. Circulated a Total 3 x Bottoms Up. Circulated Back Some Gas and Abundant Control Line Rubber. Note: When Gas was Observed at Surface, Driller Shut Down Pump and Closed Annular w! 0 psi on DP and 0 psi on Casing. Opened Choke w/ No Flow. Opened Annular, No Flow, Slight Gas Perculation. Engaged Pump and Finished Circulating Bottoms Up. Notified AOGCC. Shut Down Pump and B / O Top Drive. R / U to Reverse Circulate, RIH to Place 2-7/8" Mule Shoe 3' Inside Packer. Engaged Pump and Reverse Circulated 2 x Bottoms Up. 10 bpm, 2,780 psi. Circulated Back Some Sand. Continued to Circulate Until Returns were Clean. POOH w/ 4" DP. POOH, B / O and L / D Entire BHA. Held PJSM w/ Rig Crew, Schlumberger Slickline Crew, Tool Pusher and Drilling Supervisor. R / U Schlumberger Slickline Equipment. M / U 8.5" Gauge Ring and Junk Basket on Slickline. RIH w/ 8.5" Gauge Ring /Junk Basket. Stopped at -40', Made 3 Attempts w/ Overpulls of 500#, 600# and 700#. Install 8.475" Gauge Ring /Junk Basket and RIH U 9,715'. Recovered 2 Small Pieces of Control Line Rubber and Small Amount of Shale. C/O 8.475" Gauge Ring !Junk Basket with 3.68" Gauge Ring /Junk Basket and RIH U 9,799'. Junk Basket Empty. PJSM-R/D Schlumberger Slickline Tools, Sheaves and Lubricator. L / D Schlumberger Slickline Tools. Removed Lubricator from BOPE's and L / D Same Cleaned and Cleared Rig Floor Held PJSM, M / U Halliburton 9-5/8" RTTS. RIH w/ 9-5/8" RTTS on 4" DP to 9,700'. M / U Top Drive, Established Parameters: String Weight Up 175,000#, String Weight Down 145,000#. RIH to 9,705', Engaged Pump and Broke Circulation. Shut Down Pump, Set 9-5/8" RTTS at 9,705'. Tested Lines to 4,000 psi, OK. Closed Pipe Rams and Tested 9-5/8" Casing to 4,000 psi f! 30 Minutes on Chart, OK. Bled Down Pressure, Blew Down Lines, Monitored Well, Static.Opened Rams, Released RTTS Packer. Held PJSM. POOH, L / D 4" DP. B/O and L/D Halliburton 9-5/8" RTTS Held PJSM w/ Rig Crew, Schlumberger Wireline Crew, BP Drilling Supervisor and Doyon Tool Pusher. Install Lubricator, R/U Wireline Sheaves, String Wireline and M/U Logging Tools RIH w/ USIT / CL / GR on Schlumberger E-Line U 9,700'. Logged Up and Located Top Of Cement at 2,670'. POH w/ Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start: 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To !Hours Task Code; NPT Phase 9/13/2005 19:30 - 00:00 4.50 EVA~P ~ DECOMP 9/14/2005 00:00 - 01:00 1.00 EVAL P DECOMP 01:00 - 03:30 2.50 BUNCO RUNCMP 03:30 - 04:30 1.00 BUNCO RUNCMP 04:30 - 18:30 14.00 BUNCO RUNCMP 18:30 - 00:00 I 5.501 RUNCON~P I I RUNCMP 9/15/2005 ~ 00:00 - 00:30 ~ 0.50 ~ EVAL ~ N ~ ~ DECOMP 00:30 - 02:00 I 1.501 EVAL I N I I DECOMP 02:00 - 03:30 I 1.501 EVAL I N I I DECOMP 03:30 - 12:30 I 9.001 EVAL I N I I DECOMP 12:30 - 15:30 I 3.001 EVAL I N I I DECOMP 15:30 - 16:00 I 0.501 EVAL I N f I DECOMP 16:00 - 17:00 I 1.001 EVAL I N I I DECOMP Description of Operations Logging Tools Remove Lubricator, B/O and UD USIT / CL / GR Logging Tools. R/D Wireline Sheaves, Remove Excess E-Line Equipment from Rig Floor Held PJSM-M/U Tubing Hanger XO to Landing Joint and Torque Same. CIO Bails, R / U Tubing Elevators and Hung Compensator. R / U Power Tongs and Torque Turn Equipment. M / U 4-1/2" 12.6# L-80 TC II Tail Pipe Assembly: Mule Shoe Joint - Lower X Nipple Assy w/ RHC-M Sleeve - 9-5/8" x 4-1/2" Baker S-3 Packer Assy - Upper X Nipple Assy. Bakerlocked All Connections Below Packer. P / U All Assy's w/ Compensator, Torque Turned All Connections. M / U Torque 3,850 ft / lbs. Doped Connections Above Packer w/Jet Lube Seal Guard. RIH w/ 232 Joints 4-1/2" 12.6# L-80 TC II Tubing. P / U Joints w/ Compensator, Torque Turned All Connections. M / U Torque 3,850 ft / lbs. Doped Connections w/Jet Lube Seal Guard. M/U Joint # 233 and Established Parameters; String Weight Up 141,000#, String Weight Down 124,000#. RIH for Space Out Measurments. Tagged at 9,720'. Recriprocate Tubing and Attempt to Work By 9,720' w/o Success. Apply Turns to Right and Try to Work Past 9,720' w/o Success. P/U and Rotate Down w/ Power Tongs w/o Success. L / D Jt #, #233, #232 and #231. M / U Space Out Pup Joints, M / U Jt #231. M / U Tubing Hanger Assy. and Landing Jt. M/U Top Drive to Landing Joint.. Established Circulation at 3 bpm, 80 psi. Attempted to Rotate Down with Top Drive Past 9,720' w!o Success. POH and B/O and VD Tubing Hanger and Joint # 233. C/O 1 Pup Joint. P/U Joint # 233, Tubing Hanger and Landing Joint. Landed at 9,718'. RILDS and B/O and UD Landing Joint Held PJSM w/ Rig Crew, Schlumberger Slickline Crew, BP Dri{ling Supervisor. Doyon Tooi Pusher. Install Lubricator, R/U Slickline Sheaves and String Wire. M/U RHC Sleeve Retrieving Tool and RIH. Latch Sleeve and POH w/ Same M/U 3.5 Drift and RIH. Drift Stopped at 9,736'. Multiple Attempts Made to Drift Past 9,736' w/o Success. POH w/ Drift M/U 2.75 Drift /Bailer and RIH 9,736'. Worked Down t/ 9,740'. POH w/ Drift /Bailer. Recovered 1/2 Gal. Sand /Paraffin. Rerun 2.75 Drift /Bailer and TaggedUp at 9,740', Worked Down t/ 9,744'. POH, Recovered 1 Gal. Sand / Pararffin. Rerun 2.75 Drift /Bailer, Tagged Up at 9,744'. Attempted to Work Past 9,744' w/o Succes. POH, Recovered 1 Gal Sand / Pararffin. Rerun and Tagged Up at 9,742'. Unable to Work Past 9,744'. POH, Recovered 1 Gal. Sand /Paraffin B/O and UD 2.75" Drift /Bailer. M/U Memory GR-CCL Logging Tool. RIH U 9,744', Logged Up U 9,500'. POH, B/O and UD Looging Tool. Download Log Data. Conferred with Anchorage Team on Plan Forward. Decision was Made To POH w! Tubing and Make Clean Out Run. R/D Schlumberger Slickline Sheaves, Spool Slickline Wire Up, Remove Excess Equipment from Rig Floor, Remove Lubricator and UD Same Printed: 9/26/2005 9:40:20 AM BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ' Name: ell Name: e: Name: From - To S-14 S-14 WORKO NORDIC NORDIC Hours VER CALIS 1 Task A .Code !' PT Start Rig Rig Phase Spud Date: 8/22/1982 : 9/2/2005 End: Release: 9/21/2005 Number: N1 Description of Operations 9/15/2005 17:00 - 18:00 1.00 PULL N DECOMP Held PJSM-R/U Single Joint Compensator and Power Tongs. 18:00 - 00:00 6.00 PULL N DECOMP POH w/ 4-1/2" 12.6# L-80 TCII Tubing. 9/16/2005 00:00 - 06:00 6.00 PULL N DECOMP POOH, B / O and L / D 231 Joints 4-1/2" 12.6# L-80 TCII Tubing, X Nipple Assy's, 3 GLM Assy's, Packer Assy, and 3 Pup Jts. 06:00 - 07:00 1.00 PULL N DECOMP R / U Wachs Cutter and Cut Tubing Above 8akerlocked Connections Between Packer Assy - Lower X Nipple Assy and Lower X Nipple Assy -Mule Shoe Joint. 07:00 - 09:00 2.00 PULL N DECOMP R / D 4-1/2" Tubing Handling Equipment, R / U to Run 4" DP. C / O Bails, R / U 2-7/8" DP Handling Equipment. Cleared and Cleaned Rig Floor. 09:00 - 09:30 0.50 CLEAN N DECOMP Held PJSM. M / U Clean Out BHA: 3.7" Convex Junk Mill, 3-3/8" Xtreme Mud Motor, Float Sub, XO, 2 -Joints 2-7/8" PAC DP, XO, Circulation Sub, XO. BHA Total Length 82.94'. 09:30 - 21:00 11.50 CLEAN N DECOMP RIH w/ BHA on 4" DP. P / U DP from Pipe Shed 1x1 U 9,500'. 21:00 - 22:00 1.00 CLEAN N DECOMP Held PJSM-Slip and Cut Drilling Line 22:00 - 22:30 0.50 CLEAN N DECOMP RIH w/ 4" DP U 9,675', Stand 1 Stand DP Back In Dewrrick To Use for Clean Out 22:30 - 00:00 1.50 CLEAN N DECOMP M / U Top Drive and Established Parameters; String Weight Up 175,000#, String Weight Down 141,000#, Rotary String Weight 160,000#, Pump 2.5 bpm, 680 psi, Rotary 20 rpm, 2,500 fUlbs Torque. Rotated Down f/ 9,675' w/ 20 rpm, 2,500 fUlbs Torque. Tagged Up at 9,715', Observed Pressure Increase U 1,400 psi w/ 4,000 WOM. Allowed Weight Drill Off, Pressure Returned to 680 psi. Continued to Rotate Down, Tagged Again At 9,725'. Milled f/ 9,725' - U 9,755'. WOM 1,000-2,000#, Intermittant Hard Spots. 9/17/2005 00:00 - 02:00 2.00 CLEAN N DECOMP Cleaned Out Wellbore f/ 9,755' - U 9,765'. 1,000-2,000 WOM, Pump 3 bpm, 660 psi, Rotary 20 rpm, 3,000 tt / Ibs Torque. 02:00 - 08:00 6.00 CLEAN N DECOMP Washed and Reamed f/ 9,715' - U 9,765'. Made Multiple Passes Reaming Tight Spots at 9,715', 9,722', 9,725' 9,727', 9,730', 9,733', 9,736', 9,743', 9,746', 9,748', 9,749', 9,752', 9,753-65'. Attempted to Mill at 9,765', WOM 500# - 1,000#, Pump Rate 3 bpm, 700 psi, Motor Continued to Stall Out. 08:00 - 10:00 2.00 CLEAN N DECOMP Dropped Ball to Open Circualating Sub, Pumped and Circulated Around 40 bbl Hi-Vis Detergent Sweep, 10 bpm, 2,450 psi. Shut Down Pump, Monitored Well, Static. Blew Down Top Drive. 10:00 - 13:30 3.50 CLEAN N DECOMP POOH w/ 4" DP. 13:30 - 14:00 0.50 CLEAN N DECOMP R / D 4" DP Handling Equipment, R / U 2-7/8" Handling Equipment. 14:00 - 14:30 0.50 CLEAN N DECOMP POOH, B / O and L / D BHA. 14:30 - 15:00 0.50 CLEAN N DECOMP Cleared and Cleaned Rig Floor. Brought BHA Components to Rig Floor. 15:00 - 15:30 0.50 CLEAN N DECOMP Held PJSM, M / U Reverse Circulating Basket BHA: 3.7" Rev Circ Basket w/ Mill Shoe, Bit Sub, 3 x 3-1/8" DC's, XO, Circulating Sub, XO. BHA Total Length 97.71'. 15:30 - 19:30 4.00 CLEAN N DECOMP RIH w/ Reverse Circulating Basket BHA on 4" DP to 9,690'. 19:30 - 21:00 1.50 CLEAN N DECOMP M/U Top Drive and Established Parameters; String Weight Up 182,000#, String Weight Down 142,000#, Rotary String Weight 162,000#, Pump 5 bpm, 930 psi. Rotary 50 rpm, 3,500 fUlbs Torque. Drop Ball and Pump On Seat. RIH and Tagged at 9,714', Rotated Down U 9,779' w/ 30 rpm, 4,000 fUlbs Torque, Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Wel{ Name: S-14 Common Well Name: S-14 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ' Hours i Task Code 9/17/2005 19:30 - 21:00 21:00 - 21:30 21:30 - 00:00 9/18/2005 00:00 - 01:00 01:00 - 01:30 01:30 - 02:00 02:00 - 04:00 04:00 - 05:30 05:30 - 07:30 07:30 - 11:30 1.50 CLEAN N 0.50 CLEAN N 2.50 CLEAN N 1.00 CLEAN N 0.50 CLEAN N 0.50 CLEAN N 2.00 CLEAN N 1.50 CLEAN N 2.00 CLEAN N 4.00 CLEAN N 11:30 - 15:00 3.50 CLEAN N 15:00 - 15:30 0.50 CLEAN N 15:30 - 16:00 0.50 CLEAN N 16:00 - 19:00 3.00 CLEAN N 19:00 - 00:00 5.00 CLEAN N 912005 00:00 - 01:30 I 1.501 CLEAN N Spud Date: 8/22/1982 Start: 9/2/2005 End: Rig Release: 9/21/2005 Rig Number: N1 NPT Phase ~, Description of Operations DECOMP Pump 4 bpm, 1,000 psi. Unable to Drill Off w/ 2,000#-3,000# WOM at 9,779'. DECOMP B/O Top Drive, Dropped Ball to Open Circulating Sub, M/U Top Drive and Pump Ball on Seat, Open Pump Out Sub, Blew Down Top Drive, Monitor Well-Static DECOMP POH w/ Reverse Circulating Basket on 4" DP DECOMP POOH w/ 4" DP. DECOMP POOH w/ BHA; B / O Pump Out Sub, Retrieve Rod and Ball. POOH w/ DC's, B / O Reverse Circulating Basket and Mill. Recovered 12 Pieces Tubing and 1 Small Piece of Cutter Knife. DECOMP Held PJSM, M / U Reverse Circulating Basket BHA; 3.687" Reverse Circulating Basket w/Mill Shoe, XO, 3 x 3-3/8" DC's, XO, Pump Out Sub, XO. Total BHA Length 100.27'. DECOMP RIH w/ BHA on 4" DP U 4895'., Broke Circulation Every 25 Stands. DECOMP C / O Top Drive Saver Sub. DECOMP RIH w/ BHA on 4" DP to 9,690'. DECOMP M / U Top Drive, Established Parameters, String Weight Up 175,000#, String Weight Down 150,000#, String Weight Rotating 160,000#, RPM 40, Torque 3,500 ft /Ibs, Pump Rate 3 bpm, 470 psi. Shut Down Pump, B / O Connection, Dropped Reverse Circulating Basket By-Pass Ball, M / U Connection, Pumped Ball on Seat, 4 bpm, 470 psi. Washed and Reamed Down to 9,779', Tagged Up at 9,779'. Milled and Worked Down to 9,780', WOM 2,000# - 3,000#, RPM 50, Torque 5,500 ft / Ibs, 6 bpm, 1,270 psi. Unable to Work Mill Shoe and Reverse Circulating Basket Below 9,780'. Shut Down Pump, B / O Connection, Dropped Circulating Sub Opening Ball, M / U Connection, Pumped Ball on Seat, 6 bpm, 1,250 psi, Opened Circulating Sub. Shut Down Pump, Monitored Well, Static, Blew Down Top Drive. DECOMP POOH w/ 4" DP. DECOMP POOH w/ BHA, B / O Reverse Circulating Basket, No Recovery. DECOMP M / U Milling BHA: 3.70" Junk Mill, Bit Sub, 3 x 3-3/8" DC's, XO, Circ Sub, XO. BHA Total Length 95.89'. DECOMP RIH w/ Milling BHA on 4" DP. DECOMP MiU Top Drive, Established Parameters, String Weight Up 172,000#, String Weight Down 150,000#, Rotary String Weight 161,000#, Pump 4 bpm, 440 psi, Rotary20 rpm, 2,500 ft/Ibs Torque, Wash Down f/ 9,688' - t/ 9,712', Tagged Packer Top at 9,712', P/U U 9,700', Rotate Down w/ 20 rpm, 3,000 fUlbs Torque t/ 9,780'. Milled f19,780' - U 9,784' w/ 60-70 rpm, 6,000-7,000 fUlbs Torque, 5 bpm, 820 psi. 3,000#-6,000# WOM. DECOMP Mill f/ 9,784' - U 9,788', 5,000# -6,000# WOM, Rotary 70 rpm, 6,000 - 7,000 fUlbs Torque, Pump 5 bpm, 820 psi. Unable to Mill Past 9,788'. Observe Pump Pressure Increase 100 - 150 psi When Mill on Bottom. While Picking Up Off Bottom Unable to Pull Mill Past 9,766'. Full Circulation and Rotation Below 9,766'. "X" Nipple w/ 3.813" ID at 9,766'. Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 9/2/2005 Rig Release: 9/21/2005 Rig Number: N1 Spud Date: 8/22!1982 End: Date From - To ~, Hours .Task Code ___-- I __ 9/19/2005 01:30 - 08:30 ~ 7.00 ~ CLEAN N NPT Phase ! Description of Operations DECOMP Attempt to Pull Mill Through "X" Nipple at 9,766'. Work Mill and Backream at 9,766', Rotary 60-80, Torque Steady at 7,500 fUlbs. Utilizing Overpulls in 10,000# Increments Up to 225,000# Up Weight with Straight Pulls to 235,000#. Pipe Rotation Stalling When Exceeded Up Weight of 190,000#. Observe Pressure Increase When Over 175,000# Up Weight. Pulled Free w/ 150,000# Overpull. 08:30 - 12:30 4.00 CLEAN N DECOMP POH w/ 4" DP 12:30 - 13:00 0.50 CLEAN N DECOMP POH w/ Milling BHA; Left 2 x 3-3/8" DC's, Bit Sub and Mill in Hole. Total Length 62.4' 13:00 - 14:00 1.00 CLEAN N DECOMP Slip and Cut Drilling Line 14:00 - 15:00 1.00 CLEAN N DECOMP Service and Inspect Top Drive and Derrick 15:00 - 16:00 1.00 CLEAN N SURE RIH w/ Mule Shoe on 4" DP U 960' 16:00 - 17:00 1.00 CLEAN N SURE POH w/ Mule Shoe and 4" DP 17:00 - 18:00 1.00 TA C SURE Wait On Halliburton Fasdril 18:00 - 19:00 1.00 DHB C SURE M/U 9-5/8" Halliburton Fasdril Plug; Fasdril Plug, Running Tool, Ported Sub, XO. Total Length 11.72'. 19:00 - 23:00 4.00 TA C SURE RIH w/ Fasdril on 4" DP t/ 8,990' 23:00 - 23:30 0.50 TA C SURE M/U Top Drive, Established Parameters; String Weight Up 162,000#, String Weight Down 142,000#, Pump 4 bpm, 450 psi. S/O t/ 8,995, P/U t/ 8,992', Rotate Pipe 37 Turns to Right to Set Fasdril. P/U U 215,000# and Shear Out Running Tool Pins. P/U 10' and S/O to Verify Fasdril Set at 8,992'. 23:30 - 00:00 0.50 TA C SURE B/O Top Drive, M/U Circulating Head, Safety Valve and Cement Hose. 9/20/2005 00:00 - 00:30 0.50 TA C SURE Held PJSM w/ Rig Crew, Schlumberger Cementing Crew, Vac Truck Drivers, Doyon Tool Pusher, BP Drilling Supervisor. Break Circulation at 5 bpm, 1000 psi. 00:30 - 01:30 1.00 TA C SURE Shut Down Rig Pump, Line Up to Pump Cement, Pump 5 bbls Water, Close Floor Valve, Test Lines U 3,000 psi, Bled Down Pressure, Open Floor Valve, Pump 5 bbls 15.8 ppg Class "G" Cement, Pump 1 bbl Water, Switch to Rig Pump and Displace Cement w/ 8.5 ppg Seawater at 8 bpm; Volume Pressure 5 bbls Water 775 psi 5 bbls Cmt 575 psi 1 bbl Water 350 psi 10 bbls SW 1,000 psi 20 bbls SW 1,000 psi 30 bbls SW 1,010 spi 40 bbls SW 1,030 psi 50 bbls SW 1,030 psi 60 bbls Sw 1,030 psi 70 bbls SW 1,030 psi 80 bbls SW 1,040 psi 90 bbls SW 1,100 psi 91 bbls SW 1,150 psi 92 bbls SW 1,225 psi 93 bbls SW 1,300 psi 94 bbls SW 1,410 psi -Shut Down Pump Printed: 9/26/2005 9:40:20 AM • BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: S-14 Common Well Name: S-14 Spud Date: 8/22/1982 Event Name: WORKOVER Start : 9/2/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/21/2005 Rig Name: NORDIC 1 Rig Number: N1 ~' Date ', From - To Hours ~ Task Code NPT Phase Description of Operations 9/20/2005 00:30 - 01:30 1.00 TA C SURE CIP At 0100 hrs. B/O Circulating Head and UD Same. POH 5 Stands 4" DP U 8,512'. String Weight Up 162,000#. 01:30 - 02:30 1.00 TA C SURE M/U Top Drive, Circulate Bottoms Up at 10 bpm, 1,830 psi. No Cement Contaminated Fluid at,Bottoms Up 02:30 - 04:00 1.50 TA C SURE Held PJSM-Clean Pits 3 & 4. Offload All Seawter from Pits. Take On Clean 8.5 ppg Seawater in Pits 3 & 4. 04:00 - 05:30 1.50 TA C SURE Displaced Wellbore w/ Clean 8.5 ppg Seawater at 9 bpm, 1,500 psi. B/O and Blew Down Top Drive. Monitor Well, Static 05:30 - 13:30 8.00 TA C SURE POH w/ Halliburton Fasdril Running Tool, UD DP 13:30 - 15:00 ~ 1.50 TA C SURE Pull Wear Ring, Clear and Clean Rig Floor. R/U Tubing Handling Eqpt to RIH w/ 4-1/2" Buttress Tubing Kill String. 15:00 - 18:00 3.00 TA C SURE RIH w/ 4-1/2" Buttress Tubing from Surface to 2,064'. 18:00 - 20:00 2.00 WHSUR C SURE M/U Tubing Hanger and Landing Joint. RIH and Land Tubing. RILDS. B/O and UD Landing Joint. Set TWC and Test from Below t/ 1,000 psi. 20:00 - 21:30 1.50 WHSUR C SURE Held PJSM- Remove Drilling Riser, N/D BOPE's, Stand BOPE's on Cellar Pedistal. 21:30 - 00:00 2.50 WHSUR C SURE N/U Adapter Flange and Tgst to 5,000 psi 9/21/2005 00:00 - 02:00 2.00 WHSUR C SURE N/U Production Tree and Test to 5,000 psi. Stem Packing Leaked on Wing Valve and Master Valve, DSM Serviced Valves, Retested to 5,000 psi. OK 02:00 - 02:30 0.50 WHSUR C SURE R/U DSM Luricator and Pull TWC, R/D and UD Lubricator 02:30 - 03:30 1.00 WHSUR C i SURE Held PJSM w/ Rig Crew, Hot Oil Crew, Vac Truck Driver, R/U ` Hot Oil Lines to Tree. Test Lines t! 2,000 psi. Pump 145 bbls Diesel Down Tubing Taking Returns Up IA to Slop Tank. Pump at 5 bpm, 600 psi. 03:30 - 04:00 0.50 WHSUR C SURE Set BPV and Test from Below t/ 1,000 psi. 04:00 - 05:30 1.50 WHSUR C SURE R/D Hot Oil Lines, Fill Tree w/ Diesel, Install Tree Cap, Remove Secondary Annulus Valve, Install Gauge Flange on Primary Annulus Valve, Install Gauges on Tree Cap and IA Annulus Valve, Secure Well 05:30 - 06:00 0.50 TA C SURE Cleaned and Cleared Cellar, Released Rig at 0600 hrs. 9/21 /2005. Printed: 9/26/2005 9:40:20 AM Well History Well Date Summary S-14A 9/24/2007 T/I/0= 0/0/0. Temp= SI. Eval for MIT-OA w/N2. Cellar is 8' x 9' and 5' in depth. Strapped conductor for a depth of 16' from top of flutes to bottom with 7' of fluids. Conductor is 2.5' above the ground. S-14A 9/24/2007 T/I/0=0/0/0. Temp=Sl. MIT-OA to 500 psi w/N2 Eval for SC Leak/Secure. OA FL near surface. Pressured up OAP to 10 psi w/N2. OAP decreased to 0 psi in 2 mins, 02 meter read 17% LEL's in conductor flutes. Gas appears to be coming from just under the bottom of flute in the 7 0' clock position inside of conductor. Fluid in conductor is at 7', no movement in fluid. Final WHPs 0/0/0. Note: conductor is 20"with 30" insulator installed, no circulation ports. S-14A 10/6/2007 T/I/O =VAC/0+/0. Temp = SI. Monitor, T, IA, OA FL (for AOGCC). TBG FL near surface ? IA FL near surface. OA FL inconclusive. TREE = 6" Mc EV OY WELLHEAD= 13-3/8"McEVOY ACTUATOR = OTIS KB. ELEV = 67.77' BF. ELEV = 39.07' KOP = 3200' Max Angle = 99 @ 10763' Datum MD = 10365 Datum TV D = 8700' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2676' Minimum ID = 2.37" @ 10541' 2-7/8" LNR FISH DETAILS. 9/19/05: 3.687" OD Mill: L = 1.35`, ID = 1.00" Bit Sub: OD = 3.375", L = 1.87', ID = 1.00" 2 x 3-3/8" Drill Collars: OD = 3.375", L = 59.18`, ID = 1.00" Total length = 62.40` Bottom of fish -9795' Top of fish -9733` Prior to leaving the fish in the hole, junk was milled to -9795`. Unable to pull through the X nipple at 9774'. Able to rotate and move down. The fish probably fell downhole when the DC connection pulled in two. TOP OF4-1/2" TBG 9734' TOP OF7"LNR ~-) 9792' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9856' 3-1(2" LNR, 8.81#, L-80, .0087 bpf, ID=2.990" 9871' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10064 PERFORATION SUMMARY REF LOG: CNL/GR ON 09/18/04 ANGLE AT TOP PERF: 84° @ 12380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 12380 - 12580 O 09/18!04 S -14A SA~NOTES: ''"* TxIA COMM POST CTD Suspended RWO SIDE('RACK**' 2064' -j4-1/2", 12.6# Buttress with WLEG 2591' 9-5(8" DV PKR 8990' I-{ 9-5/8" FasDrill BP w / 5 bbl cmt cap to -8922'. 9719' -j 9-5/8" BAKER PKR, ID = 4.75" 9726' MILL OUT EXTENSION, ID = 6.00" ~~ 9733' S-v2" x a-v2° xo 9774' 4-1/2" OTIS X NIP, ID = 3.813" 9799' 3-1/2" BKR DEPLOY SLV, ID = 3.000" 9815' 4-1/2" OTIS XN NIP, M ILLED ID = 3.80" (BEHIND LNR) 9838' 3-1 /2" HES X NIP, ID = 2.813" 9856' 4-1/2' BAKER TBG TAIL, ID = 3.958" {BEHIND LNR) 9871' 3-1/2" X 3-3/16" XO, ID = 2.786" 10121' HOLE IN 7" LNR (POST CTD 9/19/04) 10296' TOP OF WHIPSTOCK MILLOUT WINDOW 10298' - ????' 10541' 3-3/16" X 2-7/8" XO, ID = 2.440" 17" LNR, 26#, L-80 i~ 11216' I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" 10541' PBTD 12621' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 12658' DATE REV BY COMMENTS DATE REV BY COMMENTS 09116/82 ORIGINAL COMPLETION 09/18/04 JLM/TL CTDSIDETRACK(S-14A) 09/21/05 Bartel Suspended Fishing Operations. PRUDHOE BAY UNIT WELL: S-14A PERMIT No: 2040710 API No: 50-029-20804-01 SEC 35, T12N, T12E BP Exploration (Alaska) . ~1f~1fŒ ffi)~ ~~~~æ . AI.,ASIiA. OIL AlO) GAS CONSERVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Terrie Hubble Drilling Technologist BP Exploration (Alaska), Inc. SCANNED NOV {) 1 2007 PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU S-14A Sundry Number: 307-327 ~Ùq~o11 Dear Ms. Hubble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 1i!day of October, 2007 Enc1. 1...'7 01 /ð /2.¡, / 7 :11lo~~~~t>1 ..¿?ø· RECEIVED ,,(£J .4~!f) Î SìATE OF ALASKA . /ç~~7 /lrlLhlfi ALAS OIL AND GAS CONSERVATION COM ION OCT 232007 ¡Ð APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~Iaska Oil & Gas Cons. Commission 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program 181 Suspend o Repair Well o Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time ExtensionAnchorage o Re-Enter Suspended Well o Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes ~ No 9. Property Designation: 110. KB Elevation (ft): , 11. Field / Pool(s): ADL 385193./ 67.8' Prudhoe Bay Field / Prudhoe Bay Pool 12. i'/;</'<',I,I/<il' ,."!,, ,"..»yy¡; .L ~\.INUI,!I!,;/<,. ",1.,; Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12658 ' 8835 ' 8922 7775 8922 9733 Casino Lenoth Size MD TVD Burst Collacse Structural Conductor Surface Intermediate Production Liner 4. Current Well Class: o Development 0 Exploratory ~ Service 0 Stratigraphic 5. Permit To Drill Number 204-071/ 305-278 6. API Number: 50-029-20804-01-00 - 8. Well Name and Number: PBU S-14A - 110' 2676' 10064' 20" x 30" 13-3/8" 9-5/8" 110' 2676' 10064' 110' 2676' 8562' 5380 6870 2670 4760 Liner 1424' 2859' 7" 3-112" x 3-3/16" x 2-7/8" 9792' - 10293' 9799' - 12658' 8373' - 8723' 8378' - 8835' 7240 5410 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 12380' - 12580' 8785' - 8809' Packers and SSSV Type: 9-5/8" Baker packer 13. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for CommencinQ Ocerations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Terrie Hubble Title Drilling Technologist Signature --r.; lì~ 0 t!, 1 ~ Phone 564-4628 Tubing Grade: Tubing MD (ft): L-80 2064' & 9719' - 9857' I Packers and SSSV MD (ft): 9719' 14. Well Class after proposed work: o Exploratory 0 Development ~ Service Tubing Size: 4-1/2" 12.6# Date: 16. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ ~ Plugged OWINJ o Abandoned o WDSPL Contact Danielle Ohms, 564-5759 Date 10/2210 7 Prepared By Name/Number: Terrie Hubble, 564-4628 Commission Use Only I Sundry Number: 3a7~ 3fl7 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: Subsequent Form Required: ~\) ~ ttJY~\~~~=:!D:loç~a~-~f3~:·D.~ ~~ M/fOMMISSIONER THE COMMISSION Date IV' ~rJ· 1'1 oM; rti4 L ~ Submit In Duplicate Approved By: Form 10-403 Revised 06/2006 RBDMS 8Ft OC1 2 9 2007 . . S-14A Historv (DHO 10/26/07) The original well S-14 was CTD sidetracked in September 2004 to a final TD of 12,658' MD.. A 2-7/8" liner was run and the perfs were shot in a bleach pill and have sat static since September, 2004. During the liner lap test, TxIA communication was noted. While performing a subsequent MIT-IA, the 5-1/2" tbg collapsed. Drifts could not pass 9366' SLM. A RWO was performed in September 2005 to replace the completion. The 5-1/2 tbg above the cut at 9327' MD was pulled. Subsequent trip pulled only a portion of the remaining tbg fish. Milled to ..JJ795' MD and unable to pull junk through X nipple at 9774' MD. Able to rotate and move down though. The fish probably fell downhole when the DC connection pulled in two. Left 2 drill collars and mill on top of tbg fish. A RTTS packer was set at 9705' MD and the 9-5/8" casing was pressure tested to 4000 psi and held. The RTTS packer was then released and a USIT log run to confirm good cement behind pipe. A Fasdrill bridge plug was set at 8990' MD and 5 bbls of cement (68' in 9-5/8" csg) was set on top of the plug. The well was then displaced with 8.5 ppg seawater, a kill string run and fteeze protected 12/24/03: 02/07/04: 09/06/04: 09/16/04 09/18/04: 09/19/04: 10/01/04: 10/23/04: 08/28/05: 08/31/05: 09/02/05: MIT -IA to 2500 psi passed. MIT -IA to 2000 psi passed. RU Nordic 1 for cm ST. drilled to 12,658' MD using 8.6 ppg drilling fluid. Pressure test liner lap w/ Nordicl. Failed lost 2300 psi in 5 min. lAP increased from 80 psi to 220 psi. Fluid leaking from tbg to IA. Pressure up IA to 2500 psi and tbg to 2200 psi. Hold for 30 minutes - good test. Circ well to 2% KCI. Lay in 22 bbls bleach across perf section. Perf 12380 - 12580' MD. Freeze protect tbg and RD CTD. MIT -IA failed. Comunication between IA and tubing at a LLR of 0.3 BPM. OA pressure held at 0 psi thoughout. Drift to 9381' SLM w/l.75" and sat down at 9366' MD (Sta #2). LIB indicated RA latch. Chem cut tbg.at 9327' MD. MIT OA to 2000 psi failed. PPPOT - T passed. IC failed. 8 stuck LDS on tbg spool. Pump 997 bbls 1 % KCL and 175 bbls diesel down tbg and up IA. RU Doyon 16 for RWO. .. 09/13/05 : 09/15/05: 09/19/05: 09/20/05: 09/21/05 : 08/25/07: 09/24/07 : 10/06/07: . . Set 9-5/8" RTIS at 9705' MD. Tested 9-5/8" csg to 4000 psi for 30 min. OK. Released RTTS packer. USIT Log of 9-5/8" casing obtained. Indicated good cement behind pipe from 9700' to 8640' MD. And fair cement to 2670' MD. The 7" casing appears to be in good condition and no sign of collapse nor burst based on logs of internal and external radius. Pulled RHC plug from XN @ 9685' SLM. Set Fasdril bridge plug at 8990' MD. Pump 5 bbls 15.8 ppg Class "G" cement. Displace wellbore with 8.5 ppg seawater. Run 4-1/2" buttress tbg kill string to 2064' MD. Pump 145 bbls diesel down tbg taking returns up IA. Set BPV. RD Doyon 16. Pull BPV after wellhead repair. MIT -OA to 500 psi w/ N2 failed. OA FL near surface. V AC/O+/O. TBG FL near surface. IA FL near surface. Future Plans: Work is underway to plan another ST from S-14 to the same general location as the 2004 CTST as the logs indicated good reservoir and oil. It is expected to be re-sidetracked in 2008. The surface casing would be repaired as part of the future rig operations. The following are the last reservoir pressures for S-14 and surrounding wells: S-14 S-05A M-14 M-19 5/28/03 FL (3 Day SI) 3/21106 SBHP (19 day SI) 9/10/05 FL (6 day SI) 10/25/05 S8HP (42 day SI) 3548 psi @8800' TVDss datum 3149 psi@8800' TVDss datum 3103 psi @88oo' TVDss datum 3335 psi @8800' TVDss datum With the 8.5 ppg brine and diesel freeze protect above the plug and 2% KCL below the plug, the hydrostatic pressure to 8800' TVD is ~3700 psi. This alone offsets the highest of reservoir pressure in the area. With the Fasdrill bridge plug at 8990' MD and 68' of cement on top holding as indicated by the surface tbg and IA pressures, FL's, and competent 9-5/8" casing based on the 9/13/05 pressure test to 4000 psi this well is secured. Request Suspended status until able to RWO/ST. TREE = 6" McEVOY WEL,",HEAD"= 13-3/8" McEVOY ACTUA TOR = OTIS KB. ELEV = 67.71' BF. ELEV = 39.01' KOP - 3200' Max Angle = 99 @ 10763' Datum MD = 10365 Datum TVD = 8700' SS s S-14A nded NOTES: *** TxlA COMM POST CTD 2064' -14-1/2",12.6# Buttress with WLEG 113-3/8" CSG, 72#, L-SO, ID = 12.341" I Minimum ID = 2.37" @ 10541' 2-7/8" LNR FISH DETAILS 9/19/05' 3.687" OD Mill: L = 1.35', ID = 1.00" Bit Sub: OD = 3.375", L = 1.87', ID = 1.00" 2 x 3-3/8" Drill Collars: OD = 3.375", L = 59.18', ID = 1.00" Total length = 62.40' Bottom of fish -9795' Top of fish -9733' Prior to leaving the fish in the hole, junk was milled to -9795'. Unable to pull through the X nipple at 9774'. Able to rotate and move down. The fish probably fell downhole when the DC connection pulled in two. -19-5/8" FasDrill BP w / 5 bbl cmt cap to -8922'. I 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.S00" H 10541' I 9792' -19-5/8" BAKERPKR, ID-4.75" I H MILL OUT EXTENSION, ID - 6.00" -15-1/2" x 4-1/2" XO I -14-1/2" OTIS X NIP. ID = 3.813" I -13-1/2" BKR DEPLOY SL V, ID - 3000" I 4-1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND LNR) 9838' -131/2" HES X NIP, ID 2.S13" I -14-1/2' BAKER TBG TAIL, ID = 3.958" (BEHIND LNR) -13-1/2" X 3-3/16" XO, ID = 2.786" I -1 HOLE IN 7" LNR (POST CTD 9/19/04) 10296' H TOP OF WHIPSTOCK I MILLOUTWINOOW 10298' - ????' I TOP OF 4-1/2" TBG I TOPOF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 13-1/2" LNR, 8.81#, L-80, .0087 bpf.ID = 2.990" 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9856' 9871' ÆRFORA TION SUMrv1ARY REF LOG: CNLlGR ON 09/18/04 ANGLEATTOPÆRF: 84° @ 123S0' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 6 12380 - 12580 0 09/18/04 -13-3/16" X 2-7/8" XO, ID = 2.440" I IPBTD I 12-7/S" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I DA TE REV BY 09/16/82 09/18/04 JLMITL 09/21/05 Bartel COMMENTS ORIGINAL COM PLETION CTD SIDETRACK (S-14A) Suspended Fishing Operations. DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: S-14A ÆRMIT No: '2040710 API No: 50-029-20804-01 SEC 35, T12N, T12E BP Exploration (Alaska) API No. ~2~804~~.!I ~ ~ ~ v( -~-~ (<{ ~ J\)d~ \\ " DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2040710 Well Name/No. PRUDHOE BAY UNIT S-14A Operator BP EXPLORATION (ALASKA) INC ../ MD 12658 TVD 8835./ Completion Date 9/19/2004 / Completion Status WAGIN Current Status WAGIN ._~--~-,-~_. ---- REQUIRED INFORMATION Directional Survey 0 Mud Log No Samples No --~,- -~~-~ DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR / CCL / CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ f- "'dlFnnt Number Name Scale Media No Start Stop CH Received Comments Log Gamma Ray 5 Col 1 2600 9700 Case 11/29/2005 Ultrasonic Imaging TO~ Gamma Ray/CCL 13-Sep- k6 D Asc Directional Survey 10200 12658 Open 1 0/7/2004 2005 I IIFR ! I Rpt Directional Survey 10200 12658 Open 10/7/2004 IIFR I i r C Lis 12868 Neutron 9528 12542 Case 11/29/2004 COMPENSATED ! NEUTRON LOG/MEMORY I ~ GRlCCLlCNL I 12868 Neutron 2 Blu 9528 12542 Case 11/29/2004 COMPENSATED I NEUTRON LOG/MEMORY I GRlCCLlCNL , ~D Lis 12943 Gamma Ray 10145 12607 Open 1/27/2005 GRlEWR4/ABI/ROP/MWD i 12943 LIS Verification 10145 12607 Open 1/27/2005 GRlEWR4IABIIROPIMWD I Leak Blu 0 9800 Case 8/30/2005 Leak Detection Log PRESSITEMP/GRAD/SPIN i I NERS I ~ C Lis 13663 Induction/Resistivity 10317 12658 Open 2/22/2006 ROP NGP EWR plus I Graphics --~ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . . DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2040710 Well NamelNo. PRUDHOE BAY UNIT S-14A Operator BP EXPLORATION (ALASKA) INC MD 12658 TVD 8835 ADDITIONAL INFORMATION Well Cored? Y 0 Chips Received? -y II~ Completion Date 9/19/2004 Completion Status WAGIN Current Status WAGIN Daily History Received? WN 0/N Formation Tops Analysis Received? ~ Comments: ~ompJian'. Rev'....:.~; . ~.~.~~ Date: {[ API No. 50-029-20804-01-00 UIC Y aF~ç- . . . . WELL LOG TRANSMITTAL OIC a04-D11 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 {% lf3 RE: MWD Formation Evaluation Logs S-14A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 S-14A: LAS Data & Digital Log Images: 50-029-20804-01 1 CD Rom ~~ 11/28/05 Schlumberger r t: \\'¥~:.;r~~ t::~ ,~~ J ia~ ~~ ~ NO. 3613 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ,. ...' ~:; n 2005 I~~ ;3.;).;, (QHS.. CQ;tnffU~n ÙS¡d'¡iJfage Field: Prudhoe Bay, Milne pt. Well Job # Loa Descriotion Date BL Color CD PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT 10/06/05 1 S-14A 10987547 USIT ';;;>04, - O~l I 09/13/05 1 Y-10A 10889216 SCMT 02/21/05 1 D.S. 03-33A 10893093 SCMT 03/05/05 1 C-19B 10928633 SCMT 05/15/05 1 09-20 10889215 SCMT 02/18/05 1 D.S.09-31C N/A SCMT 11/05/05 1 P-06A 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT 07/04/05 1 D.S.06-20 11062630 USIT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth R~';"d b,/J ~)Q C ~ Date Delivered: \\I4)C~\o5 . . . . r? a;, ,::;:¡ ¡ î ì ¡ ..., r{ù nVlJ \ \ ."" j < \".' U" , ' ,"",\, ij\\ f ~.3.:V . ! \}. í FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Bartel Production Engineer BP Exploration (Alaska) Inc. Anchorage, AK 99519-6612 Re: PBU S-14A Sundry Number: 305-278 Dear Mr. Bartel: .~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. o orman . /. Chairman DATED this'ÿ day of September, 2005 Encl. C(l} qi" ¿; "0 t{ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM SSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 WGA- q IZ I I ~ooS 1. Type of Request: o Abandon o Alter Casing o Change Approved Program o Suspend o Repair Well o Pull Tubing III Operation Shutdown 0 Perforate 0 Other o Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: D Development D Exploratory D Stratigraphic 1m Service / 5. Permit To Drill Number 204-07{1 305-250 " 6. API Number: 50-029-20804-01-00./' 99519-6612 67.8' 9. Well Name and Number: PBU S-14A 8. Property Designation: 10. Field I Pool(s): ADL 385193 Prudhoe Bay Field / Prudhoe Bay Pool PRESE:tÎlrWELL CONDITIONSI..J.MMARY Total Depth rvD (ft): Effective Depth MD (ft): Effective Depth rvD (ft): 8835 8920 7774 110' 20' x 30" 110' 110' 2676' 13-3/8" 2676' 2676' 5380 2670 10064' 9-5/8" 10064 ' 8562' 6870 4760 1424' 7" 9792' - 10293' 8373' - 8723' 7240 5410 2859' 3-1/2" x 3-3/16" x2-7/B" 9799' - 12658' 8378' - 8835' Perforation Depth MD (ft): Perforation Depth rvD (ft): 12380' - 12580' 8785' - 8809' Packers and SSSV Type: 9-5/8" Baker packer Tubing Size: 4-112" 12.6# Tubing Grade: Tubing MD (ft): L-80 -2000' & 9719' - 9857' Packers and SSSV MD (ft): 9719' 12. Attachments: 1m Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: ..... D Exploratory D Development 1m Service 16. Verbal Approval: Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Paul Bartel Title Production Engineer 15. Well Status after proposed work: DOil DGas 1m WAG D GINJ D Plugged DWINJ D Abandoned D WDSPL Phone 564-5402 Contact Paul Bartel, 564-5402 Paul Chan, 564-5254 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: RBDMS 8Ft SEP 2 6 200J V~ J FOY Ì'V'- '0 - 4 0 ~ yejl we: N'd Þ; ~ Ç. /-tv f "yl)'lV"r.A- Þ ~rl s.. . " APPROVED BY THE COMMISSION Date L .. . . S-14A RWO Summary of Operations: 9/3/05 9/4/05 - 9/5/05 9/6/05 - 9/8/05 9/9/05 - 9/11/05 9/12/05 9/13/05 9/14/05 - 9/15/05 9/16/05 9/17/05 9/18/05 9/19/05 9/20/05 Plan Forward: MIRU POOH w/ 5~ 1/2" tubing. Engaged fish and jar. Recovered collapsed pup jt, GLM #2 and a portion of the collapsed pup jt below the GLM. - Washed over collapsed pup and perfonn outside cut (multiple attempts). Recovered collapsed pup and tubing to 9506' . Made multiple, unsuccessful, attempts to cut the tubing at -9668'. -- Rotated the K-anchor out of the 9-5/8" packer and recovered the remaining 5-112" tubing and SBR. Cleaned out to the packer at 9719' with mill and scraper. Slickline successfully drifted the 4-1/2" tubing tail to the 3-1/2" liner top at 9799' with a 3.68" drift. Set RTTS at 9705' and pressure test 9-5/8" casing to 4000 psi for 30 minutes, good test. Ran USIT log. /' Attempt to run 4-112" completion. Tagged high. Unable to sting into the packer at 9719'. Pulled the 4-112" completion. Milled junk in the 4-1/2" tubing tail to -9765'. Made multiple runs with reverse circulating junk basket and cleaned out junk to -9780'. Milled junk to -9788' (-9795' corrected depth). Mill hung up at the X nipple at 9774' when POOH. Able to move down and able to rotate. Worked fish. Pulled free. The connection on a 3-3/8" drill collar parted, leaving the junk mill, bit sub and two 3-3/8" drill collars in the hole. Suspend operations. Set 9-5/8" FasDrill bridge plug at 8990' and cap with 5 bbls of cement to -8920'. Run 4-112" kill string to 2000'. Freeze .- protect. RDMO. The top of the fish is at the bottom of the 9-5/8" packer mill out extenstion. We may be able to latch it, but we have no way to release from it because the fish is free to rotate. We must now evaluate additional fishing operations to include milling the 9-5/8" packer, and recovering the 4- 112" tubing tail (and the fish inside of it) down to the 3-112" liner top. /' Prepared by: Paul Bartel, 9/20/05 1'REE =~ 6" McEVOY WB.LHEAO = 13-3/8" McEVOY ACTUATOR = OTIS KB. B.EV = 67.77' BF. B.EV = 39.07' KOP = 3200' Max Angle = 99 @ 10763' Datum MD = 10365 Datum TVD = 8700' SS sus'nded S-14A RWO NOTES: *** TxlA COMM POST CTD RACK *** 113-3/8" CSG, 72#, L-80, ID = 12.347" I "'4-1/2", 12.6# Buttress with WLEG Minimum ID = 2.37" @ 10541' 2-7/8" LNR FISH DETAILS, 9/19/05: 3.7" OD Mill Bit Sub 3-3/8" Drill Collar 3-3/8" Drill Collar Total length = 62.4' Bottom of fish -9795' Top of fish -9733' Prior to leaving the fish in the hole, junk was milled to -9795'. Unable to pull through the X nipple at 9774'. Able to rotate and move down. 1 TOP OF 4-1/2" TBG I -i 9-5/8" FasDrill BP w /5 bbl cmt cap to -8922'. , r 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" H 10541' I -i9-5/8" BAKERA<R, 10- 4.75" I / H MILL OUT EXT8\JSION, ID - 6.00" I -i5-1/2" x 4-1/2" XO I -i4-1/2" OTIS X NIP, ID = 3.813" I ,/ 3-1/2" BKR DEA..OY SLV, 10 = 3.000" 4-1/2" OTIS XN NIP, MILLED ID = 3,80" (B8-iIND LNR 9838' -i3-1/2" HES X NIP, 10 2.813" I -i4-1/2' BAKER TBG TAIL, 10 = 3.958" (B8-iINO LNR) -i3-1/2" X 3-3/16" XO, ID = 2.786" I .., HOLE IN 7" LNR (POST CTD 9/19/04) 10296' H TOP OF WHIPSTOCK I MILLOUT WINDOW 10298' - ??17' I 1 TOP OF 7" LNR I 9792' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9856' 13-1/2" LNR, 8.81#, L-80, .0087 bpf, 10 = 2.990" I 9871' 19-5/8" CSG, 47#, L-80, 10 = 8.681" I ÆRFORA TION SUMMARY REF LOG: CNUGR ON 09/18/04 ANGLEATTOPÆRF: 84° @ 12380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12380 - 12580 0 09/18/04 o 10541' H3-3/16"X2-7/8"XO,ID=2.440 PBTD I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, 10 = 2.441" I DA TE REV BY COMM8'ITS 09/16/82 ORIGINAL COMPLETION 09/18/04 JLMITL CTD SIDETRACK (S-14A) OA TE REV BY COMMENTS PRUDHOE BA Y UNIT WB.L: S-14A ÆRMIT No: 2040710 API No: 50-029-20804-01 SEC 35, T12N, T12E BP Exploration (Alaska) Re: BOPE Test Interval Extension . . Galloway, Casey F (Fair) wrote: Jeff, As per our phone conversation I am requesting a bop test interval extension on the 7 days for RWO on S-14A. The bop test is due today 18 Sept, we will be running tubing tomorrow and have the well secured by early Tuesday. Thanks, Casey */Casey Galloway/* */Drilling Supervisor/* */Doyon Rig 16/* */907-659-4168/* */907-659-4236 pgr 252/* Casey, your request for a 48 hr BOPE test extension to complete the well is acceptable based on our telephone conversation and the information you have provided. Please keep the on-duty AOGCC Inspector informed of any changes to your plans related to this test extension. Jeff Jones AOGCC JDvt-67t 1 of I 9/19/2005 8:26 AM 08/30/05 Scblumbepger NO. 3460 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD l-15 1'S'j·- U¿( 11084273 PPROF W/DEFT/GHOST/CALlPER 07/08/05 1 L5-17A 1 r, ',í~ ~U. 3 11075898 MEM PPROF W/DEFT/GHOST 07/03/05 1 DS 04-26 I.~ ~"'-JN 11072873 PRODUCTION PROFILE 07/30/05 1 S-14A 'À.ÓI.f - 0·71 10893047 LEAK DETECTION LOG 10/17/04 1 G-27 I .'f""- I r (¿, 10942221 MEM PPROF & IPROF 06/29/05 1 DS 05-20B ~ t'-j .- J..) I.j 10942220 MEM INJECTION LOG 06/26/05 1 E-37A :.tCç- \:¡t ~ 10928640 MEM PPROF, IPROF & WARMBACK 06/14/05 1 D-29 I-\,Ç- )..,S-1 11084274 RST 07109/05 1 1 i~;) À 3 L2-28 /,1' r - û 3 ç 11076453 RST 07/27/05 1 1 /3:0.'1 C-13A (f.(7-Jl.í ~ 11075900 MCNL 07/05/05 1 1 i J).J r OWDW-SW/Ij iì .- ,¡ 3 ::t 10893096 RST-BORAX CHANNEL DETECTION LOG 03/24/05 1 1 /J).). &. 06-08A lq)--I q r 11062628 RST 05/17/05 1 1 n ).:;" 7 12-29 J S if- t,,3 '2- 11072867 RST 07/07/05 1 1 ¡U.J.8 C.19BÂ(¡ .~- O~)- 10928632 MCNL 05/12/05 1 1 j~).2r:1 G-27 HI\¡- 11 (,,¡ 10942221 MCNL 06/29/05 1 1 J ~ 13t F·02A ').. Ò~- ~ C '" 'i 10928630 MCNL 05/08/05 1 1 13:0; 03-33B ).0>- - Ol~ 10913011 US IT PDC-GR 03/19/05 1 1 1 "'.1 ~ )... MPK-22 ~ÀÓ')-:" Ü~2.. 10893106 USIT 04/20/05 1 . . BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: )1 ~ :Zi~ \-- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995.~3-2¡¡'36 .. '.t1¡ . . ATTN: Beth ,..; '1¡~1 l Ú1 ! I); I Received by: ì!4 ' "" . . / e ¡If) rb LWU e FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Bartel Production Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe S-14A Sundry Number: 305-250 Dear Mr. Bartel: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a liday or weekend. A person may not appeal a Commission decisio 0 S perior Court unless rehearing has been requested. DATED thisJOday of August, 2005 Encl. Cff ~;'¡OJ' STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL,. t·( 20 AAC 25.280 e IN () 1\-. !DIS ~ Ii 7/ t "vs ct I c.'t 1S 1. Type of Request: o Abandon 0 Suspend o Alter Casing Cft.,s."9.Repair Well o Change Approved proffam III Pull Tubing / o Operation Shutdown 0 Perforate 0 Other o Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: D Development D Exploratory D Stratigraphic 181 Service / 5. Permit To Drill Number 204-071 / 6. API Number: 50-029-20804-01-00 ../ 67.8' 9. Well Name and Number: PBU S-14A / 8. Property Designation: ADL 385193 10. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 11. Total Depth MD (ft): 12658 110' 20" x 30" 110' 110' 2676' 13-3/8" 2676' 2676' 5380 2670 10064' 9-5/8" 10064' ".- 8562' 6870 4760 1424' 7" 9792' - 1 0293' ./ 8373' - 8723' 7240 5410 Liner 2859' 3-1/2' x 3-3/16" x 2-7/8" 9799' - 12658' 8378' - 8835' Peñoration Depth MD (ft): 12380' - 12580' / Packers and SSSV Type: Peñoration Depth TVD (ft): 8785' - 8809' 9-5/8" Baker packer 5-1/2" DBE SSSV Landing Nipple Tubing Size: 5-1/2" 17# x 4-112" 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 9719' 2093' Tubing MD (ft): 9857' ./ 12. Attachments: a Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: ./ D Exploratory D Development a Service 16. Verbal Approval: Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Paul Bartel Title Production Engineer September 5, 2005 Date: 15. Well Status after proposed work: DOil DGas ./ a WAG DGINJ D Plugged DWINJ D Abandoned D WDSPL Contact Paul Bartel, 564-5402 Paul Chan, 564-5254 Phone 564-5402 Sundry Number: ..305.;)50 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: Tes·~ /SC Pi: RBDMS 8Ft Ai ;~ 7005 APPROVED BY THE COMMISSION Date e e G S-14A DroDosed Ria Workover Procedure / 1. MIRU. ND tree. NU and test BOPE to 4000 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-1/2" tubing string to the cut at +/- 9400' MD. 3. PU drillpipe and fishing tools. Attempt to jar the SBR off the production packer at 9687'. If / unsuccessful then: 3a. Wash over the collapsed tubing with a dress-off shoe followed by outside cutter. 3b. Recover the 5-1/2" collapsed tubing stub. / 3c. Cut the remaining 5-1/2" above the SBR at approximately 9667' and recover same. 4. RIH with mill x scraper and dress off tubing stub. 5. RIH with RTTS to the tubing stub and test casing to 4000 psi for 30 minutes. Note: If casing does / not pressure test, a 7" scab/tieback liner may be run. 6. Run USIT log from the tubing stub to approximately 5000' to evaluate the 9-5/8" cement job. (future Orion recompletion evaluation). 7. Run 4-1/2" L-80 TC-II premium connection completion with overshot and stacker packer to -9565'. . 8. Displace the IA to packer fluid and set the packer. / 9. Test tubing to 4000 psi, test annulus to 4000 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. ./ TREE" 6" McEVOY WELLHEAD - 13-3/8" McEVOY ACTUATOR = OTIS KB. ELEV = 67.77' BF. ELEV = 39.07' KOP = 3200' Max Angle = 99 @ 10763' Datum MD = 10365 Datum TVD = 8700' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.37" @ 10541' 2-7/8" LNR 15-1/2" TBG, 17#, L-80 IPC, .0232 bpf, ID = 4.892" I I TOP OF 4-1/2" TBG I ITOPOF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" I e 2676' 9719' 9734' 9792' 9856' 9871' I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 10064' ÆRFORA TION SUMMARY REF LOG: CNUGR ON 09/18/04 ANGLEATTOPÆRF: 84° @ 12380' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12380 - 12580 0 09/18/04 S-14A ~NOTES: *** TxlA COMM POST CTD SIDETRACK *** 2093' 1--5-1/2" OTIS SSSV NIP, ID = 4.562" I ~ -j 2591' I-- 9-5/8" DV PKR I GAS LIFT MANDRELS DEV TYÆ VLV LATCH 9 OTIS LBD DMY RA 38 OTIS LBD DMY RA 37 OTIS LBD DMY RA 37 OTIS LBD DMY RA 37 OTIS LBD DMY RA 42 OTIS LBD DMY RA 44 OTIS LBD DMY RA 44 OTIS LBD DMY RA 43 OTIS LBD DMY RA 45 OTIS LBD DMY RA 45 OTIS LBD DMY RA 48 OTIS LBD DMY RA 48 OTIS LBD DMY RA . = -µ ST MD TVD ~ 13 3100 3031 12 4921 4620 11 6337 5734 10 7081 6338 9 7237 6462 8 7726 6842 7 7871 6948 6 8237 7213 5 8392 4325 4 8754 7587 3 8911 7699 2 9401 8043 1 9557 8148 l PORT DA TE o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 o 09/16/82 I I I 9630' 1--5-1/2" OTIS XA SLIDING SLEEVE, ID = 4.562" I í X" h I I ~ I ~ I 9687' 1--20' BAKER SBR TBG SEAL ASSY I 9719' 9-5/8" BAKER PKR, ID = 4.00" I 9726' I MILLED OUT EXTENSION, ID = ?? I 9733' I-- 5-1/2" x 4-1/2" XO I : 9774' 1--4-1/2"OTISXNIP,ID=3.813" I I 9799' I-- 3-1/2" BKR DEPLOY SL V, ID 3.000" I I 9815' 4-1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND LNR) I 9838' 1--3-1/2" HES X NIP, ID 2.813" I 1 9856' H4-1/2' BAKER TBG TAIL, ID = 3.958" (BEHIND LNR) I I 9871' 1-13-1/2" X 3-3/16" XO, ID = 2.786" I - I ~ . . II I ~ ~ --J 10121' I--HOLE IN 7" LNR(POSTCID9/19/04) I I 10296' H TOP OF WHIPSTOCK I I MILLOUT WINDOW 10298' - ????' I ~ c-i 17" LNR, 26#, L-80 I 11216' 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" H 10541' I DA TE REV BY COMMENTS 09/16/82 ORIGINAL COM PLETION 09/18/04 JLM/TLH CTD SIDETRACK (S-14A) IPBTD I 12-7/8" LNR, 6.16#, L-80. .0058 bpf, ID = 2.441" I DA TE REV BY COMMENTS 10541' H3-3/16" X 2-7/8"XO, ID=2.440" I 12621' }- 12658' f A -V ~ PRUDHOE BAY UNfT WELL: S-14A ÆRMfT No: 2040710 Apt No: 50-029-20804-01 SEC 35, T12N, T12E BP Exploration (Alaska) Pro~sed S-14A RWO TREE It 6" McEVOY WELLHEAD = 13-3/8" McEVOY ACTUA TOR = OTIS KB. ELEV = 67.77' BF. ELEV = 39.07' KOP = 3200' Max Angle = 99 @ 10763' Datum MD = 10365 Datum TV D = 8700' SS = 113-3/8" CSG, 72#, L-80, ID = 12.347" I ~ 2676' Minimum ID = 2.37" @ 10541' 2-7/8" LNR 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID 3.958" I I . ~ NOTES: *** TxlA COMM POST CTD SIDETRACK *** 2100' 1-14-1/2" X Nipple, ID - 3.813" I 2591' H 9-5/8" DV PKR I ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 3 3838 3800 26 2 6582 6000 35 1 8264 7300 43 ~~ l I I I 9535' H4-1/2" X Nipple, ID - 3.813" ~ ¡o:;:::-;: 9565' I-- 9-5/8" x 4-1/2" BA KER S-3 PA CKER .::::..::: . I 9600' 1--14-1/2" X Nipple, ID - 3.813" 1 UNIQUE MA CHINE OVERSHOT 9662' I I 15-1/2" TBG, 17#, L-80 IPC, .0232 bpf, ID = 4.892" I 9719' I ~ TOPOF 4-1/2" TBG I 9734' - r- ITOPOF7" LNR I 9792' I I II II 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" I 9856' 9871' 1 l' ....... . ~r-.....I "1 þ; I H 19-5/8" CSG, 47#, L-80, ID = 8.681" I 10064' ~ ~ ÆRFORA TION SUMMARY REF LOG: CNUGR ON 09/18/04 ANGLEATTOPÆRF: 84° @ 12380' Note: Refer to Production DB for historical perf data . SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12380 - 12580 0 09/18/04 I 7" LNR, 26#, L-80 I 11216' I I I I 9667' 1--15-1/2" CUT TUBING --20' BAKER SBR TBG SEAL ASSY I I 9687' I 9719' 9-5/8" BAKER PKR, ID = 4.00" I 9726' I MILLED OUT EXTENSION, ID = ?? I 9733' -5-1/2" x 4-1/2" XO I 9774' -14-1/2" OTIS X NIP, ID = 3.813" I 9799' -- 3-1/2" BKR DEPLOY SL V, ID 3.000" , 9815' 4-1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND LNR) 9838' -13-1/2" HES X NIP, ID 2.813" I 9856' --4-1/2' BAKER TBG TAIL, ID = 3.958" (BEHIND LNR) I 9871' -- 3-1/2" X 3-3/16" XO, ID = 2.786" I 10121' - HOLE IN 7" LNR (POST CTD 9/19/04) I I 10296' H TOP OF WHIPSTOCK I I MILLOUT WINDOW 10298' - ????' I rl 10541' 1--13-3/16" X 2-7/8" XO, ID = 2.440" 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" H 10541' I IPBTD I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I ~ 12621' ~ 12658' DA TE REV BY COMMENTS 09/16/82 ORIGINAL COMPLETION 09/18/04 JLMITL~ CTD SIDETRACK (S-14A) DA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: S-14A ÆRMIT No: 2040710 API No: 50-029-20804-01 SEe 35, T12N, T12E BP Exploration (Alaska) . . 2.0 '1-0 7/ j-J 1 qui; WELL LOG TRANSMITTAL ;... N\ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 November 17, 2004 RE: MWD Formation Evaluation Logs: S-14A, AK-MW-3268702 I LDWG formatted Disc with verification listing. API#: 50-029-20804-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF TIlE TRANSM1'l~rAL LEITER TO THE AITENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:# Sig 11/23/04 Schlumberger NO. 3277 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . ~ 'DtJ ?1J ?01- 20 l"Ð pt J.d{ ~ ..($0 W-05A Well ob# oa escrlDtion ate ue me rm s 10715426 CH EDIT (PDC-GR) 09/02/04 1 .~ L3-02 10708048 RST-SIGMA 02/05/04 1 1 -cì OWDW-SW 10563038 RST -SIGMA 03/30/03 1 1 .-, OWDW-SW 10672360 RST -BORAX 03/27/04 1 1 t{,()'!J P1-07A 10621778 USIT (PDC) 04/20/04 1 1 rn J-25A 10715419 MCNL 08/13/04 1 1 v.1o't C-25B 10715434 MCNL 10/11/04 1 1 ...07/ S-14A 10884020 MCNL 09/18/04 1 1 ~(}f 0 E-39A 10728394 MCNL 03/28/04 1 1 -rz.õ 07-32B 10861926 MCNL 08/03/04 1 1 if~ elf ( Q-05A 10715356 MCNL 10/26/03 1 1 ~ DS 09-41 10563111 RST -SIGMA 10/12/03 1 1 . J L D D BI r Color p' t CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 /lh9 ~t . , ¡ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950}-Z838 ATTN: Beth I /1 Date Delivered: . STATE OF ALASKA .. ALASKA AND GAS CONSERVATION COMI'vWIION WELL COMPLETION OR RECOMPLETION REPORT AND LOG n. CT ..~ ~~Ji'I4 \J 'C' l.> (..jU 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended !HI WAG 1b. Well Class: þ::·'.·..ir··~;.ß 20AAC 25.105 20AAC 25.110 o Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic !HI Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/19/2004 204-071 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/10/2004 50- 029-20804-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/16/2004 PBU S-14A 1651' SNL, 2185' EWL, SEC. 35, T12N, R12E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1721' SNL, 1278' EWL, SEC. 36, T12N, R12E, UM 67.8' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1503' SNL, 3524' EWL, SEC. 36, T12N, R12E, UM 12623 + 8823 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 620347 y- 5979855 Zone- ASP4 12658 + 8835 Ft ADL 385193 TPI: x- 624721 y- 5979857 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 626962 y- 5980112 Zone- ASP4 (Nipple) 2093' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey !HI Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD GR / EWR, MGR / CCL I CNL 22. CASING, LINER AND CEMENTING RECORD ~ ~~~~G VIIT.PER FT. ..;:S!$rTIN$LleRTH~D SeT11NG JePTH T\ID ·HBtÊ'il G~QE loP I:SOTTOM Top BOTTOM .r ¡i¡·' 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2676' Surface 2676' 17-112" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 10064' Surface 8562' 12-1/4" 1415 cu ft Class 'G', 130 cu ft AS I 7" 26# L-80 9792' 10293' 8373' 8723' 8-1/2" 1438 cu ft Class 'G' 3-1/2" x 3-3/16" x 2·7/8" 8.81# /6.2# /6.16 L-80 9799' 12658' 8378' 8835' 4-1/8" x 3-3/4" 225 CU ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBINGRg~dRD ........ Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 5-112", 17#, L-80 9719' 9719' MD TVD MD TVD 4-112", 12.6#, L-80 9719' - 9857' 12380' - 12580' 8785' - 8809' 25. ìf""~ ....... ~¡.., !.-EMi:N·' ..........;.. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with 60 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oil -BBl GAs-MCF W A TER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None f-cõf'~~'f~~ì štT~'Òirl ,. ., ;-'"'"" r GI[\JAL '~k~ u ~\! í ~ ' J¡.; 't!.~' ¡~J (j) : nlJ1 ~ C9Y .~ . ..........ii ~: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE .. I ~ ~ 2S. GEOLOGIC MARKERS 29. RMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Sadlerochit Top Sadlerochit (Inverted) 10300' 8728' None 11980' 8749' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 10-/6-0 PBU S-14A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Peter Du Cane 204-071 Permit No. I A roval 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/6/2004 20:00 - 21 :00 1.00 MOB P PRE Rig Released from W-05A @ 202:00 9/6/2004. P/U spill dykes. PJSM. Move off well. Conduct post-operations pad inspection. 21 :00 - 21 :30 0.50 MOB P PRE Held pre-move safety meeting with Security, tool service all personnel. 21 :30 - 23:00 1.50 MOB P PRE Move rig from W-05 to side-pad on the access road. 23:00 - 00:00 1.00 MOB N WAIT PRE Stand-by on side-pad on the access road while Tool Services reposition mats around rig. 9/7/2004 00:00 - 14:00 14.00 MOB N WAIT PRE Standby for rig mats. 14:00 - 16:00 2.00 MOB P PRE Move rig to wide spot in road to allow passage of rig mats ahead of rig. 16:00 - 00:00 8.00 MOB N WAIT PRE Standby of rig mats. 9/8/2004 00:00 - 02:00 2.00 MOB N WAIT PRE Continue moving rig mats around rig. 02:00 - 04:30 2.50 MOB P PRE Move rig to S pad 04:30 - 07:30 3.00 MOB N WAIT PRE Wait on Doyon 16. 07:30 - 08:30 1.00 RIGU P PRE PJSM. Verify 0 psi wellhead pressure. Move rig over well S-14Ai. RIG ACCEPT 08:00 hrs 9/8/04 08:30 - 11 :00 2.50 BOPSU P PRE ND tree cap. NU BOPE. 11 :00 - 16:30 5.50 BOPSU P PRE Test BOPE. - John Spalding with AOGCC waived witness. - Fill pits with seawater. 16:30 - 17:30 1.00 ZONISO P WEXIT Load and pump dart. Latch at 58.7 bbls. 17:30 - 18:00 0.50 ZONISO P WEXIT Retrieve dart. Test inner reel valve. 18:00 - 18:15 0.25 ZONISO P WEXIT Open well. Well on vacuum. Fill hole while MU BHA. 18:15 - 20:15 2.00 ZONISO P WEXIT RIH tag at 10,302'. PU 10' and flag. 20:15 - 20:45 0.50 ZONISO P WEXIT Perform injection test. Rate bpm, PP psi, WHP psi 1 770 1.5 1100 612 2 1680 710 3.3 3280 879 20:45 - 21 :30 0.75 ZONISO N WAIT WEXIT Wait on dirty vac. 21 :30 - 22:00 0.50 ZONISO P WEXIT PJSM for cement job. 22:00 - 00:00 2.00 ZONISO P WEXIT Prime up and PT lines to 3945 psi. Mix and pump 2 bbl H20, 5 bbl neat, 20 bbl 15.8 ppg cement with 12 ppb agg, 5 bbl cement and 5 bbl H20 displace with #2 bio 30 bbl and KCL. Out Micro motion quit working. With cement at nozzle Shut in choke. Bullhead at 2.0 bpm 546 psi, Annular pressure initially 600 psi. Continue bull heading allowing annular pressure to clime to 1100 psi. Bleed off. POH 1: 1. Pull to safety @ 9800. Squeeze to 1000 psi. Lost 125 psi in 30 minutes. Estimated 12 bbl cement below WS. 9/9/2004 00:00 - 00:30 0.50 ZONISO P WEXIT Cleanout cement to 10' above WS. Make additional cleanout passes. 00:30 - 02:15 1.75 ZONISO P WEXIT POH. 02:15 - 03:00 0.75 ZONISO P WEXIT LD nozzle. Flush BOP stack. 03:00 - 04:00 1.00 STWHIP P WEXIT MU BHA install baker coil connector 04:00 - 05:50 1.83 STWHIP P WEXIT RIH 05:50 - 13:30 7.67 STWHIP P WEXIT Tag mill cement to Pinch point 10,305. Mill window to 10,312'. - Mill window as per ADW RP. Printed: 9/20/2004 11: 14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/912004 05:50 - 13:30 7.67 STWHIP P WEXIT - 2.57 bpm, 1600 psi - 2-3 k WOB. - PU 40k; SO 18k - PU through window to confirm access. 13:30 - 14:45 1.25 STWHIP P WEXIT Mill 10' of new formation from 10,312' to 10,322' MD. Dress window. RIH dry to ensure access. - Swap well to new Flo Pro mud. 14:45 - 16:30 1.75 STWHIP P WEXIT POOH with window milling BHA. 16:30 - 18:00 1.50 STWHIP P WEXIT LD window milling BHA. - String mill and window mill both gauge 3.8" no go 13.78" go 18:00 - 18:30 0.50 DRILL P PROD1 PU build BHA ~ 18:30 - 20:50 2.33 DRILL P PROD1 RIH to 10215 20:50 - 21 :35 0.75 DRILL P PROD1 Tie in log. Log up 10218 to 10160. Gamma readings above 10175 not corrolating. Hi Gamma. 21 :35 - 23:20 1.75 DRILL P PROD1 RIH tag at 10326. Log up 10290 to 10160. Correct -7'. High Gamma reading above 10175 repeating. (Possible scale) 23:20 - 00:00 0.67 DRILL P PROD1 RIH Orient 9/10/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Orient L HS lots of reactive torque. Numerous attemtps required. 01:00 - 06:15 5.25 DRILL P PROD1 Directionally drill with 2.4 bpm, 2700 psi, 35K up, 20K dn, 1-2 K WOB,TF 58L, ROP 23. 06:15 - 06:45 0.50 DRILL P PROD1 PU to window. Orient TF to 90L. RIH. 06:45 - 07:30 0.75 DRILL P PROD1 Drill ahead with build BHA to 10,482' MD. - 2.5 I 2.6 bpm. - 2900 psi - 2k WOB - 45 ROP 07:30 - 07:45 0.25 DRILL P PROD1 PU to window. Orient TF to 90L. RIH. 07:45 - 09:00 1.25 DRILL P PROD1 Drill ahead with build BHA 10,570' MD. - 2.5 I 2.6 bpm. - 3000 psi - 1-2k WOB - 70 ROP 09:00 - 11 :00 2.00 DRILL P PROD1 POOH with build BHA from 10,570' MD. 11 :00 - 12:30 1.50 DRILL P PROD1 LD build BHA. PU EWR, 3.75" DS49 bit. Set motor to 1.04 deg. 12:30 - 15:00 2.50 DRILL P PROD1 RIH with lateral BHA at 90 fpm, minimum circulation. - Shallow hole test MWD and orienter at 3,000' MD. 15:00 - 16:00 1.00 DRILL P PROD1 Tag TD at 10,585' MD. Correct to 10,570' MD. Mad pass build section to 10,308' MD. 16:00 - 17:30 1.50 DRILL C PROD1 POOH. - Prepping for rig move for Doyon 16 access to S-Pad. 17:30 - 18:45 1.25 DRILL C PROD1 LD Lateral BHA. - Download RES tool. 18:45 - 20:00 1.25 DRILL C PROD1 RD rig to allow Doyon 16 to pass onto location. 20:00 - 23:00 3.00 DRILL C PROD1 Move off well and allow Doyon 16 to pass. 23:00 - 00:00 1.00 DRILL C PROD1 Move back onto well. 9/11/2004 00:00 - 01 :30 1.50 BOPSU C PROD1 NU and body test BOP. Replace and pressure test choke manifold valve #7. 01 :30 - 03:00 1.50 DRILL C PROD1 MU lateral drilling BHA. 03:00 - 05:10 2.17 DRILL C PROD1 Shallow hole test and RIH with 1.04 motor. - Light tag at top of whipstock. Printed: 9/20/2004 11: 14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/11/2004 05:10 - 05:30 0.33 DRILL P PROD1 Tie-in log correction -11'. 05:30 - 07:15 1.75 DRILL P PROD1 Pull up to window, orient TF to 60L. RIH. 07:15-11:00 3.75 DRILL P PROD1 Drill lateral section to 10,750' MD. - 2.5-2.58 bpm. - 3100 psi (2850 free spin). - SO 18k; PU 38k - Orient periodically, as required. 11 :00 - 11 :30 0.50 DRILL P PROD1 Wiper trip to window. - No overpulls. 11 :30 - 12:30 1.00 DRILL P PROD1 Drill lateral section to 10,850' MD. - Free spin 3000 psi. - 2.6/2.74 bpm. - 3250 psi. - 100 - 115 ROP, increase wiper trip frequency. - 3-5k overpull when picking up off bottom. 12:30 - 13:30 1.00 DRILL P PROD1 Wiper trip to tubing tail. - Hole in good condition. 13:30 - 13:45 0.25 DRILL P PROD1 Orient tool face to 90R. 13:45 - 14:30 0.75 DRILL P PROD1 Drill lateral section to 10,888' MD - 2.5 12.64 bpm. - 3250 psi (free spin 3000 psi) - Eratic tool face requiring repeated orientation. 14:30 - 16:00 1.50 DRILL P PROD1 Drill lateral section to 10,988' MD. - 2.57 I 2.65 bpm. - 3300 psi (free spin 3000 psi) - Continued difficulty with orienter (180 deg "flop") 16:00 - 17:30 1.50 DRILL P PROD1 Wiper trip to window. - Tie in (correct +9 ft). - Tagged up on shale at 10,980' MD. 17:30 - 17:45 0.25 DRILL P PROD1 Orient TF to 11 OR 17:45 - 18:45 1.00 DRILL P PROD1 Drill lateral section to 11050' 18:45 - 19:05 0.33 DRILL P PROD1 Wiper to 10350. No problem at 10980. 19:05 - 19:50 0.75 DRILL P PROD1 Drill lateral section to 11150' MD. - 2.52 I 2.66 bpm. - 3230 psi (free spin 2920 psi) - Up WT 34K, DN wt 16K - ROP 116 WOB 2K 19:50 - 20:00 0.17 DRILL P PROD1 Wiper to 11050. 20:00 - 21 :00 1.00 DRILL P PROD1 Drill lateral section to 11200' MD. - 2.52 12.66 bpm. - 3230 psi (free spin 2920 psi) - Up WT 34K, DN wt 16K - ROP 90 WOB 2K - TF 90R 21 :00 - 21 :30 0.50 DRILL P PROD1 Wiper to tailpipe. 21 :30 - 22:45 1.25 DRILL N DPRB PROD1 Setting down on window. Orient around. No Go 22:45 - 00:00 1.25 DRILL N DPRB PROD1 POH 9/12/2004 00:00 - 00:40 0.67 DRILL N DPRB PROD1 POH 00:40 - 02:15 1.58 DRILL N DPRB PROD1 PU 3,78" Crayola 2.0 motor + 2 joints PH-6 = 155.92' 02:15 - 04:00 1.75 DRILL N DPRB PROD1 RIH with window dressing assembly. 04:00 - 04:15 0.25 DRILL N DPRB PROD1 Orient27L. Run thru window at 2.6 bpm. Went thru no problem. RIH to 10385 inclination 52 have to be out of window. 04:15 - 04:50 0.58 DRILL N DPRB PROD1 Log up from 10385 to tie - in.-15' correction. Printed: 9/20/2004 11: 14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/12/2004 04:50 - 08:15 3.42 DRILL N DPRB PROD1 Dress window. - Back Ream thru window TF 27L. 2.57 bpm 3030 psi. TF 15R, 45R. No Motor work. - Attempt 75 R No Go at 10294.3. Top of WS. Orient 75L No Problem, RIH to 10,322' MD. - Orient to 117R, backream through window at 2.5 bpm, 3000 psi. No motor work. - RBIH through window at 117R. - Orient to 165L, backream through window at 2.5 bpm, 3000 psi. Some motor work observed. 08: 15 - 09:45 1.50 DRILL N DPRB PROD1 POOH with crayola mill. - 2.17/1.77 bpm - 2450 psi 09:45 - 11 :00 1.25 DRILL N DPRB PROD1 LD Crayola mill (3.71" no go 13.7" go). Re-program MWD. PU BHA #6. PU used 3.75 x 4.25 Hycalog DS100 bicenter. Adjust motor to 1.4 deg. 11 :00 - 13:00 2.00 DRILL N DPRB PROD1 RIH with BHA #6. - Orient to 75L to enter window. No problems. 13:00 - 13:40 0.67 DRILL N DPRB PROD1 Tie in (- 12 ft correction). RIH to bottom at 11,202' MD. - 2.5/2.8 bpm; 3050 psi. - 18k SO; 36k PU. - Conducting mud swap. 13:40 - 14:00 0.33 DRILL P PROD1 Orient TF to 120R. 14:00 - 15:15 1.25 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11,221' MD. - Conducting mud swap. - Difficulty getting started. - 2.48 I 2.66 bpm - 3100 psi 15:15-15:30 0.25 DRILL P PROD1 Orient TF to 100R. 15:30 - 16:15 0.75 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11,248' MD. - 2.48 I 2.58 bpm - 3300 psi (free spin 3000 psi) - 30 ROP. 16:15 - 16:30 0.25 DRILL P PROD1 Orient TF to 70L. 16:30 - 19:45 3.25 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11350.' MD - 2.5 I 2.6 bpm - 3300 psi (free spin 3000 psi) - 30 ROP. 19:45 - 20:45 1.00 DRILL P PROD1 Wiper to window 10350'. 20:45 - 00:00 3.25 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11400.' MD - 2.5 / 2.6 bpm - 3450 psi (free spin 3000 psi) - 27 ROP. - WOB 4-5 -32K Up Wt -16K Dn Wt 9/13/2004 00:00 - 04:30 4.50 DRILL P PROD1 Continue Drill ahead in Lateral Zone 4 to 11500.' MD - 2.5 I 2.6 bpm - 3450 psi (free spin 3000 psi) - 27 ROP. Printed: 9/20/2004 11: 14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/13/2004 00:00 - 04:30 4.50 DRILL P PROD1 - WOB 4-5 -32K Up Wt -16K Dn Wt 04:30 - 05:50 1.33 DRILL P PROD1 Wiper to window. Sticky at 11340-11370. 05:50 - 08:00 2.17 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11,562' MD - 2.6/2.7 bpm - 3400 psi (free spin 3000 psi) - 30 ROP. - WOB 4-5 -32K Up Wt -16K Dn Wt 08:00 - 11 :30 3.50 DRILL P PROD1 POOH for bit/motor. - Slow ROP and continuous stalling. Changeout BHA. - PU 34k; S016K - Pumping Lo/Hi vis sweep down coil to clean 7" low energy annulus. - 2.65 bpm, 3200 psi. - Reciprocate in 7" low energy annulus with sweep coming out of BHA. - Observed sweep coming over shakers. Nolminimal increase in cuttings. Did catch some rubber chunks, suspect from motor. 11:30-13:15 1.75 DRILL P PROD1 LD BHA #6. MU BHA #7. - Change out bit. White clays in junk slots. - Change out motor. Decrease bend to 1.04 deg. 13:15 - 15:00 1.75 DRILL P PROD1 RIH with BHA #7, lateral drilling in Zone 4. - Shallow hole test MWDIOrienter at 3000' MD. 15:00 - 16:00 1.00 DRILL P PROD1 Tie in (-13 ft correction). RIH through window at 27L. Slick. 16:00 - 16:45 0.75 DRILL P PROD1 Drill ahead in Lateral Zone 4 - 2.6/2.7 bpm - 3000 psi (free spin 2700 psi) - 35K Up Wt - 17K Dn Wt - ROP = 1 00 - 130 fph 16:45 -17:15 0.50 DRILL P PROD1 Orient TF to 70R. 17:15 - 18:20 1.08 DRILL P PROD1 Drill ahead in Lateral Zone 4 - 2.6/2.7 bpm - 3000 psi (free spin 2700 psi) - 35K Up Wt - 17K Dn Wt - ROP = 100 - 130 fph - Evidence of differential sticking. 18:20 - 21 :45 3.42 DRILL P PROD1 Wiper to wimdow set down 11350 orient 180 work thru after many attempts. 21:45 - 23:30 1.75 DRILL P PROD1 Drill ahead in Lateral Zone 4 - 2.6/2.7 bpm - 3250 psi (free spin 3000 psi) - 35K Up Wt - 17K Dn Wt - ROP = 100 - 130 fph+ 23:30 - 00:00 0.50 DRILL N RREP PROD1 #1 motor down. Pick Up slow at .8 bpm. 9/14/2004 00:00 - 00:20 0.33 DRILL P PROD1 Directionlally drill to 11850'. Printed: 9/20/2004 11:14:56AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/14/2004 00:20 - 03:30 3.17 DRILL P PROD1 Wiper to window. Backream 11350 shale. Set Down at 11353. No Go . Orient 156R Set down 11368.work thru. Back ream tight spot. 11350 -11375'. Set down and work thru. 03:30 - 08:00 4.50 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11, 956' MD - 2.6/2.7 bpm - 3300 psi (free spin 3000 psi) - 100 ROP falling to 20 ROP at 11,900' MD. - WOB 12 - 36K Up Wt - 14K Dn Wt Drill to 11900 . Well took drink 20 bbl. Continue to drill losing 10 bbll hr. 08:00 - 08: 15 0.25 DRILL P PROD1 Orient to 150L 08:15 - 09:30 1.25 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 11,985' MD - 2.51 2.6 bpm - 3000 psi (free spin 2800 psi) - ROP sporadic from 10 fph to 130 fph. - 35K Up Wt - 14K Dn Wt - Losses are minimal 09:30 - 10:00 0.50 DRILL P PROD1 Wiper trip to the tubing tail. - 5k overpull, no motor work, from 11,400 - 11,300' MD. - 10k overpull and motor work at 11,330' MD - Tie in. (+ 5 ft correction) - No problem entering window. 10:00 - 14:30 4.50 DRILL P PROD1 Drill ahead in Lateral Zone 4 to 12,037' MD - 2.5/2.6 bpm - 3000 psi (free spin 2800 psi) - ROP sporadic from 10 fph to 130 fph. - 35K Up Wt - 14K Dn Wt Swap mud good weight transfer but can't drill. POH to look at bit. 14:30 - 16:45 2.25 DRILL P PROD1 POH. 16:45 - 18:45 2.00 DRILL P PROD1 CIO Bit, bit was balled up, Adjust motor to 1.37 deg. Download RES data. 18:45 - 20:45 2.00 DRILL P PROD1 RIH with MWD RES BHA #8. DS49 bit and 1.37 deg motor. SHT tools OK. RIH. 20:45 - 21 :30 0.75 DRILL P PROD1 Log tie-in with GR above window at 10,250'. [-10 ft CTD]. 21 :30 - 22:30 1.00 DRILL P PROD1 Set down wt in window at 10298 ft. TOWS at 10,293'. Orient TF to high side and went thru window on third try. RIH. Stacked wt at shale at 11350' and fell thru on first try. RIH clean to TD. Tag TD at 12037'. 22:30 - 22:45 0.25 DRILL P PROD1 Orient TF to 60L. 22:45 - 00:00 1.25 DRILL P PROD1 Drilling Shublik, 2.6/2.6 bpm, 3100 - 3600 psi, 60L, 82 deg incl, slow drilling. Drilled to 12048'. 9/15/2004 00:00 - 03:00 3.00 DRILL P PROD1 Drilling Lower Shublik, 2.6/2.6 bpm, 3100-4000 psi, 83 deg Incl, 50L, Slow drilling, stacking wt, several stalls, Fluid loss of 7 BPH. Drilled to 12,070'. 03:00 - 04:30 1.50 DRILL P PROD1 Drilling Z4, 2.6/2.6 bpm, 3100-4000 psi, 84 deg Incl, 20L, Many stalls, Staking wt. Not slidig well, add 1 % Lubetex to system. Fluid loss of 7 BPH. Drilled to 12,086'. Printed: 9/20/2004 11:14:56AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/15/2004 04:30 - 04:45 0.25 DRILL P PROD1 Orient TF to 100L. 04:45 - 06:00 1.25 DRILL P PROD1 Drilling Z4, 2.6/2.6 bpm, 3100-4000 psi, 86 deg Incl, 100L, Drilled to 12,112 ft. 06:00 - 06:15 0.25 DRILL P PROD1 Orient TF to 70R. 06:15 - 07:50 1.58 DRILL P PROD1 Drilling Z4, 2.5/2.5 bpm, 3450 psi, FS= 3200 85 deg Incl, 100R, Drilled to 12,160 ft. Stacking continues to be problem. 07:50 - 09:30 1.67 DRILL P PROD1 Short wiper. No Go. Wiper to window. 09:30 - 13:20 3.83 DRILL P PROD1 Drilling Z4, 2.5/2.5 bpm, 3450 psi, FS= 3200 85 deg Incl, 80R, Drilled to 12,160 ft. Stacking & stalling continues to be problem. Lot of reactive torque. 13:20 - 13:40 0.33 DRILL P PROD1 Short wiper 13:40 - 18:00 4.33 DRILL P PROD1 Drilling Z4, 2.5/2.5 bpm, 3450 psi, FS= 3200 85 deg Incl, 180R, Drilled to 12,272 ft. Stacking & stalling continues to be problem. Lot of reactive torque.Add 150 bbl new mud with 12 ppb Kia Gard and Drill Zone. Effective 5% lubricant in mud inclusive of Drill Zone. Seemed to do some good. Resumed to intermitent drilling. Stacking. Drilled to 12,280'. 18:00 - 21 :40 3.67 DRILL P PROD1 POH for new bit, motor and Agitator. Had motor work and overpull in shale at 11350', not bad, Some overpull at window. Clean up 7" liner and POH chasing returns to surface. Pump 2.8 bpm to surface. 21 :40 - 21 :50 0.17 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for MWD BHA C/O. 21 :50 - 23:45 1.92 DRILL P PROD1 CIO bit, motor and add Agitator tool. Bit was [1,6,1] with broken gauge cutters from bad window. Wear on gauge matrix from formation, so slow ROP. M/U 1.04 deg new motor, re-built DS49 Bit, and added Agitator as backup to drill to needed TD. Download and upload RES tool. OAL = 97.18 ft. 23:45 - 00:00 0.25 DRILL P PROD1 RIH with RES, Vibrator, MWD lateral BHA #9. SHT tools, OK. RIH. 9/16/2004 00:00 - 01 :45 1.75 DRILL P PROD1 RIH with BHA #9, Re-built DS49 bit, 1.04 deg motor, RES MWD and Agitator. 01:45 - 02:15 0.50 DRILL P PROD1 Sat down at window with 90L, 24L, 7L and 10R TF. Pump at 0 .5, 0.75, 1.0 and 1.25 bpm, Bit fell thru at 1.25 BPM at 10R TF. 02:15 - 02:50 0.58 DRILL P PROD1 Log Tie-in with GR. Subtract 11 ft CTD. 02:50 - 03:45 0.92 DRILL P PROD1 RIH. RIH clean to TD. Tag at 12,283 ft. 03:45 - 04:00 0.25 DRILL P PROD1 Orient TF to 100R. 04:00 - 04:20 0.33 DRILL P PROD1 Drilling Z4 lateral, 2.5/2.5 bpm, 3350-4000 psi, 95R, 87 deg Incl, 60 fph. Good weight transfer, drilling with 17K up wt. RIH wt = 21 K. Steady WOB, steady ROP. Drilled to 12,298'. 04:20 - 04:40 0.33 DRILL P PROD1 Orient TF to 100L. 04:40 - 06:00 1.33 DRILL P PROD1 Drilled Z4 Lateral, 2.4/2.4 bpm, 3200-3800 psi, 90L, 84 deg incl, 70 fph, Good weight transfer, drilling with 15K up wt, 21 K Dwn WT off bottom, steady WOB, Steady ROP. Drilled to 12,370'. 06:00 - 07:10 1.17 DRILL P PROD1 Drilled Z4 Lateral, 2.4/2.4 bpm, 3200-3800 psi, 80L, 84 deg incl, 70 fph, Drill to 12420' 07:10 - 09:15 2.08 DRILL P PROD1 Wiper to window. Motor work at 11350 = 50 psi. while POH. Motor work whle RIH at 10400-10577, 11345 MW 300 psi spike. 09:15 - 12:00 2.75 DRILL P PROD1 Drilled Z4 Lateral, 2.5/2.5 bpm, 3500 psi FS 3800 psi, 80L, Printed: 9/20/2004 11 :14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/16/2004 09:15 - 12:00 2.75 DRILL P PROD1 84 deg incl, 70 fph, Drill to 12590' 12:00 - 14:00 2.00 DRILL P PROD1 Wiper to window. POH MW at 10590 and 10510 to 10400 270 psi MW. RIH MW at 10425 & 11350. RIH min rate .17 surface weight 12-14K. @ 12,000' to 12,590'. 14:00 - 15:00 1.00 DRILL P PROD1 Drilled 24 Lateral, 2.5 / 2.5 bpm, 3500 psi FS 3800 psi, 170L, 87 deg incl, 60 fph, Drill to 12640' 15:00 - 16:20 1.33 DRILL P PROD1 Wiper to window MW at 10500 to 10460. PU to 10350' 16:20 - 17:00 0.67 DRILL P PROD1 log up Tie -in. Correction + 23'. 17:00 - 17:45 0.75 DRILL P PROD1 RIH set down once at 11350. Tag final TD at 12,658. 17:45 - 21:10 3.42 DRILL P PROD1 POH, 2.4 bpm 33 ftImin. Motor work at 11, 350. POH. Small overpull at window. Circ while POH to surface. Flag Coil at 9700' and 7300' EOP. Small amount of black scale seen on shaker when BHA reached surface. 21:10 - 22:30 1.33 DRILL P PROD1 Download RES data. UO BHA. Recover 100% of BHA. Bit graded at 2,4,1. Some wear on one side of SWS CTC from Agitator tool. Worn thru one set screw and set screw threads were washed out. The rest of the BHA was OK. 22:30 - 22:45 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running liner. 22:45 - 23:15 0.50 CASE P RUNPRD Cut off SWS CTC and M/U Baker CTC. Pull and pressure test CTC. Prep rig floor for running liner. 23:15 - 00:00 0.75 CASE P RUNPRD Run 2-7/8", STL Liner with BKR steel bull nose float shoe, 1 jt, BKR float collar, BKR latch collar and 65 jts of 2-7/8", STL liner with turbos. 9/17/2004 00:00 - 03:15 3.25 CASE P RUNPRD Run total of 66 jts of 2-7/8", STL Liner, LSL sub, 22 Jts of 3-3/16" Liner, 2 jts of 3-1/2" STL liner, X Nipple and Baker Deployment Sleeve. Stop and filled liner with water at 45 jts in hole. OAL of liner = 2,859 ft. 03:15 - 03:45 0.50 CASE P RUNPRD M/U Baker CTLRT with LWP. M/U injecter. BHA = 2,868 ft. 03:45 - 05:00 1.25 CASE P RUNPRD RIH with liner on CT. Circ. FloPro at 0.3 bpm. 1200 psi. Stop at flag, correct depth [-19.5 ft CTD] to 10,164 ft. Up wt = 41 K, Dwn wt = 20.5K dwn wt. 05:00 - 06:00 1.00 CASE P RUNPRD Sat down at bottom of window 4 times, fell thru on fifth try. RIH at 60 fpm, circ at 0.3 bpm, 1400 psi. RIH clean to shale at 11,350', went thru shale with 10K wt loss. RIH clean to TD. Tag TD of 12,658' with liner 3 times. Liner is landed at TD. Pump 5/8" steel ball to release from liner. 2.0 bpm, 2500 psi. 06:00 - 06:45 0.75 CASE P RUNPRD Displace 5/8" steel ball with FloPro at 2.0 bpm, slow to 0.5 bpm at 44 bbls, Bump up at 49.9 bbl. Shear at 3750 psi. 06:45 - 10:00 3.25 CASE P RUNPRD Swap well to 2% KCL. 2550 psi at 2.9 bpm. Mix Bio pill 35 bbl. 10:00-10:15 0.25 CASE P RUNPRD PJSM for cement job. 10:15 -11:40 1.42 CEMT P RUNPRD Mix 40 bbl15.8ppg cement. Pump cemet 2.6/2.38 bpm @ 1470 psi. Launch dart with 600 psi. displace with 35 bbl2# bio 3.4/1.9 bpm @2200 psi. When cement turn corner 2.81/2.52 bpm.. PU liner wiper plug @ 59 bbl Bump plug at 76.0 bbl.Calculated 76.7bbl.. Floats held. Pressure to 400 psi pull off liner. 4 bbl cement lost to formation. 11 :40 - 13:45 2.08 CEMT P RUNPRD POH chasing cement. @ 3bpm no losses. Printed: 9/20/2004 11:14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/17/2004 13:45 - 14:45 1.00 CEMT P RUNPRD LD Liner running tools. Flush BOP. 14:45 - 15:00 0.25 EV AL C LOWER1 PJSM logging memory CNL 15:00 - 16:00 1.00 EVAL C LOWER1 Ru logging unit and MU BHA 16:00 - 18:00 2.00 EVAL C LOWER1 RIH 46 stands CSH 1-1/4", M/U SWS MHA. BHA OAL = 2,930'. 18:00 - 19:50 1.83 EVAL C LOWER1 RIH with logging BHA to 9600'. 19:50 - 21 :30 1.67 EVAL C LOWER1 Log down at 30 fpm with SWS memory CNUGR/CCL, 1 bpm, 1300 psi. Tag PBTD at 12,627' CTD. Liner was clean. 21 :30 - 22:30 1.00 EVAL C LOWER1 Log up at 60 fpm, lay in 20 bbl Bleach perf pill at 0.5 bpm while logging up. 0.5 bpm, 500 psi. Log up to 9600'. 22:30 - 23:40 1.17 EVAL C LOWER1 POH. circ at 1 bpm. 23:40 - 00:00 0.33 EVAL C LOWER1 Stand back 1-1/4" CSH workstring. 47 stds. 9/18/2004 00:00 - 01 :15 1.25 EVAL C LOWER1 Stand back a total of 47 stds of CSH workstring. 01: 15 - 01 :30 0.25 EVAL C LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for recovery of SWS memory CNUGR logging tools. 01:30 - 02:15 0.75 EVAL C LOWER1 Layout SWS memory CNL tools. recover motor and mill. MCNUGR indicated PBTD = 12,621 ft. Top of Liner at 9,794 ft. No gas indicated from CNL. Fax'd log to Anc office. 02:15 - 03:00 0.75 CEMT P RUNPRD Pressure test liner lap. Test failed. Lost 2300 psi in 5 min. lAP increased from 80 psi to 220 psi. Fluid leaking from tubing to IA. lAP stayed at 220 psi with 0 psi SIWHP. IA not fluid packed, last fluid level measured at 300 ft. To large of volume to fill with rig test pump. 03:00 - 05:00 2.00 CEMT N DPRB RUNPRD Call out Little Red to pump diesel down inner annulus to prove liner lap is not leaking. MITIA in well handover was done on 12/24/2003, 9 month old test. 05:00 - 08:30 3.50 CEMT P RUNPRD Rig up Little Red to IA. Pump diesel to pressure up IA. PU, IA to 2500 psi and tubing to 2200 psi. + 300 psi density difference to equalize. Hold for 30 min good test. Lost 50 psi in 30 minutes. 08:30 - 09:00 0.50 CEMT RUNPRD RD Little Red. 09:00 - 09:20 0.33 PERFO LOWER1 PJSM of Perforating operations. PU guns. 09:20 - 11 :30 2.17 PERFO LOWER1 MU 10 guns 2" 6SPF 60 degree orientation. RIH on 46 stands of CSH. 11 :30 - 13:30 2.00 LOWER1 RIH . Tag TD and correct to 12621. PU to put guns on depth. 13:30 - 16:00 2.50 LOWER1 Circulate well to clean 2% KCL water. 16:00 - 16:45 0.75 LOWER1 Launch 5/8" aluminum ball with 200 psi. Pumping at 1.6 pbm @ 2300 psi. Ball launched with 12 bbl bleach ahead and 10 bbl bleach behind. At 45 bbl into displacement slow pump to 1 bpm @ 880 psi. Ball on firing head at 58.9 bbls @ 3300 psi fired. Shot indication. Shot on the fly. Bottom shot 12580. PERFORATED INTERVAL: 12,380 - 12,580 ft BKB at 6 SPF. 16:45 - 18:45 2.00 LOWER1 POH to CSH. 18:45 - 19:45 1.00 LOWER1 Stand back CSH workstring. 19:45 - 20:00 0.25 LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS fired perf guns. 20:00 - 21 :00 1.00 LOWER1 Layout SWS fired perf guns, 10 guns, all shots fired. Load out guns from pipe shed. 21 :00 - 22:00 1.00 RIGD P POST RIH with nozzle to 2500 ft. Freeze protect 5-1/2" tubing with 60 Printed: 9/20/2004 11: 14:56 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-14 S-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/31/2004 Rig Release: Rig Number: N1 Spud Date: 8/22/1982 End: 9/18/2004 21 :00 - 22:00 1.00 RIGD P 22:00 - 22:10 0.17 RIGD P 22:10 - 00:00 1.83 RIGD P 9/19/2004 00:00 - 01 :00 1.00 RIGD P POST bbls of diesel to surface. Close master and swab valves. POST SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2 thru coil. POST Displace coil to N2. Send returns to tiger tank. Bleed down coil. Empty and clean rig pits, tiger tank and cuttings tank. POST Nipple down BOPE. N/U tree cap and pressure test. RELEASED RIG AT 0100 HRS, 09/19/2004 A Total of 10 days, 17 hours from rig accept to rig release. The rig move time will be on the DIMS report for DS 02-16B. Printed: 9/20/2004 11: 14:56 AM . . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well S-14A 04-0ct-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,200.00' MD 10,293.00' MD 12,658.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /J / II /I j j / Date ì6!fÁNt-1 Signed~~ U~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Q.,~:J" ""tl·7' ".( "'~'í1 ""f "..."""' '1 - DEFINITIVE Halliburton Sperry-Sun North Slope Alaska BPXA PBU_WOA S Pad S-14A . Job No. AKMW3268702, Surveyed: 16 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292080401 Surface Coordinates: 5979855.00 N, 620347.00 E (70021'12.7929" N, 149001'21.8645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 979855.00 N, 120347.00 E (Grid) Surface Coordinates relative to Structure Reference: 1040.14 S, 2413.88 E (True) Kelly Bushing Elevation: 67. 80ft above Mean Sea Level Kelly Bushing Elevation: 67.80ft above Project V Reference Kelly Bushing Elevation: 67.80ft above Structure Reference SpE!r"'i'Y-SUr, DAILLINS SER.VICeS A Halliburton Company Survey Ref: svy4394 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-14A Your Ref: API 500292080401 Job No. AKMW3268702, Surveyed: 16 September, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 10200.00 46.000 95.000 8589.68 8657.48 63.52 S 4302.75 E 5979860.60 N 624650.22 E 4298.60 Tie On Point MWD Magnetic 10293.00 45.070 95.000 8654.83 8722.63 69.31 S 4368.87 E 5979855.88 N 624716.42 E 1.000 4364.50 Window Point 10330.30 49.830 92.640 8680.05 8747.85 71.12 S 4396.28 E 5979854.51 N 624743.86 E 13.584 4391.84 10369.73 62.060 90.190 8702.09 8769.89 71.87 5 4428.87 E 5979854.28 N 624776.46 E 31.437 4424.39 10401.55 71.100 88.560 8714.72 8782.52 71.54 5 4458.04 E 5979855.08 N 624805.61 E 28.795 4453.55 . 10434.19 81.300 85.750 8722.50 8790.30 69.95 S 4489.65 E 5979857.18 N 624837.19 E 32.346 4485.20 10469.29 88.070 81.530 8725.75 8793.55 66.07 S 4524.36 E 5979861.61 N 624871.83 E 22.697 4520.01 10504.40 87.890 67.640 8726.99 8794.79 56.77 S 4558.10 E 5979871.45 N 624905.42 E 39.540 4554.03 10536.85 92.720 60.260 8726.82 8794.62 42.53 S 4587.22 E 5979886.15 N 624934.31 E 27.175 4583.59 10569.93 92.470 47.340 8725.32 8793.12 23.06 S 4613.83 E 5979906.06 N 624960.61 E 39.024 4610.80 10600.50 92.070 46.780 8724.11 8791.91 2.255 4636.19 E 5979927.22 N 624982.63 E 2.250 4633.81 1 0632.44 93.920 49.250 8722.44 8790.24 19.08 N 4659.90 E 5979948.93 N 625005.99 E 9.653 4658.18 10665.07 94.270 51.360 8720.11 8787.91 39.87 N 4684.94 E 5979970.12 N 625030.70 E 6.539 4683.86 10698.81 96.210 54.880 8717.02 8784.82 60.03 N 4711.81 E 5979990.71 N 625057.24 E 11.874 4711.36 1 0732.25 98.060 58.060 8712.87 8780.67 78.36 N 4739.47 E 5980009.48 N 625084.59 E 10.938 4739.58 10762.98 98.770 61.580 8708.37 8776.17 93.64 N 4765.74 E 5980025.18 N 625110.62 E 11.564 4766.32 10802.96 97.620 64.930 8702.67 8770.47 111.44 N 4801.07 E 5980043.55 N 625145.66 E 8.778 4802.20 10836.76 94.360 64.930 8699.14 8766.94 125.68 N 4831.52 E 5980058.28 N 625175.87 E 9.645 4833.08 10867.93 93.570 67.040 8696.99 8764.79 138.34 N 4859.92 E 5980071.39 N 625204.07 E 7.213 4861.86 10899.55 94.710 66.870 8694.71 8762.51 150.68 N 4888.94 E 5980084.20 N 625232.89 E 3.645 4891.26 10933.65 94.180 68.980 8692.06 8759.86 163.46 N 4920.44 E 5980097.48 N 625264.18 E 6.362 4923.15 . 1 0965.48 94.630 73.210 8689.62 8757.42 173.74 N 4950.46 E 5980108.24 N 625294.03 E 13.325 4953.48 10998.37 94.450 75.500 8687.01 8754.81 182.58 N 4982.03 E 5980117.58 N 625325.45 E 6.962 4985.31 11034.79 93.220 79.020 8684.58 8752.38 190.59 N 5017.47E 5980126.16 N 625360.76 E 10.217 5020.98 11068.45 92.860 85.020 8682.79 8750.59 195.26 N 5050.74 E 5980131.36 N 625393.95 E 17.832 5054.39 11098.00 93.220 88.010 8681.22 8749.02 197.05N 5080.19 E 5980133.63 N 625423.37 E 10.177 5083.88 11127.10 93.740 91.360 8679.46 8747.26 197.21 N 5109.23 E 5980134.25 N 625452.40 E 11.629 5112.91 11155.49 93.920 95.060 8677.56 8745.36 195.62 N 5137.51 E 5980133.12 N 625480.70 E 13.019 5141.12 11187.05 94.180 97.530 8675.33 8743.13 192.17 N 5168.80 E 5980130.17 N 625512.04 E 7.850 5172.29 11217.20 90.930 99.640 8673.99 8741.79 187.68 N 5198.57 E 5980126.16 N 625541.89 E 12.848 5201.91 30 September, 2004·13:29 Page 2 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-14A Your Ref: API 500292080401 Job No. AKMW3268702, Surveyed: 16 September, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11248.09 88.370 102.110 8674.17 8741.97 181.85 N 5228.90 E 5980120.82 N 625572.31 E 11.516 5232.04 11279.54 92.160 100.170 8674.03 8741.83 175.78 N 5259.75 E 5980115.24 N 625603.25 E 13.537 5262.68 11307.14 95.770 98.230 8672.12 8739.92 171.37N 5286.93 E 5980111.27 N 625630.49 E 14.840 5289.70 11336.27 96.390 93.470 8669.03 8736.83 168.42 N 5315.73 E 5980108.79 N 625659.34 E 16.387 5318.40 11367.65 92.160 91.890 8666.69 8734.49 166.96 N 5346.98 E 5980107.83 N 625690.61 E 14.384 5349.59 11399.08 89.250 90.650 8666.31 8734.11 166.26 N 5378.40 E 5980107.63 N 625722.04 E 10.064 5380.97 . 11434.38 87.840 87.480 8667.20 8735.00 166.84 N 5413.68 E 5980108.78 N 625757.30 E 9.826 5416.25 11467.70 91.190 84.140 8667.49 8735.29 169.27 N 5446.90 E 5980111.74 N 625790.48 E 14.196 5449.53 11496.38 91.720 79.910 8666.76 8734.56 173.25 N 5475.29 E 5980116.18 N 625818.80 E 14.860 5478.03 11528.20 91.720 80.790 8665.80 8733.60 178.58 N 5506.64 E 5980122.01 N 625850.06 E 2.764 5509.53 11559.84 93.300 80.080 8664.42 8732.22 183.83 N 5537.81 E 5980127.76 N 625881.14 E 5.474 5540.85 11591.92 90.480 83.250 8663.36 8731.16 188.48 N 5569.53 E 5980132.92 N 625912.78 E 13.221 5572.70 11627.44 91.370 86.780 8662.79 8730.59 191.56N 5604.90 E 5980136.57 N 625948.10 E 10.248 5608.16 11658.03 91.810 88.720 8661.94 8729.74 192.76 N 5635.45 E 5980138.26 N 625978.63 E 6.501 5638.73 11700.65 86.080 91.180 8662.72 8730.52 192.80 N 5678.05 E 5980138.98 N 626021.22 E 14.630 5681.30 11732.27 83.960 94.880 8665.47 8733.27 191.14 N 5709.50 E 5980137.83 N 626052.69 E 13.447 5712.68 11762.33 83.170 98.940 8668.84 8736.64 187.55 N 5739.14 E 5980134.71 N 626082.39 E 13.676 5742.20 11793.39 83.700 99.110 8672.39 8740.19 182.71 N 5769.62 E 5980130.36 N 626112.94 E 1.791 5772.51 11831.94 86.430 96.120 8675.70 8743.50 177.62 N 5807.68 E 5980125.89 N 626151.08 E 10.481 5810.39 11866.16 88.190 93.650 8677.31 8745.11 174.71 N 5841.73 E 5980123.52 N 626185.17 E 8.856 5844.34 11901.25 89.340 91.360 8678.07 8745.87 173.18 N 5876.78 E 5980122.55 N 626220.24 E 7.301 5879.32 11938.66 88.900 84.840 8678.64 8746.44 174.42 N 5914.14 E 5980124.39 N 626257.58 E 17 .466 5916.70 . 11970.48 84.230 88.010 8680.55 8748.35 176.40 N 5945.83 E 5980126.88 N 626289.23 E 17.727 5948.44 12001.92 82.200 86.780 8684.26 8752.06 177.82 N 5977.02 E 5980128.80 N 626320.39 E 7.535 5979.65 12030.77 82.200 86.600 8688.18 8755.98 179.47 N 6005.55 E 5980130.91 N 626348.89 E 0.618 6008.22 12061.48 83.350 82.900 8692.04 8759.84 182.26 N 6035.88 E 5980134.19 N 626379.18 E 12.525 6038.63 12097.19 85.020 78.320 8695.66 8763.46 188.05 N 6070.92 E 5980140.55 N 626414.12 E 13.589 6073.83 12132.27 85.550 82.730 8698.55 8766.35 193.81 N 6105.40 E 5980146.85 N 626448.50 E 12.619 6108.47 12163.88 85.460 87.480 8701.03 8768.83 196.49 N 6136.79 E 5980150.04 N 626479.84 E 14.983 6139.93 12195.69 85.730 92.240 8703.47 8771.27 196.57 N 6168.49 E 5980150.63 N 626511.54 E 14.944 6171.62 12226.86 85.730 97.880 8705.79 8773.59 193.83 N 6199.44 E 5980148.39 N 626542.53 E 18.044 6202.47 12256.24 87.050 102.110 8707.64 8775.44 188.74 N 6228.31 E 5980143.76 N 626571.48 E 15.055 6231.17 12288.75 87.220 108.280 8709.27 8777.07 180.24 N 6259.63 E 5980135.76 N 626602.93 E 18.962 6262.20 12318.36 85.550 104.580 8711.14 8778.94 171.88 N 6287.97 E 5980127.86 N 626631.40 E 13.687 6290.26 12349.29 83.440 101.400 8714.11 8781.91 164.96 N 6317.96 E 5980121.42 N 626661.50 E 12.299 6320.02 30 September, 2004 - 13:29 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-14A Your Ref: API 500292080401 Job No. AKMW3268702, Surveyed: 16 September, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 12380.08 84.320 99.470 8717.39 8785.19 159.41 N 6348.07 E 5980116.36 N 626691.69 E 6.857 6349.94 12410.70 82.380 94.710 8720.94 8788.74 155.66 N 6378.24 E 5980113.09 N 626721.92 E 16.689 6379.97 12446.32 83.880 90.480 8725.20 8793.00 154.06 N 6413.56 E 5980112.06 N 626757.26 E 12.519 6415.23 12479.31 85.900 87.840 8728.14 8795.94 154.54 N 6446.41 E 5980113.07 N 626790.10 E 10.051 6448.07 12511.92 85.810 89.250 8730.49 8798.29 155.37 N 6478.92 E 5980114.42 N 626822.59 E 4.321 6480.60 12547.39 80.620 93.650 8734.69 8802.49 154.49 N 6514.11 E 5980114.10 N 626857.79 E 19.124 6515.74 . 12578.48 75.150 93.300 8741.21 8809.01 152.64 N 6544.44 E 5980112.75 N 626888.15 E 17.628 6546.00 12615.95 69.160 93.470 8752.69 8820.49 150.54 N 6580.03 E 5980111.21 N 626923.76 E 15.992 6581.50 12658.00 69.160 93.470 8767.65 8835.45 148.16 N 6619.26 E 5980109.47 N 626963.03 E 0.000 6620.64 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 88.190° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12658.00ft., The Bottom Hole Displacement is 6620.92ft., in the Direction of 88.718° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 10200.00 10293.00 12658.00 8657.48 8722.63 8835.45 63.52 S 69.31 S 148.16 N 4302.75 E 4368.87 E 6619.26 E Tie On Point Window Point Projected Survey 30 September, 2004 - 13:29 Page 4 of 5 Dril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-14A Your Ref: API 500292080401 Job No. AKMW3268702, Surveyed: 16 September, 2004 BPXA North Slope Alaska Survey tool prOf/ram for S-14A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10200.00 0.00 10200.00 8657.48 12658.00 8657.48 BP High Accuracy Gyro - CB-GYRO-MS (S-14) 8835.45 MWD Magnetic (S-14A) . . 30 September, 2004 - 13:29 Page 50f5 DríllQuest 3.03.06.006 . TREE : 6" McEVOY . WB-LHEAD: 13-3/8" McEVOY S-14A SAaOTES: *** TxlA COMM POST CTD ACTUATOR: OTIS SID CK *** KB. ELEV : 67.77' BF. ELEV : 39.07' KOp: 3200' 2093' 1-15-1/2" OTIS SSSV NIP, ID - 4.562" I Max Angle: 99 @ 10763' . I Datum MD : 10365 = -j 2591' H 9-5/8" DV PKR I -:::-'~~~~..~~~_...."'--~....,-- = Datum TVD : 8700' SS GAS LIFT MANDRB-S ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8" CSG, 72#, L-80, ID: 12.347" I 2676' ~ ~ 13 3100 3031 9 OTIS LBD DMY RA 0 09/16/82 12 4921 4620 38 OTIS LBD DMY RA 0 09/16/82 11 6337 5734 37 OTIS LBO DMY RA 0 09/16/82 Minimum ID = 2.37" @ 10541' L 10 7081 6338 37 OTIS LBD DMY RA 0 09/16/82 9 7237 6462 37 OTIS LBD DMY RA 0 09/16/82 2·7/8" LNR 8 7726 6842 42 OTIS LBD DMY RA 0 09/16/82 7 7871 6948 44 OTIS LBD DMY RA 0 09/16/82 6 8237 7213 44 OTIS LBD DMY RA 0 09/16/82 5 8392 4325 43 OTIS LBD DMY RA 0 09/16/82 4 8754 7587 45 OTIS LBD DMY RA 0 09/16/82 3 8911 7699 45 OTIS LBD DMY RA 0 09/16/82 2 9401 8043 48 OTIS LBD DMY RA 0 09/16/82 1 9557 8148 48 OTIS LBD DMY RA 0 09/16/82 I I 9630' H 5-1/2" OTIS XA SLIDING SLEEVE, ID:= 4.562" I í ¡- ---i 9687' -120' BAKER SBR TBG SEAL ASSY I 15-1/2" TBG, 17#, L-80 IPC, .0232 bpf, ID: 4.892" I x: 9719' 1-19-5/8" BAKER PKR, ID = 4.00" I 9719' ~ 9726' 1-1 MILLED OUT EXTENSION, ID := ?? I TOPOF 4-1/2" TBG I 9734' - ............. -15-1/2" x 4-112" XO I ,...- 9733' TOP OF 7" LNR I . 9774' -14-1/2" OTIS X NIP, ID - 3.813" I 9792' pi II 9799' 1-13-1/2" BKR DEPLOY SLV, ID 3.000" I . I 9815' J--L4 1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND LNR) I . 9838' -13-1/2" HES X NIP, ID - 2.813" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID: 3.958" I 9856' 1 9856' 1-14-1/2' BAKER TBG TAIL, ID - 3.958" (BEHIND LNR) I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID: 2.990" I 9871' I 9871' 1-13-1/2" x 3-3116" XO, ID: 2.786" I 19-5/8" CSG, 47#, L-80, ID: 8.681" I 10064' 1----4 .. 10121' -1 HOLE IN 7" LNR (POST CTD 9/19/04) I PERFORATION SUMMARY I 10296' H TOP OF WHIPSTOCK I REF LOG: CNUGR ON 09/18/04 I MILLOUTWINDOW 10298' - ????' I ANGLE AT TOP PERF: 84° @ 12380' Note: Refer to Production DB for historical perf data . SIZE SPF INTERVAL Opn/Sqz DATE 0 10541' H3-3/16" X 2-718" XO, ID: 2.440"1 2" 6 12380 - 12580 0 09/18/04 1 7" LNR, 26#, L-80 I 11216' I 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" H 10541' I PBTD I 12621' I ~ 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID: 2.441" I 12658' L V I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 09/16/82 ORIGINAL COM PLETION WB-L: S-14A 09/18/04 JLM/TLH CTD SIDETRACK (S-14A) PERMIT No: 2040710 API No: 50-029-20804-01 SEC35, T12N, T12E BP Exploration (Alaska) Injection Well S-14A Failed MITlA . . ~(zzfw Hello Jim & Winton. Well S-14A (PTD not available, it's a new CT sidetrack) has indications of TxIA communication. CTD sidetracked the well and on 9/18/04 the IA pressure was observed to increase during the liner lap pressure test. The IA was then pressured to 2500 psi and the tubing pressure increased to 2200 psi. CTD is off the well and it is currently shut-in. We are evaluating several options, including: - Conducting a leak rate test and LDL to determine the leak point. - Running GLV's, pre-producing the well and conducting a TIFL. We will review the evaluation options with you and keep you informed of evaluation progress. Attached is the field annotated wellbore schematic. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: ~§_~l\º~~~~.:!:_~!:l!:.~_g~_~~yEng:!:p~_~E~~ÞE:..S:~~ «S-14A.ZIP» Content-Description: S-14A.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 1 of 1 9/22/2004 12:46 PM · rP IL- I r~ U -' FRANK H. MURKOWSKI, GOVERNOR AItASKA OILAlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Peter DuCane CT Drilling Engineer BP Exploration (Alaska) Inc, P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-14A BP Exploration (Alaska) Inc. Permit No: 204-071 Surface Location: 1651' SNL, 2185' EWL, SEe. 35, Tl2N, Rl2E, UM Bottomhole Location: 1448' SNL, 3407' EWL, SEC. 36, TI2N, RI2E, UM Dear Mr. DuCane: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you :ITom obtaining additional permits or approvals required by law :ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio witness any required test. Contact the Commission's North Slope petroleum field inspec rat -3607 (pager). BY ORDER 9F THE COMMISSION DA TED this.(- day of May, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . y.J6~ 5/5/2.004- .. STATE OF ALASKA . RECEIVED ALASKA~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL APR 2 8 2004 20 MC 25.005 Alaska Oil & Gas Cons. Commission 11b. Current Well Class 0 Exploratory 0 Development ~il.,.hC&4uItiple Zone I 0 Stratigraphic Test II Service 0 Development ~!:t"1!) ~Ie Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU S-14A 6. Proposed Depth: 12. Field I Pool(s): MD 12525 TVD 8798 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 385193 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1651' SNL, 2185' EWL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 1722' SNL. 1279' EWL, SEC. 36, T12N, R12E, UM Total Depth: 1448' SNL, 3407' EWL, SEC. 36, T12N, R12E, UM 9. Acres in Property: 2560 13. Approximate Spud Date: 06/14/04 14. Distance to Nearest Property: 10100' 8. Land Use Permit: 4b. Location of Well (State Base Plane Coordinates): Surface: x- 620347 y- 5979855 Zone- ASP4 16. Deviated Wells: Kickoff Depth tß>Cðsing Program Size CasinQ WeiQht 4-1/8" x 3-3/4" 3-3/16" x 2-7/8" 6.4# I 6.5# 10305 ft Maximum Hole Angle Specifications Grade CouDlinQ L-80 TCIII ST 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 67.8' feet 926' away from M-14 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) 940 Downhole: 3550 psig Surface: 2663 psig S~ttil1g pepth Top .... .... .. Bottom Lenath MD TVD MD TVD 2740' .1Q6ðO ~ 12525 8798 'H ~~ Wql\ (c.f. or sacks) OncludinQ staQe data) 127 cu ft Class 'G' Hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): 11216 9359 10510 10510 I 8875 I \,.;aSIOQ Length Size H........" MD Junk (measured): None TVD Conductor 110' 20" x 30" 8 cu yds Concrete 110' ~llrf::lr.p. 2676' 13-3/8" 3720 cu ft Arctic Set II 2676' In . te 10064' 9-5/8" 1415 cu ft Class 'G'. 130 cu ft Arctic Set I 10064' Production Liner 1424' 7" 438 cu ft Class 'G' 9792' -11216' 110' 2676' 8562' 8373' - 9359' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch \perfOration Depth TVD (ft): 8731' - 8875' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements Perforation Depth MD (ft): 10305' - 10510' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Peter Du Cane Title CT Drilling Engineer Date: Contact Peter Du Cane Signature &v C!¿)...~ Prepared By Name/Number: Phone 564-5238 Date Sondra Stewman, 564-4750 II..A Onh Permit Approval ¿ II ~l)L I See cover letter for Date: ' J ,,'Iv other requirements [] Yes ~ No Mud Log Required / 0 Yes ~ No 8 Yes [J No Directional Survey I equired ~ Yes 0 No pev C. O. SI¿,. 000. Permit To Drill I API Number: Number:2o<l-ð7} 150-029-20804-01-00 Conditions of Approval: Samples Required _ ¡Hildrogen Sulfide Measur~s Other: T.e~t- Bo¡ft-] +0 35'00 ps,.I J Anomvedill/~ \ Form 1 0-4~evised 12/2003 --- n D I ~ I f\1 ^ I V , , I V I I ,. r", L. BY ORDER OF THE COMMISSION Date5¡ijðtf ISubfnit In buplicate . . BP Prudhoe Bay S-14A CTD Sidetrack Summary of Operations Well S-14 is scheduled for a through tubing sidetrack with coiled tubing drilling rig Nordic 1. The sidetrack, S-14A (injection well), will kick off from a window milled off a mechanical whipstock set above the existing perforations in the 7" liner. Zone 4B will be the target for this sidetrack. The existing perforations in S-14 will be abandoned by downsqeezing cement past the whipstock. Pre Rig Prep Work i) Complete mechanical integrity test of inner and outer annulus. ii) Pressure test wellhead and tubing packoffs. iii) Run mechanical whipstock through tubing into the 7" liner and set above existing perforations at 10305' MD. iv) Downsqueeze cement past whipstock to plug and abandon existing perforations Nordic 1 CTD - Mill window, drill and complete sidetrack: v) Mill 3.8" window at 10305' MD, through the 7" liner. vi) Directionally drill 2220' of 3-3/4" to 4-118" hole to a planned TD of 12525' MD, 8798' TVD. iÝ- vii) Run 3-3/16" x 2-7/8" liner from TD up to 9785' MD, pump 2..7bl cement from TD to 10100' MD. . . viii) Shoot 100' of perforations. viii) Rig down Nordic 1. Mud Program 8.7 ppg Flo-Pro Disposal All drilling and completion fluids and all other Class II wastes will go to grind and inject or to Pad 3. All Class I wastes will go to Pad 3 for disposal. Casing Program 715' of3-3/16" TCIl 6.4# L-80 from 10500' MD (8790' TVD) up into the 4-W' tubing to 9785' MD. 2025' of 2-7/8" STL 6.5# L-80 from TD up to 10500' MD. Cement from TD into 7" liner to 10100' MD with 22.7 bbl, 15.8 ppg cement slurry. . . Casing Burst rating Collapse rating Hole size psi psi in 13-3/8' 72# L-80 5380 2670 9-5/8" 47# L-80 6870 4750 7" 26# L-80 7240 5410 3-3/16" 4.5# L-80 4-1/8" 2-7/8" 4.6# L-80 2- 7/8" Well Control 7-1/16" BOP diagrams are attached. Directional See attached directional plan. New hole consists ofa build section of245' length, a -93 degree tangent section of 1000' length, a drop section of length 200' and a -84 degree tangent section of775' length. Max planned hole angle is -94.3 degrees. Magnetic and inclination surveys will be taken every 30 ft. The nearest offset well is M-14 at 926' away center to center at 12436' MD. The nearest property line is 10100' away from the well TD. Logging MWD gamma ray and resistivity will be run over the open hole section for geosteering purposes. Hazards Two faults are prognosed to be crossed by the well path. Contingencies for dealing with 100% losses are to be made. The most recent H2S reading was 20 ppm taken at S-12A on Mar 16th 2003. The greatest H2S reading was 70 ppm taken at S-05A (closest bottom hole location to S-14A) on Feb 4th 2003. Reservoir Pressure The estimated pore pressure at 8867' TVD is 3550 psi (7.7 ppg equivalent mud weight). Maximum surface pressure with gas (0.1 psi/ft) to surface is 2663 psi. mEE= , 6" McEVOY . r=Æ NOTES I WELLHEAD = 13-3/8" McEVOY 5-14 ACTUATOR - OTIS KS. ELEV = 67.77' SF. ELEV = 39.07' KOP= 3200' 2093' H 5-1/2" DSE SSSV LAND. NIP, ID = 4.562" I Max Angle = 47 @ 9500' . Datum MD = 10500' Datum TVD = 8800'SS ~ = --I 2591' H 9-5/8" DV PKR I GAS LIFT MANDRELS 113-3/8" CSG, 72#, L-80, ID = 12.347" I µ ~ ST MD TVD DEV lYÆ VLV LATCH PORT DATE 2676' 13 3100 3031 9 OTIS LSD DV RA 09/16/82 12 4921 4620 38 OTIS LSD DV RA 09/16/82 11 6337 5734 37 OTIS LSD DV RA 09/16/82 Minimum ID = 3.725" @ 9815' L 10 7081 6338 37 OTIS LSD DV RA 09/16/82 OTIS XN NIPPLE 9 7237 6462 37 OTIS LSD DV RA 09/16/82 8 7726 6842 42 OTIS LSD DV RA 09/16/82 7 7871 6948 44 OTIS LSD DV RA 09/16/82 6 8237 7213 44 OTIS LSD DV RA 09/16/82 5 8392 4325 43 OTIS LSD DV RA 09/16/82 4 8754 7587 45 OTIS LSD DV RA 09/16/82 3 8911 7699 45 OTIS LSD DV RA 09/16/82 2 9401 8043 48 OTIS LSD DV RA 09/16/82 1 9557 8148 48 OTIS LSD DV RA 09/16/82 I I , 9630' H5-1/2" OTIS XA SLIDING SLEEVE, ID = 4.562" I í I r 9699' 1-i2o' SAKER SSR TBG SEAL ASSY I 9 I.--. I 9719' H 9-5/8" SAKER PKR, ID = 4.00" I ¡.::::::, 5-1/2" TBG, 17#, L-80 IPC, 0.0232 bpf, ID = 4.892" 9719' Y .",/ - --r H5-1/2" x 4-112" XO I 9719' TOPOF 4-1/2" TBG I 9719' I 9774' H4-1/2" OTIS X NIP, ID = 3.813" I . TOPOF7" LNR I 9792' I I , 9815' 1-14-1/2" OTIS XN NIP, ID = 3.725" I . 14-112" TBG. 12.6#. L-80. 0.0152 bpf, ID = 3.958" I 9856' I 9856' H4-1/2'SAKERTBGTAIL,ID=3.958" I I 9-518" CSG. 47#, L-80. ID = 8.681" I 10064' -¡--...4 [ ~ I 9862' H ELMD IT LOG UNA V A ILASLE I ÆRFORA TION SUMMARY REF LOG: SHCS ON 09/05/82 10469' 1-iMARKERJOINT I ANGLE AT TOP ÆRF: 45 @ 10305' I Note: Refer to Production DS for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10305-10347 0 01/14/84 I 2-7/8" 4 10362-10436 0 01/14/84 2-7/8" 4 10451-10510 0 01/14/84 10510' HCEMENTCAP, ELMD I 2-7/8" 1 10510-10524 CMT CAP 07/10/94 2-7/8" 1 10524-10528 S 07/10/94 10524' HTOPOF SAND I 2-7/8" 1 10543-10637 S 07/10/94 2-7/8" 1 10652-10706 S 07/10/94 2-7/8" 2 10716-10722 S 07/10/94 2-7/8" 1-1/2 10737-10753 S 07/10/94 I PBTD 11177' I 17" LNR, 26#, L-80. 0.0383 bpf, ID = 6.276" I 11216' I DATE REVSY COMMENTS DATE REVSY COMMENTS PRUDHOE SAY UNIT 09/16/82 ORIGINAL COMA-EriON WELL: S-14 03/08/01 SIS-MH CONVERTED TO CANVAS PERMIT No: 182-1290 03/12/01 SIS-MD FINAL API No: 50-029-20804-00 11/28/01 RNlTP CORRECTIONS SEC 35. T12N. T12E BP Exploration (Alaska) PERFORA TION SUMMARY REF LOG: BHCS ON 09fOS1S2 A NGLE AT TOP PERF: 45 @ 1030S' Note' Refer to Production SIZE SPF 2-7f8" 4 2-7f8" 4 2-7/8" 4 2-718" 1 2-7f8" 1 2-7/8" 1 2-718" 1 2-7f8" 2 2-7/8" 1-112 10305-10347 10362-10436 10451-10510 10510-10524 10524-10528 10543-10637 1 0652-1 0706 10716-10722 10737-10753 CMT CAP S S S S S 071tO/94 07/10194 07110/94 7" LNR, 26#, L-80, 0.0383 bpf, 10 CONVERTED TO FINAL NOTES I I PRUDHOE SA Y UNIT WELL: PERMIT No: API 09/16182 ObP . . BP-GDB Baker Hughes INTEQ Planning Report Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB S Pad S-14 Plan#3 S-14A Field: Prudhoe Bay North Slope UNITED STATES Map System;US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB S Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: I<'rom: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: S-14 5980854.54 ft 617919.92 ft B.. B.ADII ..... I.NrEQ Date: 1/15/2004 Time: 13:45:59 Page: Cò-ordinate(NE) Reference: Well: S-14, Tru&North Vertical (TVD) Reference: Syst&m: Mean Sea Level SectlQn (VS) Reference: W&II (0.00N,0.00E,88.19Azi) Survey Calculatiòn Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Latitude: 70 21 Longitude: 149 2 North Reference: Grid Convergence: Slot Name: Well Position: +N/-S -1037.71 ft Northing: 5979855.00 ft Latitude: +E/-W 2411.25 ft Easting: 620347.00 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan#3 S-14A 500292080401 Current Datum: S-14 Rig Magnetic Data: 1/15/2004 Field Strength: 57569 nT Vertical Section: Depth From (TVD) ft 30.23 Targets Name Description Dip. Dir. S-14A Polygon3.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 ·Polygon 6 -Polygon 7 -Polygon 8 S-14A Fault 1 -Polygon 1 -Polygon 2 S-14A Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8655.00 8680.00 8715.00 S-14A Fault 2 -Polygon 1 -Polygon 2 S-14A T3.3 S-14A T3.2 S-14A T3.1 Height 67.80 ft +N/-S ft 0.00 +N/-S ft 253.94 253.94 -253.83 42.08 57.04 ·13.70 326.24 262.90 300.94 438.39 438.39 -96.88 593.79 593.79 408.27 417.95 765.91 417.95 408.27 417.95 417.95 54.92 197.16 177.20 70.24 +E/-W ft 4239.98 4239.98 4405.86 5162.78 5601.11 6580.18 6650.66 5923.48 5174.94 5397.19 5397.19 5344.58 4316.46 4316.46 5155.66 6047.00 6801.75 6047.00 5155.66 6047.00 6047.00 5982.16 5657.37 5156.95 4655.12 Alaska, Zone 4 Well Centre bggm2003 23.002 N 32.343 W True 0.90 deg 70 21 12.793 N 149 1 21.865 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Map Map Northing Easting ft ft 5980176.99 624582.00 5980176.99 624582.00 5979671.99 624756.00 5979979.99 625508.00 5980001.99 625946.00 5979946.99 626926.00 5980287.99 626991.00 5980212.99 626265.00 5980238.99 625516.00 5980379.99 625736.00 5980379.99 625736.00 5979843.99 625692.00 5980517.99 624653.00 5980517.99 624653.00 5980345.99 625495.00 5980369.99 626386.00 5980729.99 627135.00 5980369.99 626386.00 5980345.99 625495.00 5980369.99 626386.00 5980369.99 626386.00 5980005.99 626327.00 5980142.99 626000.00 5980114.99 625500.00 5979999.99 625000.00 S-14 10300.00 ft Mean Sea Level 25.25 deg 80.86 deg Direction deg 88.19 <~- Latitude --> Deg Min See 70 21 15.279 N 70 21 15.279 N 70 21 10.284 N 70 21 13.189 N 70 21 13.333 N 70 21 12.630 N 70 21 15.972 N 70 21 15.356 N 70 21 15.735 N 70 21 17.085 N 70 21 17.085 N 70 21 11.821 N 70 21 18.621 N 70 21 18.621 N 70 21 16.791 N 70 21 16.879 N 70 21 20.295 N 70 21 16.879 N 70 21 16.791 N 70 21 16.879 N 70 21 16.879 N 70 21 13.310 N 70 21 14.711 N 70 21 14.518 N 70 21 13.469 N 148 59 17.929 W 148 59 17.929 W 148 59 13.089 W 148 58 50.960 W 148 5838.147 W 148 58 9.531 W 148 58 7.463 W 148 58 28.720 W 148 58 50.599 W 148 5844.100 W 148 5844.100 W 148 58 45.649 W 148 59 15.688 W 148 59 15.688 W 148 5851.160 W 148 5825.106 W 148 58 3.034 W 148 5825.106 W 148 5851.160 W <-- Longitude --> Deg . Min Sec 148 58 25.106 W 148 5825.106 W 148 58 27.009 W 148 58 36.500 W 1485851.127W 148 59 5.798 W ObP . . BP-GDB Baker Hughes INTEQ Planning Report Company: Field: Site: Well: Wellpath: Targets BP Amoco Prudhoe Bay PB S Pad S-14 Plan#3 S-14A Date: 1/1512004 Time: 13:45:59 Page: 2 Co-ordinate(NE) Reference: Well: S-14. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E.88.19Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Map <--- Latitude. --> <.- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft S-14A T3.4 8730.00 205.59 6502.69 5980164.99 626845.00 70 21 14.787 N Annotation MD TVD ft ft 10300.00 8659.77 TIP 10305.00 8663.31 KOP 10325.00 8677.24 3 10453.82 8723.85 4 10553.82 8720.91 5 10653.82 8715.25 6 10903.82 8698.61 7 11053.82 8688.04 8 11303.82 8672.43 9 11503.82 8660.58 10 11653.82 8655.74 11 11753.82 8659.95 12 12003.82 8683.07 13 12253.82 8706.75 14 12525.00 8730.38 TD Plan: Plan #3 Date Composed: 1/15/2004 Identical to Lamar's Plan #3 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +N/-S +E/·W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1000 deg/1000 deg/1000 deg 10300.00 45.00 95.00 8659.77 -69.77 4373.81 0.00 0.00 0.00 0.00 10305.00 45.00 95.00 8663.31 -70.08 4377.33 0.00 0.00 0.00 0.00 10325.00 46.69 94.15 8677.24 -71.22 4391.63 9.00 8.47 -4.23 340.00 10453.82 90.00 80.14 8723.85 -63.17 4507.90 35.00 33.62 -10.88 340.00 10553.82 93.27 45.27 8720.91 -18.06 4595.36 35.00 3.27 -34.87 275.70 10653.82 93.19 57.29 8715.25 44.28 4673.11 12.00 -0.07 12.02 90.00 10903.82 94.27 87.34 8698.61 119.24 4908.04 12.00 0.43 12.02 87.00 11053.82 93.75 69.30 8688.04 149.42 5053.96 12.00 -0.35 -12.02 269.00 11303.82 93.25 99.35 8672.43 173.79 5299.41 12.00 -0.20 12.02 90.00 11503.82 93.45 75.31 8660.58 183.01 5497.39 12.00 0.10 -12.02 271.20 11653.82 90.21 93.03 8655.74 198.16 5645.92 12.00 -2.16 11.81 100.00 11753.82 84.98 103.84 8659.95 183.55 5744.57 12.00 -5.23 10.81 116.00 12003.82 84.65 73.72 8683.07 188.77 5990.59 12.00 -0.13 -12.05 268.00 12253.82 84.72 103.85 8706.75 194.00 6236.55 12.00 0.03 12.05 91.30 12525.00 85.55 71.20 8730.38 205.56 6502.80 12.00 0.31 -12.04 270.00 II.. ...... IN'f EQ ObP . BP-GDB . IG.. BAKaR IUGHIS Baker Hughes INTEQ Planning Report ,_._""""",,,.,'..,,.,,;,..,",,,,.;,,..,.,,,, INfEQ Company: BP Amoco Date: 1/15/2004 Time: 13:45:59 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 8-14, True North Site: PB S Pad Vertical (TVD) Reference: System: Mean Sea Level Well: S-14 Section (VS) Reference: Well (0.00N,0.00E,88.19Azi) Wellpath: Plan#3 S-14A Survey Calculation Methød: Minimum Curvature Db: Oracle Survey MD Incl Azim Sys TVD N/S E/W MapN MapE VS DLS TFO ft dèg deg ft ft ft ft ft ft deg/100ft deg 10300.00 45.00 95.00 8659.77 -69.77 4373.81 5979855.50 624721.00 4369.42 0.00 0.00 10305.00 45.00 95.00 8663.31 -70.08 4377.33 5979855.24 624724.52 4372.93 0.00 0.00 10325.00 46.69 94.15 8677.24 -71.22 4391.63 5979854.33 624738.84 4387.19 9.00 340.00 10329.07 48.04 93.50 8680.00 -71.42 4394.62 5979854.18 624741.83 4390.17 35.00 340.00 10350.00 54.98 90.51 8693.02 -71.97 4410.98 5979853.89 624758.20 4406.50 35.00 340.44 10375.00 63.35 87.55 8705.82 -71.59 4432.42 5979854.62 624779.63 4427.94 35.00 342.31 10398.87 71.40 85.10 8715.00 -70.16 4454.38 5979856.40 624801.56 4449.94 35.00 343.83 10400.00 71.78 84.99 8715.36 -70.07 4455.45 5979856.51 624802.63 4451.01 35.00 344.77 10425.00 80.23 82.67 8721.40 -67.46 4479.55 5979859.51 624826.68 4475.18 35.00 344.81 10450.00 88.71 80.47 8723.81 -63.81 4504.14 5979863.55 624851.20 4499.87 35.00 345.37 10453.82 90.00 80.14 8723.85 -63.17 4507.90 5979864.25 624854.96 4503.65 35.00 345.58 4 10475.00 90.73 72.76 8723.71 -58.21 4528.48 5979869.54 624875.45 4524.38 35.00 275.70 MWD 10500.00 91.58 64.05 8723.21 -49.02 4551.69 5979879.10 624898.51 4547.87 35.00 275.65 MWD 10525.00 92.40 55.33 8722.34 -36.42 4573.24 5979892.04 624919.86 4569.81 35.00 275.48 MWD 10550.00 93.16 46.60 8721.12 -20.71 4592.62 5979908.06 624938.98 4589.67 35.00 275.17 MWD 10553.82 93.27 45.27 8720.91 -18.06 4595.36 5979910.76 624941.67 4592.50 35.00 274.75 5 10575.00 93.26 47.82 8719.70 -3.51 4610.71 5979925.54 624956.79 4608.30 12.00 90.00 MWD 10600.00 93.25 50.82 8718.28 12.75 4629.64 5979942.11 624975.45 4627.73 12.00 90.14 MWD 10625.00 93.23 53.83 8716.87 28.01 4649.39 5979957.68 624994.95 4647.95 12.00 90.32 MWD 10650.00 93.20 56.83 8715.47 42.21 4669.92 5979972.20 625015.25 4668.92 12.00 90.49 MWD 10653.82 93.19 57.29 8715.25 44.28 4673.11 5979974.33 625018.41 4672.18 12.00 90.65 6 10675.00 93.32 59.83 8714.05 55.31 4691.16 5979985.65 625036.27 4690.56 12.00 87.00 MWD 10700.00 93.47 62.83 8712.57 67.28 4713.05 5979997.97 625057.97 4712.82 12.00 87.14 MWD 10725.00 93.60 65.84 8711.02 78.08 4735.54 5980009.13 625080.28 4735.64 12.00 87.32 MWD 10750.00 93.73 68.84 8709.43 87.70 4758.56 5980019.11 625103.14 4758.95 12.00 87.51 MWD 10775.00 93.85 71.84 8707.77 96.09 4782.05 5980027.88 625126.49 4782.70 12.00 87.70 MWD 10800.00 93.95 74.85 8706.07 103.23 4805.94 5980035.40 625150.26 4806.80 12.00 87.90 MWD 10825.00 94.04 77.86 8704.33 109.12 4830.17 5980041.68 625174.39 4831.21 12.00 88.10 MWD 10850.00 94.13 80.86 8702.55 113.72 4854.68 5980046.67 625198.82 4855.85 12.00 88.31 MWD 10875.00 94.20 83.87 8700.74 117.03 4879.39 5980050.38 625223.47 4880.65 12.00 88.53 MWD 10900.00 94.26 86.88 8698.89 119.04 4904.24 5980052.79 625248.28 4905.55 12.00 88.74 MWD 10903.82 94.27 87.34 8698.61 119.24 4908.04 5980053.04 625252.08 4909.36 12.00 88.97 7 10925.00 94.22 84.79 8697.04 120.69 4929.11 5980054.83 625273.12 4930.46 12.00 269.00 MWD 10950.00 94.15 81.78 8695.22 123.60 4953.87 5980058.15 625297.83 4955.30 12.00 268.81 MWD 10975.00 94.07 78.77 8693.42 127.81 4978.44 5980062.75 625322.33 4980.00 12.00 268.59 MWD 11000.00 93.98 75.77 8691.67 133.31 5002.77 5980068.64 625346.56 5004.48 12.00 268.38 MWD 11025.00 93.88 72.76 8689.96 140.07 5026.77 5980075.78 625370.45 5028.69 12.00 268.17 MWD 11050.00 93.77 69.76 8688.29 148.08 5050.39 5980084.17 625393.94 5052.55 12.00 267.96 MWD 11053.82 93.75 69.30 8688.04 149.42 5053.96 5980085.56 625397.49 5056.16 12.00 267.76 8 11075.00 93.74 71.85 8686.66 156.45 5073.89 5980092.91 625417.30 5076.30 12.00 90.00 MWD 11100.00 93.73 74.85 8685.03 163.59 5097.79 5980100.44 625441.08 5100.41 12.00 90.17 MWD 11125.00 93.71 77.86 8683.40 169.48 5122.03 5980106.71 625465.22 5124.83 12.00 90.36 MWD 11150.00 93.67 80.86 8681.80 174.08 5146.55 5980111.71 625489.66 5149.48 12.00 90.56 MWD 11175.00 93.63 83.87 8680.20 177.40 5171.27 5980115.42 625514.32 5174.29 12.00 90.75 MWD 11200.00 93.57 86.88 8678.63 179.41 5196.14 5980117.83 625539.15 5199.21 12.00 90.94 MWD 11225.00 93.51 89.88 8677.09 180.12 5221.08 5980118.94 625564.08 5224.16 12.00 91.13 MWD 11250.00 93.44 92.89 8675.57 179.51 5246.02 5980118.74 625589.02 5249.07 12.00 91.32 MWD 11275.00 93.35 95.89 8674.09 177.60 5270.90 5980117.23 625613.93 5273.88 12.00 91.50 MWD 11300.00 93.26 98.89 8672.65 174.39 5295.65 5980114.42 625638.72 5298.52 12.00 91.68 MWD 11303.82 93.25 99.35 8672.43 173.79 5299.41 5980113.87 625642.50 5302.26 12.00 91.85 9 11325.00 93.30 96.81 8671.23 170.82 5320.35 5980111.24 625663.48 5323.09 12.00 271.20 MWD 11350.00 93.35 93.80 8669.78 168.51 5345.20 5980109.33 625688.36 5347.85 12.00 271.05 MWD 11375.00 93.39 90.80 8668.31 167.51 5370.13 5980108.73 625713.30 5372.74 12.00 270.88 MWD ObP . BP-GDB . BiI. BAICD ..... Baker Hughes INTEQ Planning Report IN'fEQ Company: BP Amoco Date: 1/15/2004 Time: 13:45:59 Page: 4 Field: Prudhoe Bay Co..ordlnate(NE) Reference: Well: S-14, True North Site: PB S Pad Vertical (rVD) Reference: System: Mean SeaLevel Well: S-14 Section (VS) Reference: VVell(0.00N,0.00E,88.19Azi) Wellpath: Plan#3 S-14A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim Sys TVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 OOft deg - ~--- 11400.00 93.42 87.79 8666.82 167.82 5395.08 5980109.44 625738.24 5397.69 12.00 270.70 MWD 11425.00 93.44 84.79 8665.33 169.43 5419.98 5980111.45 625763.11 5422.63 12.00 270.53 MWD 11450.00 93.46 81.78 8663.82 172.35 5444.76 5980114.77 625787.84 5447.49 12.00 270.35 MWD 11475.00 93.46 78.78 8662.32 176.56 5469.36 5980119.37 625812.36 5472.20 12.00 270.17 MWD 11500.00 93.45 75.77 8660.81 182.06 5493.70 5980125.26 625836.60 5496.70 12.00 269.98 MWD 11503.82 93.45 75.31 8660.58 183.01 5497.39 5980126.27 625840.28 5500.42 12.00 269.80 10 11525.00 93.01 77.82 8659.38 187.92 5517.95 5980131.51 625860.76 5521.14 12.00 100.00 MWD 11550.00 92.48 80.77 8658.19 192.56 5542.49 5980136.55 625885.22 5545.80 12.00 100.14 MWD 11575.00 91.94 83.73 8657.23 195.93 5567.24 5980140.31 625909.91 5570.65 12.00 100.28 MWD 11600.00 91.39 86.68 8656.50 198.02 5592.14 5980142.80 625934.77 5595.60 12.00 1 00.40 MWD 11625.00 90.85 89.63 8656.01 198.83 5617.12 5980144.01 625959.73 5620.59 12.00 1 00.48 MWD 11650.00 90.30 92.58 8655.76 198.34 5642.11 5980143.93 625984.72 5645.56 12.00 100.54 MWD 11653.82 90.21 93.03 8655.74 198.16 5645.92 5980143.80 625988.54 5649.36 12.00 100.57 11 11675.00 89.10 95.31 8655.87 196.62 5667.04 5980142.60 626009.68 5670.43 12.00 116.00 MWD 11700.00 87.79 98.01 8656.55 193.72 5691.86 5980140.10 626034.54 5695.14 12.00 115.99 MWD 11725.00 86.48 100.72 8657.80 189.66 5716.50 5980136.43 626059.24 5719.64 12.00 115.91 MWD 11750.00 85.18 103.43 8659.62 184.44 5740.88 5980131.61 626083.69 5743.84 12.00 115.78 MWD 11753.82 84.98 103.84 8659.95 183.55 5744.57 5980130.78 626087.40 5747.50 12.00 115.58 12 11775.00 84.90 101.29 8661.82 178.96 5765.17 5980126.52 626108.07 5767.94 12.00 268.00 MWD 11800.00 84.81 98.28 8664.06 174.73 5789.70 5980122.68 626132.66 5792.33 12.00 268.23 MWD 11825.00 84.74 95.27 8666.34 171.79 5814.42 5980120.14 626157.42 5816.94 12.00 268.50 MWD 11850.00 84.68 92.26 8668.65 170.16 5839.26 5980118.91 626182.28 5841.72 12.00 268.77 MWD 11875.00 84.64 89.24 8670.97 169.83 5864.14 5980118.98 626207.17 5866.58 12.00 269.05 MWD 11900.00 84.61 86.23 8673.32 170.81 5889.01 5980120.37 626232.02 5891.47 12.00 269.33 MWD 11925.00 84.60 83.22 8675.67 173.10 5913.79 5980123.05 626256.75 5916.31 12.00 269.61 MWD 11950.00 84.60 80.20 8678.02 176.69 5938.42 5980127.04 626281.32 5941.04 12.00 269.89 MWD 11975.00 84.62 77.19 8680.37 181.57 5962.82 5980132.30 626305.64 5965.58 12.00 270.18 MWD 12000.00 84.65 74.18 8682.71 187.72 5986.94 5980138.85 626329.65 5989.88 12.00 270.46 MWD 12003.82 84.65 73.72 8683.07 188.77 5990.59 5980139.95 626333.28 5993.56 12.00 270.74 13 12025.00 84.60 76.27 8685.05 194.23 6010.96 5980145.74 626353.56 6014.09 12.00 91.30 MWD 12050.00 84.55 79.28 8687.41 199.50 6035.28 5980151.40 626377.79 6038.57 12.00 91.06 MWD 12075.00 84.52 82.30 8689.79 203.49 6059.84 5980155.78 626402.28 6063.24 12.00 90.78 MWD 12100.00 84.50 85.31 8692.18 206.17 6084.58 5980158.86 626426.97 6088.05 12.00 90.49 MWD 12125.00 84.50 88.32 8694.58 207.55 6109.42 5980160.64 626451.79 6112.93 12.00 90.20 MWD 12150.00 84.51 91.34 8696.98 207.63 6134.30 5980161.11 626476.66 6137.80 12.00 89.91 MWD 12175.00 84.54 94.35 8699.36 206.39 6159.16 5980160.28 626501.53 6162.60 12.00 89.62 MWD 12200.00 84.58 97.36 8701.73 203.85 6183.91 5980158.14 626526.32 6187.26 12.00 89.34 MWD 12225.00 84.64 100.38 8704.08 200.02 6208.50 5980154.70 626550.97 6211.72 12.00 89.05 MWD 12250.00 84.71 103.39 8706.40 194.89 6232.85 5980149.96 626575.40 6235.90 12.00 88.77 MWD 12253.82 84.72 103.85 8706.75 194.00 6236.55 5980149.13 626579.11 6239.57 12.00 88.49 14 12275.00 84.73 101.30 8708.70 189.41 6257.13 5980144.87 626599.76 6259.99 12.00 270.00 MWD 12300.00 84.75 98.28 8711.00 185.17 6281.66 5980141.03 626624.35 6284.38 12.00 270.23 MWD 12325.00 84.78 95.27 8713.28 182.24 6306.38 5980138.49 626649.11 6308.99 12.00 270.51 MWD 12350.00 84.83 92.26 8715.54 180.60 6331.22 5980137.26 626673.98 6333.77 12.00 270.79 MWD 12375.00 84.89 89.25 8717.78 180.27 6356.12 5980137.33 626698.87 6358.64 12.00 271.06 MWD 12400.00 84.97 86.24 8719.99 181.25 6381.00 5980138.71 626723.73 6383.54 12.00 271.33 MWD 12425.00 85.06 83.23 8722.16 183.54 6405.79 5980141.39 626748.49 6408.40 12.00 271.59 MWD 12450.00 85.16 80.22 8724.30 187.13 6430.44 5980145.37 626773.07 6433.14 12.00 271.86 MWD 12475.00 85.28 77.21 8726.38 192.00 6454.87 5980150.64 626797.41 6457.71 12.00 272.11 MWD 12500.00 85.41 74.20 8728.41 198.15 6479.01 5980157.18 626821.45 6482.04 12.00 272.36 MWD 12525.00 85.55 71.20 8730.38 205.56 6502.80 5980164.97 626845.12 6506.05 12.00 272.61 TD POINÞ"tWGlUpatb: Tie 011 MO: Rig: R,,'.O.atum: BP Amoco WELLPATH OETAILS PlaQ#3 S-14A 5fJfJ29WS0461 ..,. 10300.00 S_14 Rig 61.$Oft V.S'I'<:tiOIl Origtn Origl" Angl.. +WI-iS +eJ.W Stariitlg :rom'tVD REFERENCE INFORMATION ~~^~~,.._------~--~-._-~--~.~_..~ 1 103m-Mil) 45.00 g5.GU ~ H¡-305,OO:¡: ÐMO : :~~~ t,',,~ ¡. :,:1:,."',',-- Ii &3,2$ ,:,:"'.,i;, ~~ ~:~ &:un U &4,$& 10:UI,4 13 84,$5 73.72 14 84.72 'JO~.85 U &5.55 71.20 ANNOTATiONS TV. "0 kmotatloti SSSe;1! TI. 3&s~.31 KO' 8671,24- · 81Z-3j\S · 4720,&1 · &nS,2:S · IU98.1U 7 1i\6$8J)4 · 8-61-243 · IUU10.U ,. S&5S.74 11 86-59JfS " S633.01 " 15" 87.116:.15 1. 8130.U '0 7600 7700 7800 7900 'æ' .- 8000 i 08100 '!I" ..... 0 8300 Q 'i 8400 U 1: 8500 CD :::> 8600 CD 2 8700 ... 8800 SSCT!ONDETAlLS nt-OIg Ti';U>jI V$~" Y",rg.,t IiGS9.Tl ;g:~ 1172€i.&'J :~¡¡~ M$ð.!)4 :ãE:~ 865$.74 86.59.95 ~it~ -69.77 ·nu¡-s ·71.2'2 -$3.11 -1S.OO 44.211 1111-,24 1-MH!¡¡: 17:a.,î'g 18a.b1 ~:~:~~ l~ii 4373.3.1 121371.:33 mj:g~ 4555-36 4673,.11 490a.M -50.$3-'$6 529&.41 ~~::; 5144.57 5900.59 6236.55 $502'.80 ;0.00 ;Q.UI) 0,00 (UfO jU,,, 3411-06 35.00 340.06 35,00 U",70 12.00 $.1,00 1a,.OO S7-(JO 12.00 ;W$.UI) 1:1.00 $Q.OO ~tgg iò~:~ 12.00 116..00 12.00 ~6tt.OO 12.00 91,30 '12.-00 270.00 436-9'.42 :;~¡:~~ 4W3,ij.5 451it2'.50 4672.U Mii.U!.35 :!5:ii -!S649~ 5741',50- iæ:!~ T LEGEND Pian #3 (S-14iPlan#3 S-14Aì 8900 9000 9100 Created By- Brij Potnìs Date 1/15/2004 1000 900 800 700 600 ;- :i' 200 1:: 0100 Z - - ..:.. 0 .c: .. :::HOO o fI) -200 -300 -400 -500 -600 -700 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 West(-)/East(+) [100ft/in] 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6800 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 Vertical Section at 88.19· [100ft/in] 1/15/2004 1:43PM 1 . . Winton, As per your request, the following is a list of offsets within -1/4 mile (on plan) of the perforated interval of proposed injection well 8-14A: 8-14 (mother wellbore) M-16 M-14 8-12 Regards, Peter Peter Du Cane Coiled Tubing Drilling Engineer BP Exploration Alaska 900 East Benson Boulevard Anchorage 99508 Alaska +1 (907) 564 5238 Office +1 (907) 632 5659 Mobile ducap1@bp.com . . SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 1 01 "Mastercard Check" DATEO~ "7.'I-oi_ 6~~JRO JFHE ,~c..c _> I $ [D.). (~--. CJ"Y) e ~~.-\V\Å. Î~ G-M ~-S" DOLLARS First National Bank Alaska ::~fu ~O~~~A J-- ~ <Ç)\-'\.,w,t'();1)eYYYUb Çe~ I: ~ 2 5 2000~OI:~~ ~l.II'¡; 2 2 711' ~ S¡;l.II- 0 ~O ~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ßC1 S--/YA PTD# 2o~ -0 7/ Development X Service Exploration Stratigraphic CHECK WBA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) M1JLTI Tbe permit is for a new weUbore segment of LATERAL existing well . Permit No, .. API No. . (If API Dumber Production.sbould continue to be reported as last two (2) digits a function' of tbe original API number. stated are betweeD 6.0-69) above. PILOT BOLE In accordance witb 26 AAC 2S.6.oS(i), aU (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated În botb Dame (name on permit plus PH) and API Dumber (56 - 76/86) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 2.0 AAC 25.05S~ Approval to peñorate and produce is contingeDt UpOD issuance of;! conservation order approving a spacing e:xceptioD. (Company Name) assumes tbe liability of any protest to tbe spacinge:xception tbat may occur. DRY DITCH An dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 3.0' sample intervals from below tbe permafrost or from wbere samples are first caught and 1.0' sample inter-valstbrougb target zones. . . o o Well bore seg Annular Disposal PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: OE BAY UNIT S-14A Program SER ALASKA) INC Initial ClasslType SER/1~GeoArea Unit 11650 On/Off Shore On Administration Pel'l1']it fee attache.!:! ~ - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ Ye$__ - - - - - - - - - - - - - 2 _Lease number _appropripte_ _ _ - - - - - - - - - - - - - - - _ _ _ _ _ _Ye$_ - - - - - - - - - - - - - - - - - -- 3 _U_nlqueweltn_ame_and OL.!mb_er _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Ye$__ - - - - - - - - -- - - - . - - - - - - - - - - - -- 4 WeJUocated In_aßefjne.dpooL _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ - _. _ _ _ _ _ _ No - - - - - - - - - -- 5 WeJUocpted pr_oper _dlstance_ from driJling unitbound_ary_ _ _ _ _. Ye$__ - - - - - - - - - - - - 6 WellJocated proper _dlstance from otber wells_ _ _ _ - - - - - - - - - - - Xe$_ _ 7 _S_utfjcientacrea9-e_aYailpble in_driUi09-unjt _ _ _ _ _ _ _ _ _ _ _ _ _ Ye$_ - - - - - - - - - - - - - - - 8 Jtdeviated, js_ weJlbore plaUncJu_ded _ - - - - -- _ _ _ _ Ye$_ - - - - - - - - - - - - - - - -- 9 Ope(ator only affected party _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye$. - - - - - - - - - -- 10 _Oper_ator bas_appropriateJ).ond lnJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_e$ __ - - - - - - - - - - - - - - - - - - - - - - - - - -- 11 Permit c.an be lS$L.!ed wjtbout con$erva_tion order. _ _ _ . _ _ _ _ Ye$ - - - - - - - - - - - - - - - Appr Date 12 Permit C<!n be lS$L.!ed witbout admini$t(atilleapprova.1 _ _ _ _ _ _ _ _ _ _. Ye$__ - - - - - - - - - - - - - - - - -- RPC 4/29/2004 13 Can permit be approved before 15-day wait Yes 14 WelUocpted wlthin area and_stratpauthorlzed by_lnjectioo Order # (putlO# in. comments) (For_Ye$ . _ aio22 _ - - - - - - - - - - - -- 15 _AJI welJs_ wit.htn Jl43lJile _area_of reyiew ideotlfied (FO( &eNjc_e -,,'~ell onlYL _ _ _ _ _ _ _ _ _ _ _ _ Y_e$ __ S-OM,$-JO!LSct2, R-20JLM-16, M:-t4, M:2~,- _ _ _ 16 Pre-produced injector; .durption_of pre-pro.duction te$& than 3 months (for_servtce well onJy) _NA __ - - - - - - 17 ACMPJ=indjng _of ConsiJ;tencyha$ bee_nj&sueMorJbis pr_oject _ _ . _ _ .NA. - - - - - - - - - - - - - - - - - - - - -- Engineering 18 _C_onduj;lor $tringprovided _ . . - - - - - - - - - - - - - - - - NA _. - - - - - - - - - - - - -- 19 _S_urface_ca&ingprotec.t& alLknown USDW$ . _ _ _ - - - - - - .NA _ - - - - - - - - - - - - - - - - - ~ - 20 _CMT v_ol adeQuateJo circ.utateon _conductor_ & sur{CJ>g _ _ . . _ . _ . . _NA - - - - - - - - - - - - - - - - - - 21 _CMT vol adequateJo tie-tn Jong .string losurf Ç$g_ . . . _ . . . _ _ . . . NA. - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT will coyeraJl knownpro_ductiye bQrilons. . Ye$ - - - - -- 23 C.asing designs ad_eCluate for C.T" B&_Rermafmst Yes __ - - - - ~ - - - 24 _A.dequale_tan_kageor re_serve pit. . . - - - - - - - Yes. CTDU... _ _ _... _ _.... _ _.... __ 25 Jtue-.d(iIL bas. a_ 10-403 for abandonment beeo ppproved _ . Ye$. 4/29/20_04. ~ - - - - - ~ - - - - - - - - - - - - 26 A.dequalewellboreseparation_pro-PQ&ed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Rdiverter required, does it meel reguJations_ . . - - - - - - - - - NA __ Sidetrack. . - - - - - - - - - - - - - - - - - - - Appr Date 28 DriUiog fluid Rrogram $chematic_& equip Ji$tadequate. . . . _ . Yes_ _ Max MW_8~ 7. ppg._ - - - - - ~ - - - - - - - - - - - - WGA 5/5/2004 29 _BOPEs, do_they meetreguJa.tion _ _ _ _ . . _ _ _ . . . _ _ _ . Yes. - - - - - ~ - - - - - - - - - - -- 30 .BOPE-PJess rating appropriate; Jest loJpu_t psig tn_comments)_ . . _ _ _ Ye$ _. Testto_3500 psLMSf> 26_63 psi._ _ _ _ . . 31 Choke_manifold compJies_ w/API Rf>-53 (May B4L _ _ . _ _ _ . . . _ _ _ . Yes. - - - - -- - - - - - - - - - - - - - - - ~ - 32 Wo~ will occur withoutoperptionsbutdown ~ - - - - - - - - - - - ~ Yes. - - - - ~ ~ - - - - ~ - - - - - - - - - - - - 33 J& pre&ence of H2S gas. RroQable. _ _ . _ _ . _ _ _ _ . . . _ _ . . _ _ _ _ Ye$_ - - - - - - - - - ~ - - - - - ~ - - - - - - 34 MechanicaLcondjtlon of we.lI$ within ,t..OR Yerified (for_ s_ervice welJ onJy) Ye$. Cml records of pll AOR wells jndicple _mecb Integ (ity. Geology 35 Pel'l1']it c_an be lS$L.!ed w!o hydrogen sulfide measures No_ 36 D.ata_presented on pote.ntial overpre&sure _zoneJ; _ _ NA Appr Date 37 _Setsmlc_analysJs Qf sbaJlow gas_zooes _ NA RPC 5/5/2004 38 _Seabedconditioo SL.!rvey _(if off-&h_ore) _ . . _ _ _ . _NA 39 . Conta_ct namelp.hOlleJorweekly progress_reports [I NA - Geologic Date: Engineering Date Commissioner: Commissioner Dì-s S}6/i---- e e 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 infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . 201---0 7 ( $Revision: 3 $ LisLib $Revision: 4 $ Tue Nov 16 12:58:54 2004 t [d- cry] Reel Header Service name.. .......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name... ... . UNKNOWN Comments.......... ..... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .....UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA S -14A 500292080401 B. P. Exploration (Alaska) Inc Sperry-Sun Drilling Services 16-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003268702 B. JAHN B. HOLT / B. MWD RUN 3 MW0003268702 B. JAHN B. HOLT / B. MWD RUN 5 MW0003268702 B. JAHN B. HOLT / B. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0003268702 B. JAHN B. HOLT / B. MWD RUN 7 MW0003268702 B. JAHN B. LAULE / R MWD RUN 8 MW0003268702 B. JAHN B. LAULE / R # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 12N 12E 1651 2185 67.77 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE 4.125 4.125 . (IN) SIZE (IN) 7.000 DEPTH (FT) 10293.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10293'MD/ 8655'TVDSS IN THE S-14 WELLBORE. 4 . MWD RUN 1 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUN 2 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THIS RUN WAS A MAD PASS OVER THE MWD RUN 1 INTERVAL PRIOR TO A RIG-DOWN TO ALLOW ANOTHER RIG TO BE MOVED PAST S PAD. THESE MAD DATA WERE MERGED WITH MWD DATA FROM RUN 3 - NO SEPARATE MAD PASS IS PRESENTED. 6. MWD RUNS 3, 5 - 8 COMPRISED DIRECTIONAL; GM; AND EWR4. NO PROGRESS WAS MADE ON RUN 4 - THIS WAS WINDOW CLEANUP RUN. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A GAMMA RAY RUN IN S-14A ON 9/18/04. THESE DATA WERE PROVIDED TO SSDS BY KURT COONEY (SIS/BP) ON 10/18/04. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 8. MWD RUNS 1 - 3, 5 - 8 REPRESENT WELL S-14A WITH API#: 50-029-20804-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12658'MD/8768'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name. ........... .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.. .... .04/11/16 . Maximum Physical Record..65535 File Type........ ........LO Previous File Name.. .....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 10145.0 10290.5 10290.5 10290.5 10290.5 10290.5 10318.5 STOP DEPTH 12607.0 12621. 5 12621. 5 12621. 5 12621. 5 12621. 5 12652.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 10145.0 10154.0 10158.0 10163.0 10167.5 10172.5 10177.5 10180.0 10182.5 10191. 5 10194.0 10197.0 10206.0 10215.0 10225.5 10232.0 10236.5 10244.0 10249.5 10251. 5 10253.5 10272.0 10287.5 10294.5 10299.5 10303.0 10306.0 10309.5 10312.5 10314.0 10323.0 10325.5 10330.0 10333.5 10337.0 10346.5 10354.5 10359.5 10363.5 10370.0 10378.5 10389.0 GR 10152.0 10161.0 10164.5 10168.5 10173.0 10177.5 10182.5 10185.0 10187.5 10198.0 10200.5 10204.5 10213.0 10220.5 10229.5 10238.0 10241.5 10250.0 10253.5 10256.0 10258.0 10278.0 10286.5 10295.0 10299.5 10302.5 10304.5 10307.5 10311.5 10313.0 10321. 5 10325.5 10328.0 10331.5 10335.5 10344.5 10353.0 10358.0 10361.0 10368.5 10376.0 10388.0 . . 10394.0 10397.0 10408.0 10442.0 10444.5 10481. 0 10501. 5 10556.0 10567.5 10574.5 10588.5 10599.5 10628.0 10661. 0 10685.5 10700.0 10708.5 10710.5 10719.0 10727.0 10731.0 10737.5 10744.0 10796.0 10810.0 10845.5 10864.0 10873.0 10946.0 10984.5 10996.5 11032.5 11076.0 11088.0 11120.5 11140.0 11159.0 11174.5 11189.5 11238.0 11271.0 11338.0 11350.0 11377.5 11382.0 11393.0 11406.5 11412.0 11612.0 11633.0 11651. 5 11667.5 11686.5 11690.5 11705.0 11706.5 11895.0 11898.5 11912.0 11920.0 11934.0 11949.0 11959.0 11974.0 11997.5 12009.0 12022.5 12040.5 10392.0 10395.5 10407.5 10441.0 10443.5 10479.5 10499.0 10554.5 10563.0 10570.5 10591.0 10601. 0 10629.0 10660.5 10686.0 10703.5 10710.0 10712.0 10719.5 10727.0 10730.0 10735.0 10745.0 10795.0 10806.0 10840.5 10861.5 10872.0 10944.0 10986.5 10997.0 11030.5 11076.0 11090.0 11121. 0 11138.0 11157.0 11176.0 11188.5 11240.5 11271.5 11339.0 11350.5 11377.5 11381. 0 11392.0 11406.0 11413.0 11612.0 11632.0 11650.0 11667.0 11689.0 11693.0 11705.0 11707.5 11899.0 11902.5 11913 .0 11920.0 11938.5 11955.0 11966.0 11981.0 12004.5 12016.5 12028.5 12043.5 . . 12066.5 12114.5 12118.0 12150.0 12184.0 12201.0 12252.5 12274.0 12280.5 12287.0 12306.5 12317.5 12337.5 12340.5 12347.0 12355.0 12361.0 12365.5 12378.0 12386.0 12402.5 12416.5 12421. 0 12426.0 12435.5 12458.0 12467.0 12476.0 12484.5 12496.0 12506.5 12519.0 12527.5 12529.5 12652.5 $ 12068.0 12121. 0 12126.5 12158.5 12193.0 12207.5 12256.5 12279.0 12284.5 12291.5 12308.0 12319.5 12343.5 12346.0 12353.5 12358.5 12365.0 12369.5 12381.0 12390.5 12407.0 12420.0 12424.5 12431.0 12440.0 12462.5 12475.0 12482.5 12490.5 12503.0 12513.0 12524.5 12532.0 12534.5 12657.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ BIT RUN NO 1 3 5 6 7 8 MERGE TOP 10152.0 10570.0 11201.0 11565.0 12040.0 12283.0 MERGE BASE 10570.0 11201.0 11565.0 12040.0 12283.0 12657.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............. ... . Down Optical log depth units....... ....Feet Data Reference Point... ........ ...Undefined Frame Spacing... ....... .......... .60 .1IN Max frames per record.. ......... ..Undefined Absent value... ................. ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 . RPM RPD FET MWD MWD MWD OHMM OHMM HOUR 4 4 4 1 1 1 68 68 68 20 24 28 6 7 8 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10145 12652.5 11398.8 5016 10145 12652.5 ROP MWD FT/H 0.09 1627.73 77.7251 4669 10318.5 12652.5 GR MWD API 15.01 825.85 42.7703 4921 10145 12607 RPX MWD OHMM 0.22 2000 38.5736 4663 10290.5 12621.5 RPS MWD OHMM 0.13 2000 40.364 4663 10290.5 12621.5 RPM MWD OHMM 0.15 2000 36.8167 4663 10290.5 12621.5 RPD MWD OHMM 0.17 2000 91. 8357 4663 10290.5 12621. 5 FET MWD HOUR 0.19 23.13 3.26704 4663 10290.5 12621.5 First Reading For Entire File......... .10145 Last Reading For Entire File..... ..... .12652.5 File Trailer Service name...... ..... ..STSLIB.001 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation..... ..04/11/16 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name........ .....STSLIB.002 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation. .... ..04/11/16 Maximum Physical Record..65535 File Type........ ...... ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10152.0 10317.5 STOP DEPTH 10540.0 10570.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 10-SEP-04 Insite 7.75 Memory 10570.0 10317.0 10570.0 . HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ......... ..0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point...... ........Undefined Frame Spacing.......... ......... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 . 10293.0 10536.0 TOOL NUMBER TLG 011 4.125 10296.0 Flo Pro 8.40 60.0 9.5 21000 6.3 .000 .000 .000 .000 .0 133.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10152 10570 10361 837 10152 10570 ROP MWD010 FT/H 0.22 159.18 61.4877 506 10317.5 10570 GR MWD010 API 20.17 825.85 64.1914 772 10152 10540 First Reading For Entire File. ........ .10152 Last Reading For Entire File........ ...10570 File Trailer . Service name........... ..STSLIB.002 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation..... ..04/11/16 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name.......... ...STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/11/16 Maximum Physical Record..65535 File Type............. ...LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS RPX RPM RPD FET GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 10290.0 10290.0 10290.0 10290.0 10290.0 10540.5 10570.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): STOP DEPTH 11170.0 11170.0 11170.0 11170.0 11170.0 11157.0 11201.0 11-SEP-04 Insite 4.3 Memory 11201.0 10570.0 11201.0 92.1 98.8 RESIS. 4 TOOL NUMBER 78012 171170 4.125 10296.0 Flo Pro 8.70 65.0 . MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.1 21000 4.6 . .075 .038 .145 .100 65.0 135.3 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... .... ...........0 Data Specification Block Type.....O Logging Direction.. ........... ....Down Optical log depth units... ........Feet Data Reference Point... ......... ..Undefined Frame Spacing... .... ........... ...60 .1IN Max frames per record........... ..Undefined Absent value.. ................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10290 11201 10745.5 1823 10290 11201 ROP MWD030 FT/H 1. 77 250.52 102.721 1262 10570.5 11201 GR MWD030 API 17.34 114 . 14 29.7261 1234 10540.5 11157 RPX MWD030 OHMM 0.22 2000 16.9629 1761 10290 11170 RPS MWD030 OHMM 0.13 2000 25.7312 1761 10290 11170 RPM MWD030 OHMM 0.15 2000 24.2705 1761 10290 11170 RPD MWD030 OHMM 0.17 2000 28.1032 1761 10290 11170 FET MWD030 HOUR 0.19 23.17 4.44778 1761 10290 11170 First Reading For Entire File......... .10290 Last Reading For Entire File... ....... .11201 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation.... ...04/11/16 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name...... .... .STSLIB.004 . Physical EOF File Header Service name.... ....... ..STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation... ... .04/11/16 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPX FET RPD ROP $ 4 . header data for each bit run in separate files. 5 .5000 START DEPTH 11157.5 11170.5 11170.5 11170.5 11170.5 11170.5 11201.5 STOP DEPTH 11520.5 11533.5 11533.5 11533.5 11533.5 11533.5 11565.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 13 -SEP-04 Insite 4.3 Memory 11565.0 11201. 0 11565.0 87.8 96.4 TOOL NUMBER 78012 171170 4.125 10296.0 Flo Pro 8.50 60.0 9.6 21000 8.3 .080 .039 .100 65.0 141. 2 65.0 · MUD CAKE AT MT: .070 6. # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units. ........ ..Feet Data Reference Point............. .Undefined Frame Spacing... ....... ... ...... ..60 .1IN Max frames per record......... ....Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11157.5 11565 11361.3 816 11157.5 11565 ROP MWD050 FT/H 0.45 84.2 30.3216 728 11201.5 11565 GR MWD050 API 21. 44 169.02 38.0384 727 11157.5 11520.5 RPX MWD050 OHMM 7.46 32.59 14.6055 727 11170.5 11533.5 RPS MWD050 OHMM 8.96 45.33 17.7477 727 11170.5 11533.5 RPM MWD050 OHMM 8.02 61.63 20.3231 727 11170.5 11533.5 RPD MWD050 OHMM 12.71 64.89 24.3473 727 11170.5 11533.5 FET MWD050 HOUR 0.86 18.96 3.091 727 11170.5 11533.5 First Reading For Entire File........ ..11157.5 Last Reading For Entire File.......... .11565 File Trailer Service name.. ......... ..STSLIB.004 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation...... .04/11/16 Maximum Physical Record. .65535 File Type............ ....LO Next File Name...... ... ..STSLIB.005 Physical EOF File Header Service name... ........ ..STSLIB.005 . Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation..... ..04/11/16 Maximum Physical Record..65535 File Type............... .LO Previous File Name... ....STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 5 . header data for each bit run in separate files. 6 .5000 START DEPTH 11521.0 11534.0 11534.0 11534.0 11534.0 11534.0 11565.5 STOP DEPTH 11995.5 12008.5 12008.5 12008.5 12008.5 12008.5 12040.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 14-SEP-04 Insite 4.3 Memory 12040.0 11565.0 12040.0 82.2 93.3 TOOL NUMBER 78012 171170 3.750 10296.0 Flo Pro 8.70 65.0 8.9 23000 6.4 .080 .037 .100 .070 65.0 150.0 65.0 65.0 . . TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...... .........0 Data Specification Block Type.....O Logging Direction.. ......... ......Down Optical log depth units...........Feet Data Reference Point........ ......Undefined Frame Spacing..... ................60 .1IN Max frames per record.. ...........Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11521 12040 11780.5 1039 11521 12040 ROP MWD060 FT/H 0.38 509.8 86.1445 950 11565.5 12040 GR MWD060 API 20.53 383.8 59.7083 950 11521 11995.5 RPX MWD060 OHMM 3.09 2000 90.7493 950 11534 12008.5 RPS MWD060 OHMM 1. 91 2000 94.7341 950 11534 12008.5 RPM MWD060 OHMM 1. 72 2000 91. 9455 950 11534 12008.5 RPD MWD060 OHMM 1. 25 2000 274.781 950 11534 12008.5 FET MWD060 HOUR 0.26 9.4 1. 94531 950 11534 12008.5 First Reading For Entire File......... .11521 Last Reading For Entire File..... ..... .12040 File Trailer Service name...... ..... ..STSLIB.005 Service Sub Level Name... Version Number.. ..... ....1.0.0 Date of Generation..... ..04/11/16 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name... ........ ..STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/16 Maximum Physical Record. .65535 File Type........ ........LO Previous File Name..... ..STSLIB.005 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 6 . header data for each bit run in separate files. 7 .5000 START DEPTH 11996.0 12009.0 12009.0 12009.0 12009.0 12009.0 12040.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # STOP DEPTH 12238.5 12251.5 12251.5 12251.5 12251.5 12251.5 12283.0 RES IS. 4 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 15-SEP-04 Insite 4.3 Memory 12283.0 12040.0 12283.0 82.2 87.1 TOOL NUMBER 78012 171170 3.750 10296.0 Flo Pro 8.60 60.0 9.5 21000 8.4 .200 .093 .170 .150 65.0 147.1 65.0 65.0 . . Data Record Type... ........... ....0 Data Specification Block Type.....O Logging Direction.... ........ .....Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.......... ........... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11996 12283 12139.5 575 11996 12283 ROP MWD070 FT/H 0.09 1627.73 67.0526 486 12040.5 12283 GR MWD070 API 15.14 94.84 31.6469 486 11996 12238.5 RPX MWD070 OHMM 2.8 2000 86.8105 486 12009 12251.5 RPS MWD070 OHMM 2.39 2000 68.054 486 12009 12251.5 RPM MWD070 OHMM 2.35 1751.18 43.8401 486 12009 12251.5 RPD MWD070 OHMM 1. 92 2000 180.741 486 12009 12251.5 FET MWD070 HOUR 0.5 13.59 3.50866 486 12009 12251.5 First Reading For Entire File....... ...11996 Last Reading For Entire File.......... .12283 File Trailer Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/11/16 Maximum Physical Record..65535 File Type............. ...LO Next File Name..... ......STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation..... ..04/11/16 Maximum Physical Record..65535 File Type. ... ........... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 7 header data for each bit run in separate files. 8 .5000 . # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH 12239.0 12252.0 12252.0 12252.0 12252.0 12252.0 12283.5 STOP DEPTH 12612.0 12626.5 12626.5 12626.5 12626.5 12626.5 12657.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction...... ......... ..Down Optical log depth units...........Feet Data Reference Point... ........ ...Undefined Frame Spacing...... ......... ......60 .1IN Max frames per record....... ......Undefined . 16-SEP-04 Insite 4.3 Memory 12658.0 12283.0 12658.0 87.2 69.2 TOOL NUMBER 78012 171170 3.750 10296.0 Flo Pro 8.60 60.0 9.5 21000 8.4 .145 .063 .105 .125 65.0 159.0 65.0 65.0 . . Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 SGRB MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12239 12657.5 12448.3 838 12239 12657.5 ROP MWD080 FT/H 3.27 1498.73 89.3838 749 12283.5 12657.5 SGRB MWD080 API 15.01 70.7 29.8971 747 12239 12612 RPX MWD080 OHMM 4.09 837.55 13.071 7 750 12252 12626.5 RPS MWD080 OHMM 4.16 460.15 12.681 750 12252 12626.5 RPM MWD080 OHMM 4.45 62.5 12.6758 750 12252 12626.5 RPD MWD080 OHMM 5.26 1617.15 19.8881 750 12252 12626.5 FET MWD080 HOUR 0.26 13.69 1.86931 750 12252 12626.5 First Reading For Entire File......... .12239 Last Reading For Entire File.... ...... .12657.5 File Trailer Service name.......... ...STSLIB.007 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .04/11/16 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name...... .....STSLIB.008 Physical EOF Tape Trailer Service name......... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ........... .UNKNOWN Continuation Number..... .01 Next Tape Name..... ..... . UNKNOWN Comments... .... ........ ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name..... ...... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number......Ol Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF . . Physical EOF End Of LIS File