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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:24 Township:11N Range:14E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:13636 ft MD Lease No.:ADL 0028307 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface:10 3/4"O.D. Shoe@ 4651 Feet Csg Cut@ Feet Intermediate:7 5/8"O.D. Shoe@ 9560 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:5 1/2"O.D. Shoe@ 11967 Feet Csg Cut@ Feet Liner:2 3/8"O.D. Shoe@ 13634 Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 10680 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 9450 ft 5943 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2503 2329 2277 IA 5 4 5 OA 172 172 173 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: A wireline tag was peformed to find the top of cement. Cement colored sandy clay came back in the bailer. April 6, 2025 Bob Noble Well Bore Plug & Abandonment PBU 18-09B Hilcorp North Slope, LLC PTD 1980790, Sundry 324-408 none Test Data: P Casing Removal: Miles Shaw Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0406_Plug_Verification_PBU_18-09B_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 this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 18-09B Renew Suspension Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-079 50-029-21566-02-00 ADL 0028307 13636 Conductor Surface Intermediate Liner Liner 8694 80 4620 9531 2550 3041 11638 16" 10-3/4" 7-5/8" 5-1/2" 2-3/8" 8506 32 - 112 31 - 4651 29 - 9560 9417 - 11967 10593 - 13634 32 - 112 4011 29 - 7305 7198 - 8666 7975 - 8694 10520 , unknown 670 2090 4790 6280 11780 11638 1640 3580 6890 7740 11200 12030 - 13589 3-1/2" 9.2# L-80 30 - 106808678 - 8693 Structural 3-1/2" TIW HBBP , 9349 , 7147 No SSSV, (3-1/2" CA TRDP-2A locked out 9-29-98) Date: Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907) 564-4891 PRUDHOE BAY 4/30/2025 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 1:40 pm, Apr 24, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.04.17 12:57:51 - 08'00' Bo York (1248) 325-253 DSR 6/12/25 DSR-6/18/25 6/12/2030 JJL 4/28/25 SFD 4/24/2025 10-407 XX *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.20 13:12:29 -08'00'06/20/25 RBDMS JSB 062425 Hilcorp North Slope, LLC Bo York, PBE Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 04/11/2025 Commissioners – Jesse Chmielowski, Greg Wilson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Well 18-09B (PTD #198079) Application for Renewal of Existing Suspension (10-403) Dear Commissioner Chmielowski and Commissioner Wilson, An AOGCC witnessed suspended well inspection of Prudhoe well 18-09B was conducted on 07/31/2023 (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 renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Suspended Well Site Inspection form documenting the pressures and site condition. x Wellbore diagram illustrating the current configuration of the well. Prudhoe well 18-09B was suspended on 07/07/2014 and has future utility as a rig sidetrack candidate. The strata through which the well was drilled is neither abnormally geopressured nor depleted. The well is mechanically sound, with a lateral cement plug across the confining interval above the reservoir. Based on these conditions and the inspection on 07/31/2023, Prudhoe well 18-09B meets the provisions required in 20 AAC 25.110 (a)(1). 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) 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 18-09B is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 907-777-8345 or Oliver Sternicki at 907-564-4891. Sincerely, Bo York PBE Operations Manager Attachments Technical Justification 2023 Suspended Well Site Inspection Form Wellbore Schematic Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.04.16 10:49:28 - 08'00' Bo York (1248) Prudhoe Well 18-09B (PTD #198079) Technical Justification for Renewal of Suspended Status 04/11/2025 Well History and Status 18-09 was originally completed in 1986 and rig sidetracked in 1992 to 18-09A. 18-09A was then sidetracked in 1998 to 18-09B. A cretaceous leak was found in 1999 and a cement squeeze above the packer was performed. A CTD sidetrack was then planned in 2013-2014 under Sundry # 313-247. A CIBP was set in 2013 at 11638’ MD to abandon the perforations and the liner was cut in early 2014 at 11575’ CTM, but coil was unable to pull the top section of liner. The liner was cut again later that year at 11540’ MD, but coil was again unable to pull the cut liner. The well was suspended on 07/07/2014. On 3/31/2025 work was completed to place a cement plug across all annuli in the confining interval above the reservoir with coil tubing from 10322-10515’ MD. Tubing TOC was tagged at 5942’ MD. The well passed an MIT-IA on 9/29/2013 to 1884 psi and passed an MIT-T on 4/6/2025 to 2277 psi. 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, and 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. The well future utility is as a sidetrack candidate. Condition of the Wellhead and Surface Location Prudhoe well 18-09B 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. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. The well pressure readings are T/I/O = 131/ 2/ 173 psi. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for 18-09B. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 18-09B Reservoir Abandon Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-079 50-029-21566-02-00 ADL 0028307 13636 Conductor Surface Intermediate Liner Liner 8694 80 4620 9531 2550 3041 11638 16" 10-3/4" 7-5/8" 5-1/2" 2-3/8" 8506 32 - 112 31 - 4651 29 - 9560 9417 - 11967 10593 - 13634 2520 32 - 112 4011 29 - 7305 7198 - 8666 7975 - 8694 10520 , unknown 670 2090 4790 6280 11780 11638 1640 3580 6890 7740 11200 12030 - 13589 3-1/2" 9.2# L-80 30 - 106808678 - 8693 Structural 3-1/2" TIW HBBP No SSSV, (3-1/2" CA TRDP-2A locked out 9-29-98) 9349 7147 Date: Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907)564-4891 PRUDHOE BAY 2/1/2025 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 2:27 pm, Dec 18, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.12.18 12:30:32 - 09'00' Bo York (1248) 324-708 SFD 12/26/2024 SFD DSR DSR-12/20/24 X AOGCC Witnessed Tag TOC and MITT to 2250 psi. JJL 1/7/25 X &': &':IRU-/& 01/07/25Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.01.07 15:09:09 -09'00' RBDMS JSB 010925 Res AB Sundry Well: 18-09B PTD: 198079 API: 50-029-21566-02 Well Name:18-09B Permit to Drill Number:198079 Well Type SU API Number:50-029-21566-02-00 Job Scope:Res Abandon Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd: Estimated Start Date:2/1/2025 Estimated Duration:7days Regulatory Contact:Carrie Janowski First Call Engineer:Oliver Sternicki Second Call Engineer:David Bjork Current Bottom Hole Pressure:3400 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2520 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:450 psi Min ID:2.812” TRSV @ 2179’ MD Max Angle:62 deg @ 10570’ MD Top of Ivishak:10730’ MD Well History: 18-09 was originally completed in 1986. The well was rig sidetracked in 1992 to 18-09A. 18-09A was sidetracked in 1998 to 18-09B. A cretaceous leak was found in 1999 and a cement squeeze above the packer was performed. A CTD sidetrack was planned in 2013-2014 under Sundry # 313-247. A CIBP was set in 2013 at 11638’ MD to abandon the perforations and the liner was cut in early 2014 at 11575’ CTM, but coil was unable to pull the top section of liner. The liner was cut again later that year at 11540’ MD, but coil was again unable to pull the cut liner. The well was suspended on 07/07/2014. Subsequent slickline fishing attempts in 2018 resulted in a lost tool string on top of the liner and attempts to fish that tool string with coil tubing were unsuccessful on 4/25/2018. 18-09B is currently secured with a CIBP set in the 2-3/8” liner at 11638’ MD on 9/13/2013. A CBL logged in the 2-3/8” liner found TOC in the 2-3/8” x 5-1/2” annulus at 11608’ MD The well passed an MIT-IA on 9/29/2013 to 1884 psi and passed an MIT-T on 12/21/2013 to 2525 psi. The top of the Ivishak confining interval (THRZ) was logged on 11/15/2024 with a jewelry log tied into GLM #4 at 9274’ MD. THRZ was found at 10322’ MD and the top of fish was found at 10522’ MD. The calculated 5.5” liner cement top with 30% washout is well above the base of the 7.625” casing at 9560’ MD. Res AB Sundry Well: 18-09B PTD: 198079 API: 50-029-21566-02 Current Status: 18-09B is currently not operable and offline. Objectives: The intent of this program is to place a lateral cement plug from 10322’- 10510’ MD, across the confining interval above the Ivishak and cement the tubing up to ~5700’ MD to allow the well to be considered for suspension renewal. A variance to the plugging requirements under 20 AAC 25.112(c) is requested due fish obstructing access to the wellbore at the liner top. A lateral plug across the confining zone above the fish will provide isolation of the reservoir and prevent vertical movement of fluid within the wellbore. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. Eline: Res AB Sundry Well: 18-09B PTD: 198079 API: 50-029-21566-02 1. Set CIBP at 10515’ MD mid element, just above top of fish. Tie into HES Jewelry log dated 11/15/2024. 2. Punch 3.5” tubing from 10505-10510’ MD. Punch 3.5” tubing from 9380-9385’ MD. Tie into HES Jewelry log dated 11/15/2024. A. Use 0° phase, decentralized, oriented to low side, rated for 3.5”, 9.2#, L-80 tubing. Coiled Tubing: 1. MIRU CTU. 2. RIH with one-trip cement retainer and tag top of CIBP at ~10513’ MD (set counter depth at pick up). PUH to 9450’ MD based on eline set depth of CIBP. 3. Set retainer at 9450’ MD and displace CT with 1% KCL. Verify flow through punch holes and 3.5”x 5.5” annulus with returns up coil backside when pumping through the retainer. Max circ pressure= 3000 psi. a. Continue slowly circulating fluids to keep well cool until cement is ready to be pumped. 4. Pump FW spacer and then pump 23-bbls of cement through retainer, taking returns from coil annulus. Unsting from retainer, let ~1 bbl exit and begin picking up, laying in remaining 32 bbls cement, 1: 1 returns up to 5700’ MD. Displace cement with 1% KCl. 3.5” tubing capacity= 115 ft/ bbl. Max circ pressure= 3000 psi. Cement Volumes: x 3.5” tubing from 5700’-9450’ MD: 3750’ x 0.0087= 33 bbls x 3.5” tubing from 9450’-10515’ MD:1065’ x 0.0087= 9 bbls x 3.5” x 5.5” annulus from 9417’-10510’ MD: 1093’ x 0.0113 bpf= 13 bbls x 3.5” x 7.625” annulus from 9380’-9417’ MD: 37’ x 0.034 bpf= 1 bbl Total cement: 56 bbls Cement Type/weight:Class G 14-16 ppg Bottom hole static temp:210°F Fluid Loss:60-80 cc/30 min Thickening Time:Minimum 6 hours 5. Once tail end of cement is out of nozzle, SD pump and close in CTBS. 6. PUH ~200’ and begin pumping pipe displacement while POOH. 7. Freeze protect well to 2,500’ MD with diesel. 8. Breakdown cementing BHA and RDMO CTU. Slickline 1. WOC 5 days, Drift and tag TOC –AOGCC Witnessed Fullbore 1. WOC 5 days, MIT-T to 2500 psi max applied pressure, 2250 psi target pressure –AOGCC Witnessed Res AB Sundry Well: 18-09B PTD: 198079 API: 50-029-21566-02 Current Schematic Res AB Sundry Well: 18-09B PTD: 198079 API: 50-029-21566-02 Proposed Schematic 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 18-09B Ice Plug Removal Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-079 50-029-21566-02-00 13636 Conductor Surface Intermediate Liner Liner 8694 80 4620 9531 2550 3041 11638 16" 10-3/4" 7-5/8" 5-1/2" 2-3/8" 8506 32 - 112 31 - 4651 29 - 9560 9417 - 11967 10593 - 13634 32 - 112 4011 29 - 7305 7198 - 8666 7975 - 8694 10520 , unknown 670 2090 4790 6280 11780 11638 1640 3580 6890 7740 11200 12030 - 13589 3-1/2" 9.2# L-80 30 - 10680 8678 - 8693 Structural 3-1/2" TIW HBBP , 9349 , 7147 No SSSV (3-1/2" TRDP-2A locked out) 9349 7147 Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907) 564-4891 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028307 30 - 8016 0 0 0 0 0 0 0 0 0 0 324-546 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:41 pm, Nov 21, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.11.20 16:50:18 - 09'00' Bo York (1248) RBDMS JSB 112724 WCB 2-11-2025 DSR-11/21/24 ACTIVITYDATE SUMMARY 10/27/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Hydrate Thaw MIRU and RIH with slim SLB hydrate thaw BHA & 1.75" monty ice pick DJN. Jet through hydrates from 3942' to 4300' CTM. Continue in hole and tag fish at 10533' CTM. Circulate in diesel from 10520' to surface. RDMO. ***Job Complete*** 11/15/2024 ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV=PASS DRIFT AND TAG FISH @ 10,498' SLM W/ 10' x 2.0" BAILER RAN HES GR/CCL LOG FROM 10,501' SLM TO 9,000' SLM ***CONT WSR ON 11/16/2024*** 11/16/2024 ***CONT WSR FROM 11/15/2024*** HES 759 R/D ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** Daily Report of Well Operations PBU 18-09B jy MIRU and RIH with slim SLB hydrate thaw BHA & 1.75" monty ice pick DJN. Jetyy through hydrates from 3942' to 4300' CTM. Continue in hole and tag fish at 10533'gy CTM. Circulate in diesel from 10520' to surface. RDMO. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 18-09B Ice Plug Removal Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-079 50-029-21566-02-00 ADL 0028307 13636 Conductor Surface Intermediate Liner Liner 8694 80 4620 9531 2550 3041 11638 16" 10-3/4" 7-5/8" 5-1/2" 2-3/8" 8506 32 - 112 31 - 4651 29 - 9560 9417 - 11967 10593 - 13634 2470 32 - 112 4011 29 - 7305 7198 - 8666 7975 - 8694 10520 , unknown 670 2090 4790 6280 11780 11638 1640 3580 6890 7740 11200 12030 - 13589 3-1/2" 9.2# L-80 30 - 106808678 - 8693 Structural 3-1/2" TIW HBBP No SSSV (3-1/2" TRDP-2A locked out) 9349 / 7147 Date: Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907) 564 - 4891 PRUDHOE BAY 9/30/24 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 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.19 22:17:42 - 08'00' Bo York (1248) 324-546 By Grace Christianson at 11:24 am, Sep 23, 2024 MGR03OCT24 10-404 SFD 9/23/2024 DSR-9/27/24JLC 10/3/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 12:35:09 -08'00'10/07/24 RBDMS JSB 100824 Jet Ice Plug, Jewelry Log Well: 18-09B PTD: 198079 API: 50-029-21566-02 Well Name:18-09B Permit to Drill Number:198079 Well Type SU API Number:50-029-21566-02-00 Job Scope:Jet Ice Plug, Jewelry Log Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd: Estimated Start Date:09/30/24 Estimated Duration:3days Regulatory Contact:Carrie Janowski First Call Engineer:Oliver Sternicki Cell Number:907-350-0759 Second Call Engineer:David Bjork Cell Number:907-440-0331 Current Bottom Hole Pressure:3350 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2470 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:700 psi Min ID:2.812” TRSV Nip @ 2179’ MD Max Angle:62 deg @ 10590’ MD Well History: 18-09 was originally completed in 1986. It was rig sidetracked in 1992 to 18-09A. 18-09A was sidetracked in 1998 to 18-09B. A cretaceous leak was found in 1999 and a cement squeeze above the packer was performed. A CTD sidetrack was planned in 2013-2014 under Sundry # 313-247. A CIBP was set in 2013 at 11638’ MD to abandon the perforations and the liner was cut in early 2014 at 11575’ CTM, but coil was unable to pull the top section of liner. The liner was cut again later that year at 11540’ MD, but coil was unable to pull the cut liner. The well was suspended on 07/07/2014. On 4/25/18, CT place 3000' of 60/40 in the tubing. AOGCC is requiring placement of a regulatory compliant reservoir plug for continued suspension status on 18-09B. We require a jewelry log to determine if a sufficient lateral plug can be placed in the tubing and IA above the fish at 10520' SLM. Current Status: On 9/10/24, SL ran into a hydrate plug at 3857' SLM so we were unable to complete the log. Hydrate plug requires removal to get the jewelry log so the reservoir plug can be planned. Objectives: Clear tubing hydrate restriction with CT. SL jewelry log. Procedure: Eline: 1. MU DJN and clear ice/ hydrates from tubing and drift to fish at 10520' SLM. Unknown if any pressure is below SL tag at 3857' SLM, but reservoir should be secured. 2. Circ tubing out to diesel (91 BBLs to 10520' MD) Slickline : 1. Drift and tag fish at 10520' SLM. Size drift for jewerly log or future tubing puncher run, whichever is larger. 2. GR/CCL jewelry log from fish to 9000' MD, tied into 3.5" tubing summary dated 9/14/1992. Jet Ice Plug, Jewelry Log Well: 18-09B PTD: 198079 API: 50-029-21566-02 Jet Ice Plug, Jewelry Log Well: 18-09B PTD: 198079 API: 50-029-21566-02 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/28/2023 InspectNo:susSAM230731190013 Well Pressures (psi): Date Inspected:7/31/2023 Inspector:Austin McLeod If Verified, How?Other (specify in comments) Suspension Date:7/7/2014 #313-247 Tubing:520 IA:20 OA:170 Operator:Hilcorp North Slope, LLC Operator Rep:Andrew Ogg Date AOGCC Notified:7/29/2023 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT 18-09B Permit Number:1980790 Wellhead Condition All valves/gauges on wellhead/tree in good working order. SSV was closed. Opened to obtain tubing psi. SSV functioned both ways fine with no issues. Wing locked close. Surrounding Surface Condition Typical pad gravel. Nothing out of the ordinary. Condition of Cellar Dry, clean gravel. Comments Pad map used to verify location. No issues. Supervisor Comments Photos (4) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Thursday, September 28, 2023 2023-0731_Suspend_PBU_18-09B_photos_am Page 1 of 2 Suspended Well Inspection – PBU 18-09B PTD 1980790 AOGCC Inspection Rpt # susSAM230731190013 Photos by AOGCC Inspector A. McLeod 7/31/2023 2023-0731_Suspend_PBU_18-09B_photos_am Page 2 of 2 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 18-09B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-079 50-029-21566-02-00 13636 Conductor Surface Intermediate Liner Liner 8694 80 4620 9531 2550 3041 11638 16" 10-3/4" 7-5/8" 5-1/2" 2-3/8" 8506 32 - 112 31 - 4651 29 - 9560 9417 - 11967 10593 - 13634 32 - 112 31 - 4011 29 - 7305 7198 - 8666 7975 - 8694 10520 , unkown 670 2090 4790 6280 11638 1640 3580 6890 7740 12030 - 13589 3-1/2" 9.2# L-80 30 - 10680 8678 - 8693 Structural 3-1/2" TIW HBBP , 9349 , 7147 No SSSV (3-1/2" TRDP-2A locked out 9-29-98) 9349 7147 Bo York Operations Manager Andy Ogg Andrew.Ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028307 30 - 8016 000 0 00 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 11200 11780 0 0 0 0 By Grace Christianson at 1:01 pm, Aug 29, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.29 06:55:26 -08'00' DSR-8/29/23 RBDMS JSB 083123 WCB 3-12-2024 ACTIVITYDATE SUMMARY 7/31/2023 T/I/O = 530/20/170. Temp = SI. AOGCC Suspended Well inspection by Austin Mcleod. No AL. SV = C. WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 14:30 Daily Report of Well Operations PBU 18-09B D ! ) ) D ) ! ) ) D ( D ) !#) D ) D ! D ) ) D D ( D D ! ) ( ! ) ) ( ( ) ) ! D D ( ( ) D D D D ! )#) ! D ( ) D ) )) ) ) ) D ) ( ) ) ) ) D ) ) ) ) ) D ) ) D D ) ) ) ( ) D#D ) D D ! ) D ) ( ( ) ) ( ) ) ( ! ) ) ) ( ) ( ! !) ! D ) D ) ( ) ) ) D ? D (#) ( ) ) D D )#D D ) ) ) D ) ) D ) ( ! ( D ) D ) ) D ) ) D ( ) ) D D D ) ) D ( D ! ) D ) D ) )D D ) ( ) ) ( ) ( ( ) D ) D ( D ( ) ( ) ) ( ) ) D ( ! ) ! ( ) D ( D ) D ) ( ) ) ) D ) ( D ) ) ) ) )#) ( ) ( ! ) ) ! ( ) ( ) ) ( ) D ! ( (#D ( ) )#! D ) D ( ) ) )#) D #) D ) ! ) D D ) ( ) ) D ! ) D D ) ) ) D) D )( D ) )D ) ! D ! D ) D D ) WGI DSL2 DS18 NGI ( 18-10APB1 18-05A 05-16A 18-14BL1 L2-11PB1 18-02B 18-27A 18-03B 02-18CPB1 15-09B 05-28BPB1 18-15A L2-06 NGI-02 18-11 15-42PB1 15-34 18-27EPB1 05-23B 15-30APB1 L2-21A 15-11CPB1 15-37APB1 15-36C 18-35PB1 15-12BPB1 15-25B 02-38L1 15-07D L1-01L1 18-09A 18-22 18-24B 15-40A 02-17 18-04B L1-09 18-02CPB1 18-26PB1 18-06B L2-33 02-16 18-11BPB1 15-42BPB1 18-15APB1 02-08B 05-28A 15-42 15-38A 18-07APB2 02-39A 15-11A 15-07DPB2 18-07B 15-31 15-12A 02-18 L2-14B 15-37A 18-19PB1 18-27D 15-35 02-37 18-31 18-16A 18-26 15-49APB1 18-18A 15-10 02-30 02-09B 18-10B 18-26APB1 15-16A 18-11DPN 18-04BPB1 02-18APB3 18-01 15-09 18-03 02-16C 18-08 18-13BPB2 NGI-03 18-07CPB1 02-01B 18-29BPB1 15-38APB1 18-33A 15-31A 02-36APB1 15-42A 18-07C 15-12B 15-37B L2-07 L2-14C 02-38 15-49 18-27E L1-01 02-37L1 15-11B 15-07B L2-10 18-02 02-18C 18-16B 15-25 18-31A 18-18BPB1 15-15 18-14APB1 15-36A 18-17 18-26A L2-03 02-32B L2-11PB2 L2-11CNX 18-10APB2 L2-29A NGI-08 18-27B 18-02C 18-15B 07-33B 15-42PB2 15-09APB1 15-30A NGI-01 15-16BPB1 02-30BPB1 L2-14 15-08 18-07 18-08APB1 L2-26 02-36 18-13PB1 18-29A 15-49C 15-34A L2-21B 15-25APB1 18-28PB1 15-07CL1 18-14B 15-36BPB1 PBST01 15-36B L2-29PB1 18-26B 18-04C 15-07 L1-01L1PB1 18-02APB1 18-10CPB1 18-29B 02-16A 15-16CPB1 15-30B 18-11BPB2 05-28B 18-15CPB1 L2-13 18-13PB2 18-07A 18-08BPB1 02-39APB1 18-24 L2-25 02-18A L2-14A L1-13 15-11 L2-30 15-39A 18-16 15-07DPB1 18-32 PBST01PB1 18-18B 15-36BPB2 L1-02 18-13B 18-10C 02-30A 05-16B 18-14C 15-16B 18-27 02-16CPB1 18-03C L2-11 18-02A L1-13L1 15-10A 18-23 02-18BPB1 18-01A 18-13BPB3 02-32 18-33APB1 18-08A 15-42B 18-04 L2-07A 02-17A 18-27EPB2 L2-21 15-15C 02-18APB1 18-14 15-25A 15-07C 18-10 18-06 WGI-07 18-24AL1 L2-07B 18-09 18-22A 05-16C 18-04A 15-36 L2-03A 02-30B L2-29 18-23A 02-32A 15-30 18-11B 15-38 15-42PB3 18-08B 18-15C 18-19 LPC-02 18-07APB1 02-36A 02-39 18-29 WGI-05 02-17B 15-49PB1 05-28 L2-07APB1 L2-13A 18-15 15-12 NGI-12 18-27C 02-18APB2 NGI-07A 18-06A 15-15CPB1 18-14A L2-24 18-18 L2-07BPB1 15-36APB1 18-24AL2 02-33B 15-16 18-03A 02-39APB2 18-04D 18-10A 18-11BPB3 18-26APB2 18-05 15-09A 02-16B 05-28APB1 05-16 18-13BPB1 15-31B 18-18APB1 18-24A 15-49A 18-27DPB1 02-18B 15-11C L1-13PB1 18-35 15-12APB1 15-07A L1-13L1PB1 18-31PB1 18-09B 11 12 13 24 1814 7 23 19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL Z n mci 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operetions. d 3 Suspend ❑ Perforate 11 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 198-079 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-21566-02-00 7. Property Designation (Lease Number): ADL 028307 8. Well Name and Number: PBU 18-09B 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: Total Depth: measured 13636 feet Plugs measured 11638 feet true vertical 8694 feet Junk measured 10520, 10593 feet Effective Depth: measured 11638 feet Packer measured 9349, 7147 feet true vertical 8506 feet Packer true vertical 10651.8003 fee( Casing: Length. Size: MD. TVD: Burst: Collapse: Structural Conductor 80 16" 32-112 32-112 1640 670 Surface 4620 10-3/4" 31 -4651 31-4011 3580 / 5210 2090/2480 Intermediate 9531 7-5/8" 29-9560 29-7305 6890 4790 Liner 2550 5-1/2" 9417-11967 7198-8666 7740 6280 Liner 3041 2-3/8" 10593 - 13634 7975-8694 7740 6280 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 30-10680 30-8016 Packers and SSSV (type, measured and 3-12" TIW HBBP Packer 9349 7147 true vertical depth) 3-1/2" Baker SABL-3 Perm Packer 10651 8003 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: Suspended Subsequent to operation: 14.Attachments: (regwre4 per 20 nwc 25 mo 25.071,&25.283) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 21 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: I pecialist Contact Email: Travis.MontgomervAtip.com Authorized Signature: Da.: � 12.%IFI Contact Phone: +1 907 564 4127 Form 10-404 Revised 0•U201TAw •"'�'�-'-^� R$DMS�JUL 312019 Submit Original Only Daily Report of Well Operations 18-09B ACTIVITYRATF RI IMMARV T/I/O = 320/30/180. Temp = SI. Pre AOGCC SU well inspection. No AL. Wellhead, wellhouse and cellar are clean and dry. Surface area around well is clean, dry and free of debris. Well ID sign attached to wellhouse. 6/29/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 22:10 T/I/O = SSV/0/150. Temp = SI. SU Well Inspection (AOGCC inspected by Bob Noble). No AL. 7/6/2019 SV, WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 09:50 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 18-09B Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1980790 API Number: 50-029-21566-02 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 9144#2&6 Surface Location: Section: 24 Twsp: 11N Range: 14E Nearest active pad or road: DS -18 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation 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: C IeA A Pad or location surface: _�eA ^ Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pad, pits or water: C Samples taken: None Access roac concitlon: Photographs taken (# and 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: CICAn Cellar description, condition, fluids: (�Pu Rat Hole: AJ /d Wellhouse or protective be Well identification sign: Tubing Pressure (or casino Annulus pressures: Wellhead Photos taken (# Work Required: None Operator Rep (name and signature): AOGCC Inspector:1j3eL A)n6f p Inspection Date: P Time of arrival: r 69, Site access method: Acce Josh Prowant AOGCC Notice Date: Time of Departure: Arl Ll -09 11 NGF03 12 r; 18-11 BP83 C 1�-118 L2-07BPB1. 18-11$PB2 • L2 -07B j_ ,, C L2-07 ' [ is. 10Bl _ -07L1-01 G 18-10A ;{ , _ X L2-07APB1 1 30APB�- -3011-Q7C 15-3de 1 i C 13 -18B _7-18-18A 18-10AP82 A 13-10C J15 -38B — 18-10APB1 - - .18-136PB1 _ 15.-07B C L2-25 � 18-1KP81 18-18APBif7 L2-29 F 18-70 - 1&22A-13-25 5A7CL{2AP62 18-25P1°..18-2 18-2-E > 18-20PB1 15-15A 98 - 131E 0_D I,L2-2181°-- _- '7g - t3-27EPB2 L2-21 09A15 -09A 18-27E -31 1809Af, 18-23A 18-31PB 13-2, — r is2-L- L2 --!QA C 15-34A/ 1g , _ 18-09 1, i 18-31A — -S-07E 18-27E i 18-07A y L 15-49— .-07 18-08 i. 18-07APB2 — �' h C 1&31A � 15--07 III v 15-258 18-04D h5-10 15-11C 23 15-311 C18-17 v n I 15-11CPB1 � C oz -35 i5 -1Y$ 15-318 `; ❑ 15-42AA a2 -17J`{ 15' �15-11 18-05A �72^18 -- y� 18-05 12PB2 eE0 02-18B 15-42 02-33Bn 7 O L2-33 O 8-02CI L2-11 PB 1 -288 L2-1!PE2 1, �-35P81 , L1 DS L2 P81 • i✓ 13-15C L2 -14C u 4t _18A8 S" (QJ T. I A 8:08BPB1 — �1-, _ I L 18 -ORA � 18-35 — ri$TB- 18-15CP B1 /". L2 -13A LpC_q 13-15APB 1 A 18-246 1_ 15-11 L2 -03A 18-15A '� 18-13P61 L: 18-29B 24 LL 18-24 7 18-04 L V Zi 18-29A — 18-29BP61 18-04A r' r 18- _ O [�� L1 18-24A 13-04B 18-03C[_ 1 -14B 18-24AL2 4. L2-03-. 18-14 18-04BPBT u18-29. 18-19P61 _ -18C L2-11CNXC*13-19 18-03A 18-14APB1 02- ISCPB t _ 18-028 ij 313�i5--2- 118-03B 8AP63+ �-18APB2 — 18-0A 18-02A41 `0.F-1BH m 9- qvl run len WELLHEAD =FMC ACTUATOR= BAKERC OK ELELEV= _-_- BF. ELEV = -- 48' 18.68' KOP - -_ 1900' Max Argle, = 94• 0 1275T Dakin MD= WA Dakan ND= saw SS SUSPENDED 16' W NUUCTOIj 62.5#, H-40, D = 7 �y 170' 10-3/4• CSG, 45.5#, L-BO/J-55, D = 9.953' 466T EST TOC FROM A SQZ OF 12/11/99 1 97W I Minimum ID =1.941" Ca 10598' TOP OF 2-3/8" LN R 7-5/8" CSG, 29.7#, L-80, D = 6.875' 1-I 9660' FSH: 2.66" BOWEN OS w2 -7/8"G' FN & 30' SL TOOLS STRING LATCHED ONTO 3- SLICK CATCH (02/13/18) 1052W SLM SIZE SPF INTERVAL 3• SLICK CATCH G -SPEAR w/HFLOAD )NNECT (2.13) LATCHED INTO LNR (7/7/14) SHOT SQZ TOP OF 2-39• LNR 10693' HOLE N 6-12' LNR SQUEEZED 09/11/921- 04/08/02 3-12' TBG PC, 9.2#, L-80, .0087 bpi, D = 2.992' -10679- 12-3/8" JET CUT (06/15/14) 11640• PERFORATION SLFM1ARY RE= LOG: CAL ON 09/12/92 ANGLE AT TOP PERF B3"@12030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 1-9/16" 6 12030-12095 C 04/08/02 ME 1-9/16" 6 12130-12205 C 04/08/02 •'2 1-11/16" 4 12240-12305 C 0727/96 DMY 1-11/16" 4 12595-12705 C 0727/98 9119 1-11/16" 4 12745-12855 C 0727/96 RA 1-11/16" 4 12915-13589 C 0727/98 15-1/2' LNR. 17#. 13 -CR -80. D=4.892' 1 w OTIS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3940 3522 47 ME DMY T2 0 10/08/10 •'2 6817 5460 50 ME DMY T2 0 0525/02 `3 9119 6977 43 ME DMY RA 0 0525/02 `4 9274 17091 42 ME EMPTY - - 05/25/02 'STA #2,3 & 4 = CEMENT BEHIND ON THE IA -STA #2 = DAMAGED & RESTRICT® - ID UNKNOWN - SEE VIDEO LOG 05/28113 - STA #2 MILLID TO 2.800" 01/02/14 7-5/8' MLLOUT WINDOW (18-09A) 9560'- 9620' 10693' -J2.70- BKR DEPLOY SLV, D = 1.969' 10661' 5-12' X 3-12' BKR S3 PKR, D = 2.780' I116W-2-3/8"CBP(09/13/13)3/8"CBP(09/13/13) 5-12" MLLOUT WINDOW (18-09B) 11967'- 11971' 2-3/8• LNR, 4.43#, L-80 FL4S, I 134' 63 .0039 bpf, D = 1941'. DATE REV BY COMMENTS DATE REV BY COMMENTS 8411)596 N26E INTIVIL COMPLETION 0220/18 MTWJMD RECOVERED TOP FISH 02/12118 0811592 N2ES SIDETRACK (18-09A) 0726/19 JNL/JMD ADDED BF & SUSPENDED 072798 N413S CTD SIDETRACK 18-098 11A8/17 JL UMD HOLE N 5-72' LNR/S02D (9/1192) 01W18 GJB/JMD SETFISH 1229/77 01/09/18 DG/JMD SETFISH 01/03/18 BEHIND PBTD H 13607' PRUDHOE BAYUNR WELL: 18-098 PERMIT No: 1980790 API No: 50-029-21566-02 BP Exploration (Alaska) Suspended Well Inspection Review Report InspectNo: susRCN190707170310 Date Inspected: 7/6/2019 Inspector: Bob Noble Type of Inspection: Subsequent Well Name: PRUDHOE BAY UNIT 18-09B Date AOGCC Notified: 7/5/2019 Permit Number: 1980790 Operator: BP Exploration (Alaska) Inc. Suspension Approval: Completion Report Operator Rep: Josh Prowant Suspension Date: 7/7/2014 Wellbore Diagram Avail? Location Verified? Photos Taken? 0 If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 150 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead protected with a wellhouse. Flowline is attached. AL line is blinded off. SSV is closed. Condition of Cellar Good clean dry gravel. Surrounding Surface Condition Clean gravel. Comments Wellhead was verified with a pad map. Supervisor Comments Photos(2)attached Monday, August 19, 2019 Suspended Well Inspection — PBU 18-09B PTD 1980790 AOGCC Inspection Rpt # susRCN 1907071703 10 Photos by AOGCC Inspector B. Noble 7/6/2019 2019-0706_ Suspend _PBU_18-09B_photos_bn.docx Page 1 of 1 +�a:•a w Y a i 2019-0706_ Suspend _PBU_18-09B_photos_bn.docx Page 1 of 1 ID , ,A; 1 % %,k s THE STATE Alaska • il and Gas tf Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Off; Q. Anchorage, Alaska 99501 -3572 tL LASY' Main: 907.279.1433 Fax: 907.276.7542 John McMullen SCANNED MAY 2 02013 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 V t Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, T PBU 18 -09B Sundry Number: 313 -247 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i 1) z�� Cathy P. oerster Chair DATED this 17 da y of May, 2013. • Encl. STATE OF ALASKA • "' D ALASKA OIL AND GAS CONSERVATION COMMISSION ixi∎ "V1 Y' 4 1 2013 APPLICATION FOR SUNDRY APPROVAL 6/` 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ® Plug for Redrill ' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend 101 Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shwn ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 198 - 079 . 3. Address: 6. API Numbe ® Development ❑ Service P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 21566 -02 -00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 18 -09B . Will planned perforations require a Spacing Exception? ❑ Yes ® No 9. Property Designatior 10. Field / Pool(s): ADL 028307 ' Prudhoe Bay / Prudhoe Bay 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13636' 8694' 13607' 8693' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 4651' 10 -3/4" 4651' 4011' 3580 / 5210 2090 / 2480 Intermediate 9560' 7 -5/8" 9560' _ 7305' 6890 4790 Production Liner 2550' 5-1/2" 9417' - 11967' 7198' - 8666' 7740 6280 Liner 3041' 2 -3/8" 10593' - 13634' 7975' - 8694' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12030' - 13589' 8678' - 8693' 3 - 1/2 ", 9.2# L - 80 10680' Packers and SSSV Type: 7 - 5/8" x 3 - 1/2" TIW HBBP Packer Packers and SSSV 9349' / 7147' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal .■ BOP Sketch Cl Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: May 20, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston, 564 -5985 Printed Name: John M�,. Title: Engineering Team Leader Email: David.Johnston2 @bp.com A O Signature: , v Phone: 564 - 4711 Date: 4114 A„,3' L°"` Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/3 _ `-1'I ❑ Plug Integrity E(BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: ,o O p fes 7 fa 35 U p S G \ RBDMS MAY 17 701 Spacing Exception Required? ❑ Yes 13 No Subsequent Form Required: 10 -- 4o7- ) , 7 i2 / / 1 APPROVED BY Approved By: ( �z� 7 ',A„, ! G- ' — C OMMISSIONER THE COMMISSION Date: S (� '– ( -, Form 10-403 Revised 10/012 App a i �a o I' f 1 2 months from the date of approval Submit In Duplicate J �� 0 Vi-11x /13 ML i1 c .\ To: Alaska Oil & Gas Conservation Commission From: David E. Johnston 0 bp CTD Engineer Date: May 15, 2013 Re: 18 -09B Sundry Approval Sundry approval is requested to plug the 18 -09B perforations as part of the drilling and completion of proposed 18 -09C coiled tubing sidetrack. History and current status: 18 -09 was originally completed in 1986. It was rig sidetracked in 1992 to 18 -09A. 18 -09A was sidetracked in 1998 to 18 -09B. The Z1A sidetrack came on strong with normal to high gas rates. A cretaceous leak was found in 1999 and a cement squeeze above the packer was performed. A SCMT log in 2002 found the TOC at 11,606' while the liner top is at 10,598'. Z1B was added in 2002 and the production increased after the adperf job. The well has been cycled off and on since it produces at marginal GOR. Proposed plan: Sidetrack 18 -09B to the 18 -09C location using Nordic 2 Coiled Tubing Drilling rig on or around June 20, 2013. The 18 -09B perforations will be isolated using a cast iron bridge plug, and then the 2 -3/8" production liner will be cut pre rig above the logged TOC. The rig will pull and lay down the 2 -3/8" liner. The 18 -09C sidetrack will exit the existing 5.5" liner and kick off in Zone 3 a 3" pilot hole will be drilled to land in BSAD to help identify fault 1 and define Zone 1A. An aluminium billet will be set in the pilot hole and sidetracked to land in Zone 1A. This sidetrack will be completed with a 2 -3/8" L -80 liner and cemented in place with top of cement left outside the 18 -09C window. This Sundry covers plugging the existing 18 -09C perforations via the 18 -09B Cast Iron Bridge Plug, & liner top packer with a sized orifice for in -situ gas lift (alternate plug placementer 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. f "'a'*'Ce s q t Ae (j cvCr. 7 4 'raer (#. , L �e Got Qs 74e /ad ct,trgt e G H of $%oGvf (, 'tr 1 e_ r; Ch �< < Agri"- fr C o% r�G C y � f 74,y ' -d( 5' " 4 �ro4 i4;5 elf r og OAF 74 "OW ,n � � � lP Cv �wr • • Required Permit? Pre -Rig Work (scheduled to begin May 20th, 2013) 10-403 PTD 1. S B &F 3 -1/2" liner with hot diesel No No Drift to deviation or at least 11,630' MD for setting CIBP w/ E- 2. S line. No No 3. F Load & kill well concurrently with e-line prior to setting CIBP No No 4. E Set 2 -3/8" CIBP at — 11,630' MD, & MIT -T to 2,000 psi. Yes* ' No 5. F MIT - to 2,000psi & chart same. No No Jet cut 2 -3/8" tubing at 11,580' (TOC logged at 11,604 7/6/2002 6. E SLB CBL) No No Pull test 2 -3/8" liner with GS sealable spear to ensure free. 7. C Circulate out well & freeze protect well to 2,000' MD. No No 8. V PT MV, SV, WV No No 9. 0 Remove wellhouse and level pad No No * Approved alternate plug placement per 20 AAC 25.112(i) ) Required Permit? Rig Work (scheduled to begin June 20, 2013) 10-403 PTD 1. MIRU and test BOPE 250 psi low and 3,500 psi high. No Yes 2. Pull cut 2 -3/8" liner out of well. No No 3. Set 3 -1/2" X 5 -1/2" through tubing whipstock at 11,527' MD No No 4. Mill 2.74" window at 11,531' and 10' of rathole. No Yes 5. Drill PB1: 3.25" OH, 1603' (12 deg DLS planned) No Yes 6. Set billet at 12,400' MD. No Yes 7. Drill lateral: 3.25" OH, 2600' (12 deg DLS planned). No Yes ' J PTO 8. Run 2 -3/8" liner leaving TOL at 10,600' MD No Yes 9. Pump primary cement job: 16 bbls, 15.8 ppg, TOC at 11,600' MD No Yes 10. Perform liner cleanout and GR /CCL log No Yes 11. Perforate liner based on log interpretation (^'800') No Yes 12. Set 3 -1/2" liner top packer with sized orifice at 10,950' MD No Yes 13. Freeze protect well to 2500' MD No Yes 14. Set BPV; RDMO No Yes Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. ASRC flowback/well test David Johnston CTD Engineer 564 -5985 CC: Well File Joe Lastufka TRt = 3-1/8" FMC y1lELLHEAD = FMC • NOTES: TM/ HBBP PKRS REDUCED TEST PRESS. LIMITS IN SOME CASES. CONTACT WIE ACTUATOR = AXELSON 18-09B (X5102) PRIOR TO ANY PT WORK. CMT SQZ HOLE KB. ELEV = 48' BF. ELEV = IN 5 -1/2" LNR@ 10623'. WELL ANGLE > 70° @ KOP = _ _ 1900' 11965' & > 90° @ 12262'. 5 -1/2" CHROME LNR Max Angle = 94 @ 12753' Datum MD = N/A Datum TVD = 8800' SS IP I 2179' I— 3-1/2" CA TRDP -2A TRSV NIP, ID = 2.812" LOCKED OUT (9/29/98) GAS LIFT MANDRELS 10 -3/4" CSG, 45.5 #, L- 80/J -55, ID = 9.953" I 4651' 7 I STI MD I TV DI DEV I TYPE I V LV LATCH PORT DATE 1 3940 3522 47 OT -ME DMY T2 0 10/08/10 I EST TOC FROM IA SQZ OF 12/11/99 IH 5700' 1 2 6817 5460 50 OT -ME DMY T2 0 09/23/99 • 1 3 9119 6977 43 OT -ME DMY RA 0 09/15/92 � • 1�1�1� 4 9274 7091 42 OT -ME EMPTY – CMT 12/11/99 Minimum ID = 1.941" @ 10598' 1 1 1 � " TOP OF 2 -3/8" 4.43# LINER 1 1 9296' I-- I3 -1/2" PARKERSWS NIP, ID= 2.813" I '�'1 w•� 9349' H 7 -5/8" X 3 -1 /2" TM/ HBBP PKR, ID = 3.00" I I I 9372' H3_1/2" PARKER SWS NIP, ID = 2.813" I TOP OF BKR TIEBACK SLV, ID = 5.75" H 9417 I t -I 9429' I- 9425' 1-17-5/8" X 5-1/2" BAKER H PKR, ID = 4.875" 17 -5/8" X 5-1/2" BKR LNR HGR, ID = 4.875" I 17 -5/8" CSG, 29.7 #, L -80, ID = 6.875" H 9560' I— 7 -5/8" CSG SDTRK WINDOW (18 -09A) 9560'- 9620' (SECTION MILL) 2.70" BKR DEPLOYMENT SLV, ID = 1.969" H 10593' I I I TOP OF 2 -3/8" LNR, 4.43 #, ID = 1.941" I-1 10598' I 8 ,_ I 10651' I— 5-1/2" X 3-1/2" BAKER SABL -3 PKR, ID = 2.780" (BEHIND LNR) I I 10668' I— 3-1/2 PARKER SWN NIP, ID = 2.635" MILLED TO 2.780" (BEHIND LNR) 3 -1/2" TBG PC, 9.2 #, L -80, .0087 bpf, ID = 2.992" I—I 10679' I / 10680' I I3 -1/2" WLEG (BEHIND LNR) I I H ELMD TT (BEHIND LNR) I PERFORATION SUMMARY ---_ __ r ' 2. , '"' 5 REF LOG: CNL ON 09/12/92 lI 5 SO ANGLE AT TOP PERF: 83 @ 12030' r Note: Refer to Production DB for historical perf data 9 Y f I 4 SIZE SPF INTERVAL Opn /Sqz DATE 1- 9/16" 6 12030 - 12095 0 04/08/02 5 -1/2" LNR SDTRK WINDOW (18 -09B) 1- 9/16" 6 12130 - 12205 0 04/08/02 r • v 1 11967'- 11971' (OFF CMT RAMP) 1- 11/16" 4 12240 - 12305 0 07/27/98 1 1- 11/16" 4 12595 - 12705 0 07/27/98 ► 1 1 1 1 ' ∎ 1- 11/16" 4 12745 12855 0 07/27/98 ••••■ MO** •••••••■ 1- 11/16" 4 12915- 13589 0 07/27/98 111111111 11111111 111111111 1• 1• 111• 11111 11111111 44 11111111. 11111111 111111111 1 / PBTD — 13607' I 5-1/2" LNR, 17 #, 13- CR -80, ID = 4.892" I—I 12233' ,1,1,1,1,1,1,1,1, M. Ms 1 2 -3/8" LNR, 4.43 #, FL4S, .0039 bpf, ID = 1.941" I—I 13634' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/05/86 ORIGINAL COMPLETION 03/03/06 TEL /PJC GLV C/O WELL: 18 -09B 09/15/92 RIG SIDETRACK (18 -09A) 03/07/06 RCT /PJC TRDP LOCKED OUT (9/29/98) PERMIT No: 1 980790 07/27/98 CTD SIDETRACK (18 -09B) 10/23/10 RCT /AGR GLV C/O (10/08/10) API No: 50- 029 - 21566 -02 04/08/02 JAF /tlh ADD PERFS SEC 24, T11 N, R14E, 486' FNL & 342' FEL 09/13/03 CMO/TLP DATUM MD/TVD & PERF ANGL 08/27/04 CAO/TLP GLV C/O ON 05/25/02 BP Exploration (Alaska) I I TREE= 3-1/8° FMC SAFETY NOTES: TMI HBBP PKRS REDUCED TEST WELL ACTUATOR = Axfl SON PROPOSED A= FMC 1 8 _ 9 C PRESS. LIMITS IN SOME CASES. CONTACT WIE ( X5102) PRIOR TO ANY PT WORK. CMT SQZ HOLE 1 MIA_ KB_ ELE 48' BF. ELEV = - IN 5 -1/2" LNR@ 10623'. WELL ANGLE > 70 @ KOP= 1900' '. 5 -1/2" CHROME LNR Max Angle = 94° @ 12753' Datum MD = MA Datum TVD = 8800' SS O 2179' I 3-1/2" CA TRDP -2A TRSV NP, D = 2.812" LOCKED OUT (9/29/98) CiAS LI - I MA NDF1=LS 10-3/4" CSG, 45.5#, L-80/J-55, D = 9.953" H 4651' i ST M3 l VI) DEV TYPE VLV LATCH PORT DATE 1 3940 3522 48 OT -ME DMY 12 0 10/08/10 EST TOC FROM IA SOZ OF 12/11/99 -I 5700' 2 6817 5460 50 OT -M= DMY T2 0 09/23/99 4. 4. 3 9119 6977 45 OT -M= DMY RA 0 09/15/92 4 9274 7091 42 OT -11E 9)FTY - CMT 12/11/99 Minimum ID = " @ 10600' * * * TOP OF 218" 4.7# LINER _ .∎ 9296' -13-1/2" PARKER SWS NP, D= 2.813" • V � 9349• I- I7 -5/8" X 3-1/2" TNV HBBP PKR, ID = 3.00" I I 9372' H3 PARKER SWS NP, D = 2.813" TOP OF BKR TEBACK SLV, D = 5.75" H 9417' t 7 -5/8" X 5-1/2" BKR LNR HGR, D = 4.875" I-1 9429' 9425' 1 7 - 5/8" X 5-1/2" BAKER H PKR, D = 4.875" 7 -5/8" CSG SDTRK WNDOW (18 -09A) 7-5/8° CSG, 29.7 #, L -80, D = 6.875" H 9560' I— 9560' - 9620' (SECTION MLL) I3 -112" LTP w /FLOW TFRU ORFICE, D = IH 10598' -- -----_, t — 17.70" BKR DEPLOY M3aff SLV, D = 1.969" IH 10600' I — I g 8 10651' 1 5 -1/2" X 3 -1/2" BAKER SABL -3 PKR, ID = 2.780" (BEHND LNR) I I 10668' 3 -1/2 PARKER SWN NP, ID = 2.635" MILLED TO 2.780" (BEHIND LNR) 3 -1/2" TBG PC, 9.2#, L -80, .0087 bpf, D = 2.992" - I 10679' / \ 10680' IH3 -1/2" VVLEG (B9-ItD LNR) I IH ELM3 TT (BEHND LNR) 5-1/2" LNR, 17 #, 13- CR -80, D = 4.892" -1 11527' 5 -1/2" MLLOUT WINDOW (18 -09C) 11527' - 15 -1/2" WHPSTOCK (XX- XX -XX) H -11527' PERFORATION SUNSAARY r . ■ , - 11600' HTOC I REF LOG: ON )0X/XX/XX P ANGLE AT TOP PERF: ° @ ►. 1 _ Note: Refer to Production DB for historical pert data % SIZE SPF NTERVAL Opn/Sqz SHOT SQZ P P P P P P P Rj EiE I- 12 -3/8" LNR, 4.7 #, L -80 T1511, .0039 bpf, 13= 1.995' IH — 15000' DATE REV BY COMdB'TTS DATE REV BY COMv '1TS PIUJHOE BAY UVT 04/05/86 ORIGINAL COMPLETION WELL: /4 0 €; 09/15/92 RIG SIDETRACK (18 - 09A) PST No: 07/27/98 CTD SIDETRACK (18 - 09B) AR No: 50 029 - 21566 4 p 05/16/13 JM3 BUILT PROPOSED SEC 24, T11 N, R14E 486' FNL & 342' FEL BP Exploration (Alaska) NORDIC CTD UNIT # 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM r Cho e Pjnel Standeice 2 Circulation Line `W Q Duller Coupe - r , Mb 0 •• M M •• q Manual Choke pl c - Calista I CIRCULATING MANIFOLD C . 9 1-I MM 16 �OR I • 6 a MM 15 1,32,2t, SIB Transducer ,-,., I -_♦ floor :•. MM, PVT Sensor . $ - 4r. MM ef: owl Shears I Baker Choke MM 13 MM 4 MI 0 MM 17 KILL SIDE MANUAL VALVE 4411S2004141.5 CHOKE SIDE I MANUAL VALVE *Ili. a KILL HCR I II f / Rev Clr Line CHOKE HCR I fAb Blow down `, _ M MI4 .. •� � i•tkt ,. � �'. ►�i dEki♦ �Yk��� WNiWM I e II r ` � s Choke Line Coiled Tubing — ti .. . � _ �� B I I aker Choke KM Line —E % r I MP 2 61: MP1 ... e — I III J 1- KM Line `- / • I •• \ .c BOP 18 FA I HP 11 HP 10 ,,• Trenaucers COILED TUBING I I � \ BOP 17 I H HP TEM • _ _ � CS SSS i'4II /a^'fJ/ �. I � II/I /l� ( HP 14 P 1 HP I I 1 -- To Inner Reel I , Valve HP 15 © HP HP HPJ I - +�' HP 1J i� I I I H P • 12 , , HP2 HP• - _ .:. I HP 76 / / I cement line N2 SLB / / I CHOKE MANIFOLD / -- _ I HP17 N2TrFlow Si 1 a / CM85 f Gauge `' $ MG6 [II F 6.4 - I CM 29 fi CHOKE LINE .. GUS BUSTER pq-7 Test Pump Inlet CM 30 / . .. I / / CM3 . ..... .. ... / Hr Gauge PBt I 4WaV Block Flow 0 H • CM24 • - / e a � — Note '`�_` CM14 CMt/ CMS I - - liquid BIM I CM5 CM6 r _ — PB2 - leg is IMF p - 10' Baker Choke Line s high I aemwal 3 - - - _ _ I CMI3 111=. • I I 1 . I NE — CM2 In POSSUM BELLY I — CM28 e= CM21 CM/ Ce I iin -., • I CM20 I CHOK LIIII N= Tiger Tank In S ..Y4me, I • I — CM18 • CMI9 a - • • I CM27 I TIGER TANK t I • IP ' I I I I V • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IPBRD) Type Work Code in RBDMS / '1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 V form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 225■-1 0 O O i IA 0000000000001300000 ° 000000000c-) 000000000 .-+ U al (,- O• O °o • -a� ] O � a\ 0 F Z � . .-, -" 0 ,.• 0 0 n, u.a >-- ,` n U co .-1 F o ' c F O .,-+ In 4) to 5 t. 3 1 - v m Z C E ° PZI N m rt2 — cc Li-) `V 1.� M M M M M M M M ,,.) ,,, M N N M N N M M M �( 03 cn O '..1 C'� NJ w i �' L C � � .0 C .0 U U C C V \ i fd _� (S) I- V' 10 lQ as @ l0 d d N N IV f6 as Q Q N Cl.) 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NI th d u m t ° 0 0 z U' Z o (� o a d o °; p w �° Q ro E w co CL O u cc N Q (i. x a m a° Q Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 17-14 MPC-10 17-01 P2-30 L 1-31 P2-10 17-03A C-26 15-07C D-04B P2-24 P2-03 09-44 09-23 2-52/S-41 F-08A 02-16C L2-32 L5-09 02-12B 18-09B G-14A 05-20B Job# N/A 11767137 11824337 11686776 11865639 11846804 N/A 11824342 11594517 11591451 11865643 11855502 11855501 11824337 11846807 11638646 11628790 11695060 11492259 11767132 11366500 11485777 10942220 St.:ANNED SE? 1 8 2007 \ G\ q, ö1 \ '0- \£l-,o~ Date 08/17/07 08/13/07 08/15/07 08/25/07 08/14/07 08/17/07 08/17/07 08/22/07 08/23/07 08/24/07 08/21/07 08/19/07 08/16/07 08/16/07 08/18/07 06/28/07 08/24/07 OS/23/07 11/11/06 06/21/07 10/23/06 11/27/06 06/26/05 Log Description JEWELRY/SBHP HMI\.- J~4 -, 1-,(" MEM INJ PROFILE I )T": 1"'JC,_f")I< SBHPS/JEWELRY LOG 1'1f(,) -Os:<" PRODUCTION PROFILE I C) :l - D~,.cr LDL ,OJ''' 1_.' L PRODUCTION PROFILE I q 11 - tA '7- JEWELRY/SBHP }C 4- /J./I. LDL q"iÇ - l..J~ SBHP SURVEY .::)f'\?,- oq.q SBHP SURVEY ;U..{Z.. - II () PRODUCTION PROFILEIC¡'i( - DD'ð PRODUCTION PROFILE 'Cì~ - ~t./ SBHP/JEWELRY JO¡() - Qt.. SBHP/JEWELRY t~ - ft-.. ~ PRODUCTION PROFILE I~r - ()t1 ~ USIT :Jlì~ -0 SCMT dbr-07t5 RST ù".I:l'~ I""'~ -1;2..-:} ... t."'\' 14 ~ RST /C¡f>-1::J4"#. I<¿JI'+ MCNL ,Q(")'":J. -~~ ... I~J""" MCNL t:1 '1r - cn-4 ~ '# 1."'\.L. 1 C-) MCNL 1'1~ -()~... 1t I.<;LJQ./', MCNL:JoLf .:J:< ( it- I."\<'/::J I PLEASE ACKNOWLEDGE RECEIPT BY SI~!'I. ,.,.!N.,.....Ji~f\... '.'.~.'.. ~'.... ..... T. .~....",..".I'..G\¡p..'j NE COpy EACH TO: BP Exploration (Alaska) Inc. ~",,!{ ., iY"!; \G iI,,,,"' !'=) Petrotechnical Data Center LR2-1 IL" "..¿.,~,~, 900 E, Benson Blvd, Anchorage, Alaska 99508 StY 1. I! '>007 Date Delivered: .. ,.'," 1,'", ,C' P" (,()\1IJ¡¡b310n l\1;~JS~Ü~~ t ;11 ; ':~ \ J ;12,..(), . ,). BL NO. 4406 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9. "O~2~ ATTN: Beth 1.. Received by:C/L. -^----- 09/10/07 . . Problem Well Notification: 18-09B (PTD #1980790) Subject: Problem Well Notification: 18-098 (pm #1980790) From: "NSU, ADW Well [ntegrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 27 Aug 2004 20:38:38 -0800 To: "GPB, FSt DS Ops Lead" <GPBFSIDSOpsLcad@BP.com>, "GPB, FSt TL" <GPBFSITL@BP.com>, "OPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "AOGCCJim Regg (E~mail)" <jimJegg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)". <\Vinton_aubert@admin.state.ak.us>, "NSU; ADW WL & Completion Supervisor" . <NSUADWWL&CompletionSupcrvisor@BP.com>, "Schmoyer, AI" <SchrnoyAL@BP.com>, "GPB; Ops Mgr" <GPBOpsMgr@BP.co~> ... .. .. CC: "NSU, ADW Well Integrity Engineerll<NSUADWWell1ntegrityEngineer@BP~com>, "Olsen, Clark A" <OlseIiCA@BP.com>;"Mielke, Robert L." <robert.mielke@BP.com> . ~e1~ q)1 )o4f All, Well 18-09B (PTD #1980790) has sustained casing pressure on the IA and the well has been classified as a Problem well. The TIO's on 08/25/04 were 1200/1530/180. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED, FTS 2. FB: MITIA to 3000 psi, LLRT if fails 3. APE/WIC: Develop secure plan Attached is a wellbore schematic. Please call if you have any questions. «18-09B.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADí>!~~}lIntegr:!:.!Y~J?_g_tneer~!2P_. co!!,: Content-Description: t8-09B.pdf 18-09B.pdf. Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 911/20044:09 PM 1REE= 3-1/8" FMC \NELLH~D - FMC AClUA lOR = AXELSON KB. ELEV = 48' BF. ELEV = KOP= 1900' Max Angle - 94@12753' Datum WO = I>¥A Datum lVD = 8800' SS 10-3/4" COO, 45.5#, L-80/J-55, ID = 9.953" ESTTOC FROM IA SOl OF 12/11/99 Minimum ID = 1.941" @ 10598' TOP OF 2-318" 4.43# LINER TOP OF BKRTIEBACK SLV, ID= 5.75' 7-5/8" X 5-1/2" BKR LNR I£R,ID =4.875' 2.70" BKRDEPLOYWENT SLV,ID = 1.969" TOP OF 2-3/8" LNR, 4.43#, ID = 1.941" 3-1/2" TBG PC. 92#, L-80, .0087 bpf, D = 2.992" 10679' PERFORATION SUIl.tMRY REF LOG: CNL ON 09/12/92 ANGLEATTOP ÆRF: 83 @ 12030' Note: Refer to A"oduction DB for historical perf dam SIZE SPF INTERVAL Opn/Sqz [)II.1E 1-9/16" 6 12030 - 12095 0 04108102 1-9/16" 6 12130-12205 0 04108102 1-11/16" 4 12240 - 12305 0 07/27/98 1-11/16" 4 12595 - 12705 0 07/27/98 1-11/16" 4 12745- 12855 0 07/27/98 1-11/16" 4 12915- 13589 0 07/27/98 5-1/Z' LNR,17#, 13-CR-80, ID= 4.892" 12233' 18-09B . SAFETY NOTES: T1W HBBP PKRS REDUCED TEST PRESS. UMITS IN SOME CASES. CONTACTWIE (X51 02) PRIOR TO ANY PT WORK CMT SQZ HOLE IN 5-112" LNR@ 10623'. WB..LANGLE > 70° @ 11965' & > 90° @ 12262'. 5-1/2" CHROME LNR 2179' 3-1/2" CA 1RŒ'-2A 1RSV NP,ID=2.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH 1 3940 3522 47 OT-ME S/O T2 2 6817 5460 50 OT-ME DV T2 3 9119 6977 43 OT-ME DV RA 4 9274 7091 42 OT -ME OPEN OPEN 9296' 9349' 9372' 9425' PORT I)6.TE 20 01.1)9.1)0 0 09/23/99 0 09/15/92 CMf 12/11/99 3-1/Z' PARKERSV\IS NP, ID=2.813" 3-1/Z' PARKER SV\IS NP, ID = 2.813" 7-5/5' X 3-1/2"1lW HBBP A<R, ID= 3.00" 7-5/5' X 5-1/2" BAKERH A<R, ID=4.875" 7-518" COO SDTRK Vv1NDOW(18-09A) 9560'- 9620' (SECTION MLL) 10651' 10668' 5-1/Z' X 3-1/2" BAKERSABL-3 PKR, ID= 2.780" (BEHIND LNR) 3-1/2 PARKER SWN NIP, ID = 2.635" MLLED 10 2.780" (BEHIND LNR) 10680' 3-1/Z' \foJLEG (BEHND LNR) H ELWO1T(BEHNDLNR) I 5-1/2" LNR SurRK IMNDOW (18-09B) 11967'- 11971' (OFF CMT RAMI'} 2-3/5' LNR, 4.43#, FL4S, .0039 bpf, D = 1.941" DATE REV BY COMIVENTS [)II.TE REV BY COWMENTS 04/05/86 ORIGINAL COMPLETION 09/15/92 RIG SIDETRACK (18-O9A) 07/27/98 CTDSIDETRACK (18.o9B) 10/20/01 CH/KAK CORRECTIONS 04/08/02 JAF/tlh ADD PERFS 09/13/03 CMOITLP [)II. TLM WO/TVD& PERF ANGLE PRUa-tOE BA Y UNT WB.L: 18-09B ÆRMIT No: 1980790 APlNo: 50-029-21566-02 SEC 24, T11N, R14E, 486' FNL & 34Z FB. 8P Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Add Rerfs Pull tubing _ Alter casing _ Repair well _ .-~.,,:,. ~.:'.~', ;i ~l'ier...= . ~...:... .. :...,;;,,.;.:~.: 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __X Exploratory__ Stratigraphic.~ Service__ 4. Location of well at surface 486' FNL, 342' FEL, Sec. 24, T11N, R14E, UM At top of productive interval 4204' FNL, 1965' FEL, Sec. 14, T11N, R14E, UM At effective depth 2722' FNL, 2052' FEL, Sec. 14, T11N, R14E, UM At total depth 2570' FNL, 2060' FEL, Sec. 14, T11N, R14E, UM (asp's 691406, 5961373) (asp's 684466, 5962762) (asp's 684340, 5964241) (asp's 684328, 5964390) 6. Datum elevation (DF or RKB 48 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-09B 9. Permit number / approval number 198-079 10. APl number 50-029-21566-02 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 13636 feet Plugs (measured) 8694 feet Intermediate Slotted Liner Slotted Liner 13486 feet Junk (measured) 8693 feet PBTD tagged @ 13486' (07/27/1998) Length Size Cemented Measured Depth True Vertical Depth 110' 16" 1635# Poleset 158' 158' 2400 sx CS III & 400 sx 4603' 10-3/4" 4651' 4011' CS II 450 sx Class 'G' & 200 9512' 7-5/8" 9560' 7305' sx CS I 2549' 5-1/2" 365 cf Class 'G' 9417' - 11966' 8665' 3043' 2-3/8" 15 bbls of LARC 10581'- 13624' 8693' Perforation depth: measured Open Perfs 12030'- 12095', 12130'- 12205', 12240'- 12305', 12595'- 12705', Open Perfs (continued) 12745'- 12855', 12915'- 13589' true vertical Open Perfs 8678' - 8686', 8691' - 8698', 8698' - 8697', 8702' - 8696', Open Perfs (continued) 8694'- 8689', 8686'- 8693' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 PC-TBG @ 9349'. 3-1/2", 9.2# Tubing Tail (behind liner) @ 10680'. Packers & SSSV (type & measured depth) 7-5/8" x 3-1/2" TIW HBBP PKR @ 9349'. 7-5/8" x 5-1/2" BKR H PKR @ 9425'. 5-1/2" x 3-1/2" BKR SABL-3 PKR @ 10651'. 3-1/2" CA TRDP-2A TRSV Nipple @ 2179'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 04/11/2002 OiI-Bbl Shut-In 710 Representative Daily Averaqe Production or Injection Data Gas-Mcr Water-Bbl 20460 0 Casing Pressure Tubing Pressure 698 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil mX Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~,~~ ,~,~~~.,/ Title: Techical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date April 12, 2002 .Prepared by DeWayne R. Schnorr 564-5174~ SUBMIT IN DUPLICATE~ 18-09B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/17/2002 04/07/2002 04/08/2002 04/09/2002 PERFORATING: DRIFT/TAG PERFORATING: PERFORATING PERFORATING: PERFORATING PERFORATING: PERFORATING EVENT SUMMARY 03/17/O2 DRIFT W/1.69" X 10' DUMMY GUN TO 11394' SLM, STOPED DUE TO DEVIATION 0~0~02 MIRU CTU #3. KILL WELL. RIH AND DRIFT TO 12350'. RIH AND TIE IN LOG. ALL PERFS 1.56" 1602 PJ, 6 SPF, 60 DEG GUNS. RIH WITH GUN #1: SHOOT 12180' - 12205'. RIH WITH GUN #2. CONTINUED ON WSR 04/08/02. 04/08/02 CONTINUED FROM WSR 04/07/02. CONTINUE TO RIH WITH GUN #2: SHOOT 12155' - 12180'. ALL GUNS IN JOB ARE 1.56" HSD 1606 P J, 6 SPF, 60 DEG PHASE. POOH. RIH WITH GUN #3 SHOOT 12130'- 12155'. LOG TIE-IN 12200'- 11850'. RIH WITH GUN #4, SHOOT 12070' - 12095'. RIH WITH GUN #5, SHOOT 12050'- 12070'. CONTINUED ON WSR 04/09/02. O4/O9/O2 CONTINUED FROM WSR 4/8/02. POOH WITH GUN #5. CHANGE BRASS, PACK OFFS. RIH WITH WITH GUN #6: SHOOT 12030'- 12050'. ALL GUNS 1.56"-HSD- PJ1606-6SPF-60 DEG. INTERVAL'S PERFORATED <<< 12030'- 12095'/12130'- 12205' >>> ***NOTIFY DSO WELL IS READY TO POP*** FLUIDS PUMPED BBLS 0 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (0 TESTS) 10 [60/40 METHANOL WATER 88 DIESEL 2O KCL WATER 118 TOTAL ADD PERFS 04/07-09/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1.56" 1602 PJ 6SPF, 60 DEG PHASING, RANDOM ORIENTATION. 12030' - 12095' 12130' - 12205' Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~,~..,\¢, Commissioner ~'' ~.\~ ~' Tom Maunder, /~--~ ~V~ c~,~,~c~-~ P. I. Supervisor ~-(h- 0 k DATE: May 1, 2001 FROM' Lou Grimaidi, SUBJECT: Petroleum Inspector SVS Tests Misc. EOA Prudhoe Bay Field Tuesday, May 1, 2001; I witnessed four misc. SVS tests on BPX in the Eastern · _ Operating Area of the Prudhoe Bay Field. Bill Preston performed the SVS tests today. The test results (No Failures) are noted on the accompanied SVS test spreadsheets. Ali well houses were in "OK" condition. The pads were clean and in good condition. SUMMARY: I witnessed four misc. SVS tests in the Prudhoe Bay Field. 4 wells, 8 components, No failures. Attachments: SVS PBU DS-5 5-1-01 LG.XLS SVS PBU DS-2 5-1-01 LG.XLS SVS PBU DS-18 5-1-01 LG.XLS ..NON-CONFIDENTIAL SVS PBU EOA misc 5-1-01 LG1 AlaS-lin Oil and Gas Conservation CommiS~i~on Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: Prudhoe Bay, DS-2 Separator psi: LPS Date: 5/1/01 HPS 585 i ii i WeH Permit Separ Set L/P Test Test Test Date oa, wn~,c~J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCLE 02-0lB 1971400 02-02A 1971680 02-03A 1951780 02-04A 1961580 02-05 1700500 02-06A 1961380 02-07A 1981070 02-08B 1980950 02-09B 19710101 585 600 600 P P oIL ,, 02-10B 2000640 02-1lA 1981260 02-12A 1951650 02-13A 1941650 02-14 1800180 i02-15A 1960420 02'16A 1931160 , 02-17A 1961450 02-18A 1950890 02-19 1811860 02-20 1820290 02-21 1820450 , 02-22A 2000590 02-23A 2000530 02-24 1820710 02-25 1820960 ,, 02-26B 2001220 02-27A 1990930 02-28 1900220 02-29A 1900210 02-30B 2001260 02-31A 1990150 , , 02-33A 2001230 , 02-34A 1982380 ,,, 02-35A 1970960 02-36 1980700 ,, 02-37 1961750 ,,, 020~ 1/l~/l~l1961610 p~.. 1 ~¢. {:xgq DnlI hq_. q_l_al T ~ Well Permit Separ Set L/P Test Test Test Date o~i, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 02-39 1961820 ,, Wells: 1 Components: 2 Failures: 0 FailUre Rate: 0.00% [-! 90 ray Remarks: Cycle Well RJF 1/16/01 Page 2 of 2 SVS PBU DS-2 5-1-01 LG AlaSka Oil and Gas Conservation Commis~i~on Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/U~t~ad: Pmdhoe Bay,...D.S-5 Separator psi: LPS Date: 5/1/01 HPS 585 Well Permit Separ Set L/P Test Test Test Date oa, WAG, Gn~J, Number Number PSI PSI Tdp,. Code Code Code Passed fAs or CYCLE i05-01C 1990280 b5-02 1740360 ....... 05-03B 1941000 " , ,, i05-03C 2000940 05-04A 1960890 :05-05B 1961800 05-06A 1950840 585 600 600 P P 0IL 05.07 " 1770130 ' 05-08 1770240 :05-09A 1990140 05-10B 1961500 '05~l'lA 1960970 ..... 05-12A 1982600 ........ 05-13A 1940420 05-i4A 1930820 ..... 05-15B ' 1960230 " ' 05-16B 1991000 , 05-17B 1981040 05-18A 1981740 05-19 1890780 , I , , 05-20A 1971790 ," 05-22A 2001580 05-23 '1890790 , ,, 05-24 1911050 05-25B 2001470 1~91130 · . 05-26 , , . 05-27A 1961030 ,, , 05-28 1911100 05-30 1911150 0~-31A 19820~0 ............ 05-32 1910890 2000920 ' ' ' 05-33A 05-34 19112i0 05'-35 1~10680 05-36 1910780 585 660 500 P P OIL , 05o~ ~/~n/~11961850 Well Permit Separ. Set L/P Test Test Test Date oil, WAG, GINJ, Number Number PSI PSI Tri,'p Code. Code Code Passed ., ,GA~. or CYCLE 05-39 1961730 05-40 1961590 , 05-41 1961410 .. 4 Failures: 0 Failure Rate: 0.00% l-I ~0 oar Wells: 2 Components: _ Remarks: Cycle wells RJF 1/16/01 Page 2 of 2 SVS PBU DS-5 5-1-01 LG Ala/dm Oil and Gas Conservation Commis~i6n Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: ,Prud~,,o,e B,ay, DS- 18 Separator psi: LPS 160 Date: 5/1/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, G]iNJ, Number Number PSI PSI T....rip Code Code Code Passed GAS or CYCLE 18-01A 1960100 ..... 18-02A 1950300 18-03A 1941020 18-04A 1980280 ........ 18-05 1860800 18~06A - 1972470 .................. ,, ,,, , , , , , 18-07A 20001..4..0_ ............. 18-08A 1980040 18-09B '1980790 166 ' ' l'~b' 150 e " e .... 6IL 18-10A 1950600 18-1'lD 1870870 i8-'i2A " 1971230 ................. 18-13A ' 1972230 ......................... 18-14A 1950070 18-15B 1970720 18_16B ..... 19'70990 .......... 18-17 1871200 18-18A 1950140 18-19 1860940 1'8.50 1881410 ......... 18-51~k 1961~80 ......... 18-22~ 199'6500 ........... i'8-23S~ 1931410 ........... 18-24A 1950330 18-25A' 197098'6 ............................ 18-26A 1971940 18-27C 2001540 18-28 1950740 18-29B 1980690 18-30 19509i0 ..... 18-31 195109~) ............... ,i8_32 ,1951240 .................... i8-33 1951430 .......... 18-34 1951640 L2'_03A '1980620 .......... L2-07 1981650 L2~0~4/~ t;/~ 1981400 Well Permit Separ Set L/P Test Test Test Date c~, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L2-11 1980960 L2-13A 1980780 L2-18A 1981060 Wells: 1 Components: 2 Failures: 0 Failure Rate: 0.00% I-! ~o ~av Remarks: Cycle well RJF 1/16/01 Page 2 of 2 SVS PBU DS-18 5-1-01 LG Well ComPliance Report File on Left side of folder 198-079-0 PRUDHOE BAY UNIT 18-09B 50- 029-21566-02 BP EXPLORATION (ALASK A \ l~l/~" MD 13636 -~ TVD 08694 - Completion Date: '~'~7/98 Completed Status: 1-OIL Current: Microfilm Roll / Roll 2 / Name D 8874 L GR-MD L GR-TVD L LEAK-SPIN/TEM/ L MNCL R SRVY LSTNG R SRVY LSTNG T 8652 Daily Well Was the well cored? yes Comments: lnte~al Sent Received T/C/D GR ....................... OH 12/30/98 1/11/99 ~I~AL 11971-13636 "~/~[~--~379t~ OH 12/30/98 1/11/99 (~A4~7(L 8620-8645 qr' OH 12/30/98 1/11/99 ~NAL PRES 100-9360.~8/19/99 CH 5 8/26/99 8/26/99 ~NAL 10504-13604 ~/.~ ~' ~ CH 2 10/28/98 10/29/98 BH! 11925.2-13606. OH 8/25/98 8/26/98 ~i925.20-13636. OH 9/3/98 9/3/98 j SCHLUM MNCL CH 10/28/98 10/29/98 Are Dry Ditch Samples Required? yes (~.~And Received? Analysis Description Received? -_L e~et # Tuesday, August 01, 2000 Page 1 of 1 STATE OF ALASKA ...... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate_ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 48 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic~ Anchorage, AK 99510-0360 service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 486' FNL, 342' FEL, Sec. 24, T11N, R14E, UM 18-09B At top of productive interval 9. Permit number / approval number 4204' FNL, 1965' FEL, Sec. 14, T11N, R14E, UM 198-079/399-204 At effective depth 10. APl number 50-029-21566-02 At total depth 11. Field / Pool 2570' FNL, 2060' FEL, Sec. 14, T11N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summit Total depth: measured 13636 feet Plugs (measured) PBTD tagged @ 13486' MD (7/27/1998' true vertical 8694 feet Effective depth: measured 13607 feet Junk(measured) true vertical 8693 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 1 6" 1635# Poleset 110' 110' Surface 4603' 10-3/4" 2400 Sx CS III & 400 Sx CS II 4651' 4011' Production 9512' 7-5/8" 450 Sx C~ass G & 20O Sx CS ~ 9560' 7305' Liner 2549' 5-1/2" 365 cubic It Class G 11966' 8665' Liner 3043' 2-3/8" 15 bbls o115.8 ppg I_ARC 13624' 8693' Perforation depth: measured 12240' - 12305'; 12595' - 12705'; 12745' - 12855'; 12915' - 13589'. ~j~_,~"~' ~.~'~ ,em ~!! '~! ~-~ ~ ~ ~ F-' ~-.?~%' true vertical 8698' - 8697'; 8702' - 8696'; 8694' - 8689'; 8686' - 8693'. ~: -, ,,~ r ~ ..;.,~ Tubing (size, grade, & measured depth) 3-1/2", 9.2#, L-80 PC Tubing @ 10680' MD. Packers and SSSV (~pe & measured depth) 7-5/8" X 3-1/2" TIW HBBP Packer ~ 9349' MD; 5-1/2" X 3-1/2" Baker SABL-3 Packer (behind liner) ~ 10651~D. 3-1/2" CA ~DP-~-SSA SSSV Nipple ~ 2179' MD. 13. Stimulation or cement squeeze summa~ Inte~als treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pre.ute Prior to well operation (shut in) Subsequent to operation 100 1860 935 - 525 15. A~achments 16. Status of well classification as: Copies of Logs and Su~eys run ~ Daily Report of Well Operations ~ Oil __X Gas ~ Suspended ~ Se~i~ 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~ ~~ Title Arco Engineering Supe~isor Date Erin 0~ Pre~ed by Pau/ Rauf 263-~90 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 18-09B -~- DESCRIPTION OF WORK COMPLETED GEL/CEMENT CRETACEOUS SQUEEZE Date Event Summary 10/24/1999: 11/25/1999: 11/26/1999: 12/07/1999: 12/08/1999: 1 2/10/1999 - 12/11/1999: 1 2/19/1999: 1 2/26/1999: 12/27/1999: 12/28/1999: RIH & set IBP @ 9355' to isolate the perforation zones listed below: 12240'- 12305' MD (Zone lB) 12745' - 12855' MD (Zone lB) 12595'- 12705' MD (Zone lB) 12915' - 13589' MD (Zone lB) MIT Tubing to 2000 psi - passed. RIH & pulled GLM#4. Left station 4 empty. MIRU CTU. PT'd equip. RIH & tagged IBP. Pumped a gelled slurry containing 400 lbs of 20/40 mesh Sand ontop the IBP to 9302' ELM. POOH. Tbg & IA are liquid packed w/Crude to surface. Set EZSV Cement Retainer @ 9,250'. PT'D Tbg / EZSV To 2200 psi---passed. Performed a CT Maraseal Gel/Cement Squeeze for the purpose of plugging up a Cretaceous leak. Diagnostic work indicated Cretaceous leak is located in the casing @ 7170'. MIRU CTU. PT'd equip to 4000 psi. RIH w/CT stinger & stung into EZSV. Established circulation through #4 GLM. Pumped 292 bbls of Maraseal Gel. Swapped over to pumping 135 bbls of 15.6 ppg Latex Acid Resistive Cement. 10 bbls of Cement squeezed behind pipe & 124 bbls of Cement layed in IA to estimated 5700'. Unstung f/EZSV & laid in 1 bbl of Cement ontop of retainer. POOH w/CT. RD. RIH & tagged TOC @ 8936' SLM. MIRU CTU. PT'd equip. RIH & milled Cement to 9261'. Milled EZSV to 9263'. POOH. RIH & milled through EZSV. Milled Cement to 9310' (sand/Cement interface). FCO'd to 9325'. PUH to 8850'. PT'd IA to 2000 psi - passed. Pumped Biozan sweep. Attempted to POOH but BHA hung up in GLM#4. Dropped ball & disconnected f/BHA. FP'd well. Stand back for night. RIH & latched fish. POOH w/BHA fish. RIH & performed FCO to IBP. Latched IBP & pulled it from wellbore. Suspect rubber elements left in wellbore. 12/29/1999 - Operations on hold due to weather. 1/01/2000: 1/09/2000: Fished IBP rubber elements f/9366'. Also fished out metal slips f/EZSV. Cleaned up tight spots f/9061' - 9370'. Returned well to production & obtained a valid welltest. 1/10/2000: RECEIVED 2 1 000 AlaS~ 0il & Gas C~ns. C~sstm~ Anchorage STATE OF ALASKA ,_ .? ALAsKA-- OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 48 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 486' FNL, 342' FEL, Sec. 24, T11 N, R14E, UM 18-09B At top of productive interval 9. Permit number / approval number 4204' FNL, 1965' FEL, Sec. 14, T11N, R14E, UM 98-79 At effective depth 10. APl number 50-029-21566-02 At total depth 11. Field / Pool 2570' FNL, 2060' FEL, Sec. 14, T11 N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13636 feet Plugs (measured) PBTD tagged @ 13607' MD (7/27/1998) true vertical 8694 feet measured 13607 feet Junk(measured) ORiGiNAL, Effective depth: true vertical 8693 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 16" 1635# Poleset 110' 110' Surface 4603' 10-3/4" 2400 Sx cs ~ & 40o sx CS ~ 4651' 401 1' i Production ;~'~' %,,~-_ A 7-5/8" 45o SxClass G & 200 Sx CS I ~ ~'(3 (,~ ~' Liner 2549'~'~3'~I'V? 5-1/2' 365 cubic ft Class G 11966' ,~.~,*W'~. 8665' Liner 3043' ~l ~-i 2-3/8" 15 bbls of 15.8 ppg LARC 13624' I~ j ~,, 8693' Perforation depth: measured true vertical 8698'-8697';OCT 1' 1 Tubing (size, grade, and measured depth 3-1/2', 9.2#, L-80 PC Tubing @ 10680' MD. Anchorage Packers & SSSV (type & measured depth) 7-5/8" X 3-1/2" TIW HBBP Packer @ 9349' MD; 5-1/2' X 3-1/2" Baker SABL-3 Packer (behind liner) @ 10651' MD. 3-1/2" CA TRDP-2A-SSA SSSV Nipple @ 2179' MD. 13. Attachments Description summary of proposal __X Detailed operations program__ BOP sketch .._X 14. Estimated date for commencing operation 15. Status of well classification as: October 15, 1999 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Niznik @ 263-4561. FOR COMMISSION USE ONLY Conditions of approval: P,ugN°tifY, n,eg,~C;~mmissi°n_ so representatiVe, Op Test __-V' may witneSS, o~.t~, c~e,,rance __,I Approv,~ no.Z ? ?...1 ~ "/ Mechanical Integrity Test ..-..,- Subsequent form required 10- L~ {~ ;;)RIGINAL SIGNED Approved by order of the Commission ~_n_bert N. (~i'iSt. E~r~$orl Commissi.oner Date / -",.,/' Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 18-09B Gel/Cement Casing Squeeze Primary Objective Note: Primary objective is pump Maraseal Gel and LARC cement into a casing leak at 7170' MD. LARC cement will then be brought up the tubing x inner annulus to eliminate annular communication caused by the casing leak. , RU Slickline and drift / tag. Dummy off GLM's #1-3. Pull the valve from GLM # 4 (9274' MD), gel/cement will be pumped through this valve. RD Slickline 2. RU E-Line and set IBP at 9372' MD. RD E-Line , RU CTU. Fluid pack well and lay in sand plug to 9290' MD. Set an EZSV retainer at 9250' MD. Shut the IA and pump 300 bbls Maraseal gel followed by 84 bbls LARC cement into the casing leak at 7170'. Open the IA and pump 57 bbl of LARC cement to bring the cement top up to 5500' MD. GLM #1 at 3940' will be available for gas lift in the future. 4. Wait on cement 3 days. Pressure test tubing, and inner annulus. 5. MilI/FCO to IBP. Pull IBP 6. Return well to production. DS 1L~gB Gel/Cement Cretaceous ~'ueeze 7-5/8" Production Casing 29.7# @ 9560' MD 5-1/2" Liner 17.0# Volume: 3-1/2" = 0.0087 bbls/ft 3-1/2" x 7-5/8" = 0.034 bbls/ft GLM1 394O' MD. 3-1/2" 9.2# t-80 PC Tubing Surface' - 10680' MD 5500' MD Estimated TOC 15.8 ppg I_ARC GLM2 6817' MD. 7170' MD Casing Leak GLM3 9119' MD. GLM4 9274' MD. 7-5/8" X 3-1/2" TIW HBBP Packer @ 9349' MD 5-1/2" X 3-1/2" Baker SABL-3 Packer @ 10651' MD *Note* 300 bbls of Maraseal Gel and 10 bbls of LARC willl be pumped into the Cretaceous leak @ 7170' MD. pcr 10/08/1999 '6 5 4 .3 2 2 1 C01LED TUB'IN~ 'UNIT 1. 5000 PSI' ?" WELLHEAD CONNECIOR FLANGE 2. 50c]'0'PSI 4 1/16" PIPE FL,~S .. - 3. ~000 'PS~ 4, ~/e" m'D~UL~C SL 4:5000 PSI 4 1/6" SHEAR' RAMS 5. 5OO0'PS~ 4 1/6" BL~ND RAMS PSI 4 1/16" 'STUIrrlI~ BOX H ] R£L ] NE _BOP .EOU] PHE.'.NT 1. SOO0 PSi ?" .WELLHEAD CONNEC1OR' FLAN 2. SOD0 PS! W~RELIN[ RAUS'(VARIABL[. SIZE) 3. 5000 PSI 4 !/6" LUBRICAIOR 4. 5000 PS~ 4 ~/6,, Ir.LOW lUBE PACK-OFF Tubing-PC Casing Casing WSSSV NIP PKR NIP Sidetrack Window .....9_./J.~Lgg ....................................... Liner Liner PKR NIP TTL 11971' 5-1/2 Sidetrack Window .Z!;?7/~.~ ................................... Perf ...... ' .... Perf ..... -- Perf ----'" OTHER TTL 18-09B APl: 500292156602 Well Type: PROD RKB: 48 ft H2S: Spud: 7/15/98 KOP: 0.00 ftKB SSSYType: OrigCompltn: 7/27/98 PBTD: 13636.00ftKB Annular Fluid: Last W/O: 7/27/98 TD: 13636.00 ftKB Reference Log: Ref Log Date: Max Hole Angle: 94 deg @ 12753 Last Tag: Last Tag Date: Angle @ TS: deg @ Rev Reason: Perf Data Last Update: 12/22/98 Angle ~ TD: 89 deg @ 13636 ID~Pth Ahnotation$!i: :::: :: Depth Comment (ftKB) 9560.00 9560'-9610' 7-5/8 Sidetrack Window 9/15/92 10593.00 10593' Minimum ID=1.969 2-7~8 Deployment Sleeve 11971.00 11971' 5-1/2 Sidetrack Window 7~27~98 Date Note 1/9/93 Fmc 1/9/93 Hole in 5-1/2 Liner @ 10623'; sqz'd FHL/TIW HBBP Packers have reduced test pressure limits in some cases. Contact PWS (x5102) pdor to pressure testing. IGeneralNotes: :~::::::i:: ::: : Date Note 7/27/98 CTD Sidetrack Completion 7/27/98 ELM Tubing Tail (not logged) I Other (~lugsi equiP:~ etc,) -JEWERLY Depth ID 2179 2.810 9296 2.810 9349 0.000 9372 2.810 10593 1.970 10651 0.000 10668 2.630 10680 0.000 13603 1.000 13634 0:000 Type Description WSSSV 3-1/2 CA TRDP-2A-SSA SSV Nipple ID=2.812 NIP 3-1/2 Parker SWS Nipple ID=2.813 PKR 7-5/8 X 3-1/2 TIW HBBP Packer NIP 3-1/2 Parker SWS Nipple ID=2.813 OTHER 2-7/8 Deployment Sleeve ID=1.969 PKR 5-1/2 X 3-1/2 Baker SABL-3 Packer (behind liner) NIP 3-1/2 Parker SWN Nipple ID=2.635 (behind liner) 'l-rL 3-1/2 Tubing Tail W/L Re-entry Guide (behind liner) OTHER 2-3/8 Baker O Ring Sub ID=I.0 'ITL 2-3/8 Baker Float Shoe ICaSing Strings -AIl: :: :: ' Size Description Top Btm Weight Grade 10.750 Casing 0 4651 45.50 L-80/J55 7.630 Casing 0 9560 29.70 L-80 5.500 Liner 9417 11971 17.00 13CR80 2.375 Liner 10593 13634 4.43 FL45 ITUbingStHngS-AII : : Size Description Top Btm Weight Grade 3.500 Tubinq-PC 0 10680 9.20 L-80 Vlv I OasLift:Mandrels/Vaives : Stn MD Man Man Type : Vlv VIv VIv Latch VIv VIv VIv Run Mfr Mfr OD Type Port TRO (in) 1 3940 OT ME CA 1.500 GLV T2 0.000 0.0 8/2/98 2 6817 OT ME CA 1.500 GLV T2 0.250 0.0 8~3/98 3 9119 OT ME TE1,500 DMY RRA 0.000 0.0 9/15/92 4 9274 OT ME CA 1.500 OV T2 0.310 0.0 8/3/98 I pe~6rations:: summary, :: Statut Comment May have trash in it (8/3/98) Interval Zone Feet SPF Date Type 12240 - 12305 O 65 4 7/27/98 IPERF 12595 - 12705 O 110 4 7~27~98 IPERF 12745 - 12855 O 110 4 7/27/98 IPERF 12915 - 13589 O 674 4 7/27~98 IPERF Comment Schlumberger NO. 12787 8/26/99 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD 14-41~- ~t_~? 99314 RST 990811 I I 1 D.S. D.S. 3-28 PRODUCTION PROFILE W/DEFT 990816 I 1 D.S. 4-01 PRODUCTION PROFILE W/DEFT 990815 I 1 D.S. 6-22A LEAK DETECTION LOG 990820 I 1 D.S. 9-24 PRODUCTION PROFILE 990817 I 1 D,S. 9-41 PRODUCTION PROFILE 990817 1 1 D.S, 9-47 PRODUCTION PROFILE 990822 I 1 D.S. 18-09B LEAK DETECTION LOG 990819 1 1 ., . · , ~ . _._~ ~ 7o. oL/~ q.~ .o'75 SIG DATE: Aja,3~.aOii ' ' ...... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 7260 Homer Ddve, Anchorage, AK 99518 TEQ State of Alaska AOGCC Lod Taylor 3001 Porcupine St. Anchorage, AK 99501 Dear Data Distribution Recipient: Janua~ 28,1999 This letter is intended to correct Well Header Information for a Gamma Ray log distributed recently. The Gamma Ray in question was logged by Baker Hughes INTEQ' MWD on Well 18-09B, Prudhoe Bay Unit, North Slope, Alaska for ARCO Alaska, Inc. This log was acquired from 09 Jul 1998 through 23 Jul 1998. The information that need to be corrected is the APl Number, which was reported as 500292156601. The APl Number should be corrected to 500292156602. Thank you. Sincerely, Brij Potnis Technical Support Engineer RECEIVED ARCO Alaska Inc. AOGCC, Lori Taylor Well Reference Data: Well No: 18-09B Field: Prudhoe Bay Unit County: North Slope State: Alaska Date: 12/30/98 API No: 500292156602 BHI Job#: 99488 Enclosed is the following data as listed below: Log Type Bluelines Navig~mma BDEN MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navig~mma BDEN MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tapes LIS Verification Listings Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Received by: ~ ~ Date GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12003 Companl Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 10/28/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 2-15A 98517 RST-A SIGMA MODE & BORAX-~. ~. 980605 2 2 1 D.S. 14-16A 98544 RST-SIGMA ~r Oo~ '~ 980628 1 I 1 D.S. 14-37 98538 RST-A SIGMA ~ ~p~) 981007 1 I I D.S. 15-40A 98533 MCNL ~, ~o(g~ ~o 980826 1 I 1 D.S. 18-09B 98536 MCNL '1~ [~9,~ 980725 1 I 1 SiGNEE~~~' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank yoL - ~ STATE OFALASKA ALA~' OIL AND GAS CONSERVATION COMIV, .ION oilt~G~C~/~/_~/~ WELL COMPLETION OR RECOMPLETION REPORT AND L 1 Status of Well Classification of Ser~.~.~f~l Oil_X Gas__ Suspended__ Abandoned__ Service__ ,4./.~_~:._ . 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 98-79 P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21566-02 4 Lo~tion of well at su~a~ ~ ~;~ ;~ ~.~.?.,.~.~..: ~ ~~ 9 Unit or Lease Name 486' SNL, 342' WEL, Sec 24, T11N, R14E, UM , .............. ~,, J'~~ ~ PRUDHOE BAY UNIT At Top Producing inte~al ~~~ 10 Well Number At Total Depth~~---~ ~,~ ; ~~~ ...... 18-09B 11 Field and Pool UM. :' ..U HO. 5 Elevation in feet (indi~te KB, DF, etc.) 6 Lease Designation and Serial No. 48' RKB ADL 28307 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 7/15/98 7/24/98 7127198 N/A 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of Permafrost 13636' MD / 8694' WD 13607' MD / 8693' ~D YES~ NO_ 2179' MD 1900' (approx) 22 Type Electric or Other Logs Run CNUG~CCL, MWD 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH CASING SIZE ~. PER FT. G~DE TOP BOSOM HOLE SIZE CEMENTING RECORD AMT PULLED 16" 109~ Weld Su~a~ 110' 20" 1635~ Poleset 10-3/4" 45.5~ J55/L-80 Su~a~ 4651' 13-1/2" 2400 Sx CS III & 400 Sx CS II 7-5/8" 29.7~ L-80 Su~a~ 10524' 9-7/8" 450 Sx Class G & 200 Sx CS I 5-1/2" 17~ 13CR-80 9417' 11966' 6-3/4" 365 Ft~ Class G 2-3/8" 4.43~ L-80 10581' 13624' 3" 15 bbls of 15.8 ppg ~RC Cement 24 Pedoralions open to Produciion (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET MD PACKER MD 3-1/2" PC Tbg 10680' 9349' 12240' - 12305' MD; 8698' - 8697' ~D; I 12595' - 12705' MD; 8702'- 8696' ~D; ~ 4 spf. 12745'- 12855' MD; 8694'- 8689' ~D; ~ 4 spf. 26 ACID, F~CTURE, CEMENT SQUEEZE, ETC. 12915' - 13589' MD; 8686' - 8693' ~D; ~ 4 spf. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 8/1/98 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE ~ GOR 816198 3.0 TEST PERIOD ~~ 5717 Flow Tubing Press Casing Pressure CALCU~TED OIL - BBL GAS - MCF WATER - BBL OIL G~VI~ - APl (~rr) 560 24 HOUR ~TE ~ 3536 20215 39 128 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presen~ of oil, gas, or water. Submit ~re chips. * This 10-407 is submitted as directed per the 10-401 form approved 5/13/98 (Permit ~ 98-79). Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Top Sadlerochit other pics) GEOLOGIC MARKERS MEAS DEPTH 10925' 11160' TRUE VERT DEPTH 8177' 8287' FORMATION TESTS nclude interval tested, pressure data, and fluids recovered and gravity, 3OR, and time of each phase. 31 LIST OF ATTACHMENTS Summary of 18-09B CT Sidetrack Drilling Operations + Survey. 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Erin Oba INSTRUCTIONS Prepared by Paul Rauf 263-4990 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Rev. 7-1-80 '18-09B uESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 7~09~98: MIRU CTU. Full tested BOPE. 7110198: RIH w/BHA & milled out SWN nipple @ 10668' MD. Tagged TOC @ 11907' MD & POOH. 7/11198: MWD problems. RIH w/BHA & tagged 11937' MD (corrected). Oriented BHA for pilot hole drilling. 7/12~98: Milled pilot hole f/11937' to 11958' & POOH. RIH w/BHA & reamed pilot hole. POOH w/BHA. RIH & began window milling operations @ 11966' on the 5-1/2" chrome liner. 7113198: Milled to 11968'. POOH. RIH w/BHA & MWD failed. POOH to troubleshoot MWD. RIH w/BHA. 7/14/98: Milled SWN nipple & pilot hole. POOH. RIH & tagged BTM @ 11968'. Orienterjammed. POOH. RIH w/BHA. 7/15~98: POOH w/BHA. RIH w/window milling BHA & tagged BTM. Time milled on window until orienter quit working. POOH. Began BOPE testing. 7/16/98: Finished BOPE test. S/B waiting on new mill assembly. RIH w/BHA. Milled window f/11967.5' to 11971.2'. 7117/98: Milled window from f/11971.2' to 11972'. POOH. Performed LOT to ensure casing exit. Twice RIH / POOH due to MWD problems. 7/18/98: RIH & milled window f/11966' to 11974'. Milled to 11977'. POOH. RIH & motor locked up. POOH. RIH w/BHA. 7/19/98: POOH w/BHA. RIH & backreamed f/11980' to 11965' MD 3 times at different orientations. POOH. RIH w/bi- centered bit. 7~20~98: Drilled to 11994' & CT stuck. Pumped FIo Pro pill & freed pipe. Swapped hole to FIo Pro. Performed LOT to EMWof9.1 ppg. Drilled ahead to 12196'. POOH. RIH & drilled f/12196' to 12315'. 7/21/98: Drilled to 12360' with short trips to window. Reamed/backreamed hole to BTM. Drilled ahead to 12700'. 7~22~98: Reamed out hole f/12320' to 12380' multiple times. Drilled to 13015' & CT stuck. Pumped Crude & freed pipe. Short trip to window & reamed hole @ 12300'. Drilled forward to 13204'. Page 1 18-09B uESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 7~23~98: Drilled to 13590' w/short trips to window & lost returns. 7~24~98: Drilled ahead to TD @ 13636' MD. Spotted clean FIo Pro pill Ex POOH. PT'd BOPE. M/U 2-3/8" FL4S liner. 7~25~98: RIH w/liner assmebly & landed it @ 13624'. Pumped 18 bbls of 15.8 ppg LARC Cement to cement liner (15 bbls of cmt behind pipe). Estimated TOC @ 11745'. Unstung stinger from flapper valve & circulated Biozan to cleanout liner. POOH. WOC. 7126198: RIH w/memory logging tools & ran CNL/GR/CCL logs f/10500' to 13624' MD. Lay in LSRV mud pill. POOH. PT'd liner lap. 7~27~98: RIH w/perforating guns & tagged PBTD @ 13607'. Shot 959' of initial perforations located @: 12240'- 12305' MD (Z1B) 12595'- 12705' MD (Z1B) 12745'- 12855' MD (Z1B) 12915'-13589'MD (Z1B) Used 1-11/16" carriers & shot all perfs @ 4 SPF. POOH w/guns. Noted all guns fired & all shots fired. 7~28~98: RIH & freeze protected well. POOH. RDMOL. Placed well on initial production & obtained a valid well test. Page 2 ARCO Alaska, Inc. D.S. 18 18-09~ 18-09 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 18-09B Our ref : svy95 License :API 500292156602 Date printed : 2-Sep-98 Date created : 20-Jul-98 Last revised : 1-Sep-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 56.533,w148 26 59.115 Slot Grid coordinates are N 5961373.000, E 691406.220 Slot local coordinates are 486.30 S 341.96 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. SURVEY LISTING Page 1 D.S. 18,18-09 Your ref : 18-09B Prudhoe Bay, North Slope, Alaska Last revised : 1-Sep-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 11925.20 65.61 302.58 8601.27 1557.45N 6894,78W 3.90 0.00 684474.35 5962753.93 11959.00 67.10 302.00 8614.83 1573,99N 6920.95W 4.68 18.80 684447.77 5962769.80 11978.00 76.00 309.00 8620.84 1584.46N 6935.58W 58.41 30.53 684432.87 59627-/9.89 12004.00 80.00 316.20 8626.25 1601.67N 6954,28W 31.15 49.33 684413.75 5962796.61 12029.00 82.50 317.90 8630.05 1619.75N 6971,11W 12.05 68.83 684396.46 5962814.26 12062.00 83.00 327.00 8634.23 1645.68N 6991.04W 27.40 96.43 684375.88 5962839.67 12105.00 83.40 336.40 8639.33 1683.23N 7011.26W 21.73 135.63 684354.71 5962876.69 12123.00 81.70 342.50 8641.67 1699.93N 7017.52W 34.90 152.82 684348.02 5962893.23 12157.00 81.00 344.90 8646.78 1732.19N 7026.95W 7.28 185.79 684337.77 5962925.23 12186.00 87.30 342.60 8649.74 1759.87N 7035.02W 23.11 214.07 684328.99 5962952.70 12221.00 89.90 344.00 8650.59 1793.38N 7045.08W 8.44 248.35 684318.09 5962985.94 12262.00 91.00 346.90 8650.27 1833.06N 7055,38W 7.56 288.78 684306.78 5963025.34 12296.00 91.70 348.40 8649.47 1866.26N 7062.65W 4.87 322.50 684298.67 5963058.34 12350.00 91.80 354.00 8647.82 1919.58N 7070,90W 10.37 376.34 684289.06 5963111.43 12385.00 89.60 354.90 8647.39 1954.41N 7074,28W 6.79 411.33 684284.78 5963146.16 12434.00 86.90 353.00 8648.89 2003.11N 7079.45W 6.74 460.30 684278.38 5963194.71 12471.00 87.70 356.40 8650.63 2039.91N 7082.86W 9.43 497.25 684274.03 5963231.40 12499.00 87.00 358.10 8651.92 2067.84N 7084,20W 6.56 525.20 684271.98 5963259.29 12532.00 87.70 0.00 8653.45 2100.80N 7084,75W 6.13 558.07 684270.59 5963292.23 12566.00 89.90 0.10 8654.16 2134.79N 7084.72W 6.48 591.93 684269.75 5963326.20 12600.00 92.00 1.70 8653.60 2168.78N 7084,18W 7.76 625.73 684269.42 5963360.19 12653.00 93.20 1.60 8651.19 2221.70N 7082,66W 2.27 678.31 684269.59 5963413.13 12700.00 93.50 1.80 8648.45 2268.60N 7081,2714 0.77 724.90 684269.79 5963460.05 12753.00 93.70 3.80 8645.12 2321.43N 7078.68W 3.78 777.29 684271.02 5963512.93 12798.00 91.70 7.60 8643.00 2366.15N 7074,22W 9.53 821.44 684274.34 5963557.74 12852.00 92.70 8.70 8640.93 2419.56N 7066,5714 2.75 873.96 684280.63 5963611.33 12889.00 93.50 11.10 8638.92 2455.96N 7060.22W 6.83 909.64 684286.05 5963647.87 12949.00 92.60 13.60 8635.73 2514.48N 7047,40W 4.42 966.80 684297.36 5963706.70 13013.00 90.50 13.50 8634.00 2576.67N 7032,42W 3.28 1027.41 684310.76 5963769.25 13040.00 88.50 10.00 8634.24 2603.10N 7026.92W 14.93 1053.25 684315.58 5963795.81 13080.00 87.10 10.70 8635.77 2642.42N 7019,74W 3.91 1091.78 684321.76 5963835.29 13121.00 88.50 7.40 8637.35 2682.87N 7013,29W 8.74 1131.50 684327.16 5963875.89 13158.00 88.30 5.00 8638.38 2719.64N 7009,30W 6.51 1167.76 684330.22 5963912.75 13188.00 87.90 3.40 8639.37 2749.54N 7007,10W 5.49 1197.35 684331.65 5963942.70 13230.00 89.10 3.10 8640.47 2791.46N 7004,72~ 2.95 1238.89 684332.96 5963984,66 13271.00 89.10 359.00 8641,12 2832.44N 7003.97W 10.00 1279.64 684332.66 5964025.64 13335.00 89.20 5.50 8642.07 2896.35N 7001,46W 10.16 1343.08 684333.54 5964089.59 13379.00 88.60 4.70 8642.91 2940.16N 6997,55W 2.27 1386.38 684336.34 5964133.49 13420.00 88.30 4.40 8644.02 2981.02N 6994,30W 1.03 1426.78 684338.54 5964174.41 13465.00 89.80 1.40 8644.7-/ 3025.95N 6992.02W 7.45 1471.33 684339.67 5964219.38 13491.00 91.90 1.50 8644.38 3051.94N 6991.37W 8.09 1497.16 684339.67 5964245.38 13529.00 89.90 0.00 8643.79 3089.92N 6990,8714 6,58 1534.95 684339.19 5964283.36 13570.00 88.80 354.30 8644.25 3130.85N 6992,91W 14.16 1575.90 684336.11 5964324.23 13606.00 89.00 355.00 8644.94 3166.69N 6996.26W 2.02 1611.89 684331.84 5964359.96 13636.00 89.00 355.00 8645.47 3196.57N 6998,88W 0.00 1641.89 684328.47 5964389.77 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 18-09 and TVD from Mean Sea Level - rkb 48ft. Bottom hole distance is 7694.31 on azimuth 294.55 degrees from wellhead. Vertical section is from tie at N 1557,45 g 6894.78 on azimuth 354.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 18,18-09 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-09B Last revised : 1-Sep-98 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 18~09ehs 8655.00 3253.02N 7045.93~ 20-Jul-98 18-09bhs 8665.00 2006.57N 7007.71~ 20-Jul-98 AI CO Alaska, Iz c. Structure · D.S. 18 Field · Prudhoe Bay Well · 18-09 Location ' North Slope, Alaska <- West (feet) 7800 7650 7500 7,350 7200 7050 6900 6750 6600 6450 I I I I I I I I I I I I I I I I I I I I T.O. & End of Build - 8655,00 Tvd, 3253.02 N, 7045.93 W 18-09ehs 7950 18-09bhs 8100 1557 Tie on - 8601.27 Tvd .... 1 8-09ehs 8400 ~ 8550 ~ Tie on - 65.61 Inc, 11925.20 Md, 8601.27 Tvd, 0.00 Vs 8700 1 8-09bhs I--- ~1 T.D. & End of Build/Turn - 90.67 Inc, 13687.45 Md, 8655.00 Tvd, 1702.29 Vs I v 8850 9000 ] I I I I I I I I I I i I I I I I I t I I I I I I I I I I I I I I I I I I I -'-1 450 300 150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 Vertical Section (feet) -> Azimuth :354.91 with reference 1557.45 N, 6894.78 W from 18-09 3300 3150 3000 2850 27OO 2550 2400 Z 0 -,+. 2250 2100 1950 1800 1650 1500 1350 1200 TONY KNOWLE$, GOVERNOR ALASI & OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 o3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May13,1998 Erin M. Oba Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK. 99510-0360 Re; Prudhoe Bay Unit 18-09B ARCO Alaska, Inc. Permit No. 98-79 Sur. Loc. 486'FNL, 342'FEL, Sec. 24, T1 iN, R14E, UM Btmnhole Loc. 2762'FSL, 2108'FEL, Sec. 14, T11N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of. Work Drill_ Redrill ~ I lb. Type of Well Exploratory_ StratigraphicTest Development Oil X Re-Entry__ Deepen -I Service_ Development Gas_ Single Zone X Multiple Zone 2. Name ol Operator 5.Daium Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 48' 3. Address 6. Properly Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28307 Prudhoe Bay Oil Pool 14. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 486' FNL, 342' FEL, Sec 24, T11N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 720' NSL, 1417'WEL, Sec 14, T11N, R14E, UM 18-09B #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2762' FSL, 2108' FEL, Sec 14, T11N, R14E, UM May, 1998 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and -i'VD) property line I No Close Approach 13672' MD / 8713' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 11947' MD Maximum hole angle 90° Maximum surface 3500 psi9 At total depth (TVD) 8800' 18. Casing program Setting Depth Size Specification Top Boltom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2-3/4" 2-3/8" 4.7# L-80 FL4S 3072' 10600' 7978' 13672' 8713' 15 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. .~ Present well condition summary Total depth: measured 12240 feet Plugs(measured)APR · 1598 true vertical 8740 feet Effective depth: measured 12204 feet Junk (measured)^____ , ~ .... true vertical 8731 feet Casing Length Size Cemented Measured depth True Vertical depth ConduCtor 110' 16" 1635 # Poleset 110' 110' Surface 4583' 10-3/48" 2400 Sx CS III & 400 Sx CS II 4651' 4011' Production 9492' 7-5/8" 450 Sx Class G & 200 CS I 9560' 7305' Liner 2816 5-1/2' 365 Cu Ft Class G 12233" 8738' Perforation depth: measured 12120 - 12200' true vertical 8721 - 8748' 20. Attachments Filing lee _~X Property plat _ BOP Sketch ~ Diverter Sketch _ Drilling program _~x Drilling fluid program ~ , Time vs depth plot ~ Refraction analysis ~ Seabed report 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge f~U~ -5'¢G¢~/.< ' DOd ~'~ F'& 2. b_'j -/../¢.~ 7 i Signed '~?/,Jl.~ /~'J~ , ~ T itlle Engineering Supervisor Date Commission Use Only Perm, Number ' APlnumber ~ Ap p rova~l ..,,~te~ ~'.~I~--'~ I 50-~-)..~.~-- Z//--~'~- /~,2~"¢¢ See cover le,er for other requirements Condition~, of approv~ Samples required Yes ~'No Mud log required Yes Hydrogen sulfide measures ~4f'es _--No Directional survey required ~"t'es _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M _X 3500 psi for CTU Other: ORIGINAL SIGNED BY byorder ol Approved by RObl~ N. Chdstenson Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 18-09B CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to - 11915' md. · Mill window in 5-1/2" liner at -11947' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. · Directionally drill 2.75" x 1725' horizontal well to access Romeo reserves. Build angle to -90° and maintain to TD. · Run and cement 2-3/8'"' liner to TD. · Perforate selected intervals. · Place well on production. April 14, 1998 DS 18-09B Proposed CT Sidetrack Horizontal 3-1/2" Tubing 3-1/2" Camco TRSSSV @ 2179' Packer @ 9349' 5-1/2" Liner Top @ 9417' 3-1/2" SWN Nipple @ 10688' Cement top - 11915' 7-5/8" Window @ 956O' Top of 2-3/8" Liner in TT Initial Perfs 5-1/2" Liner Shoe @ 12230' Window cut in 5-1/2" liner at - 11947' 2-3/4" Open hole Current perforations cement squeezed 2-3/8" liner TD @ ~ 13672' Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for ARCO ALASKA INC Well ......... : DS18-09B (P3) Field ........ : Drill Site 18 Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.29903677 N Surface Long.: 148.44975392 W LOCATIONS - ALASKA Zone: Legal Description X-Coord Surface ...... : 4793 FSL 342 FEL S24 TllN R14E UM 691406.24 Tie-in Survey: 1067 FSL 1957 FEL S14 TllN R14E UM 684474.17 TGT1 (BSL)...: 1516 FSL 2070 FEL S14 TllN R14E UM 684350.00 TGT2 (ESL)...: 2762 FSL 2108 FEL S14 TllN R14E UM 684280.00 BHL .......... : NA/q FSL 4 Y-Coord 5961372.92 5962754.17 5963200.00 5964445.00 NAN FEL S49 T29S R95W UM-17874098.25 11947277.90 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS IDENTIFICATION DEPTH ANGLE AZIMUTH TVD SUB-SEA _-- TIE-IN SURVEY KOP/CURVE 27.00/100 SECTION DEPART ..... 11925.20 65.61 302.58 8649.17 8601.17 1594.10 11946.99 66.57 302.62 8658.00 8610.00 1604.92 11950.00 66.76 303.47 8659.19 8611.19 1606.44 11960.00 67.43 306.31 8663.08 8615.08 1611.75 11970.00 68.15 309.13 8666.86 8618.86 1617.45 11980.00 68.91 311.91 8670.53 8622.53 1623.54 11990.00 69.72 314.66 8674.06 8626.06 1629.99 12000.00 70.57 317.39 8677.46 8629.46 1636.79 12010.00 71.46 320.08 8680.71 8632.71 1643.93 12020.00 72.39 322.75 8683.81 8635.81 1651.39 12030.00 73.35 325.39 8686.76 8638.76 1659.16 ANADRILL AKA-DeC APPROVED FOR PERMITTING ONLY PLAN # ~reg~re~ ..... : 14 ~pr 1998 Vert Beat ~z.: 359.70 ~ e}evst±o~.: 48.00 ft Magnetic gcln: +28.294 (E) Scale Factor.: 0.99994162 Convergence..: +1.45954280 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 1557.46 N 6895.05 W 684474.17 5962754.17 2R <TIE 1568.20 N 6911.84 W 684457.11 5962764.47 77R 4.42 1569.70 N 6914.15 W 684454.76 5962765.92 76R 26.85 1574.97 N 6921.71 W 684447.08 5962770.99 75R 27.00 1580.63 N 6929.03 W 684439.62 5962776.47 74R 27.00 1586.68 N 6936.10 W 684432.39 5962782.33 73R 27.00 1593.09 N 6942.91 W 684425.42 5962788.57 72R 27.00 1599.86 N 6949.44 W 684418.72 5962795.17 71R 27.00 1606.97 N 6955.67 W 684412.31 5962802.11 70R 27.00 1614.40 N 6961.60 W 684406.19 5962809.39 69R 27.00 1622.14 N 6967.21 W 684400.~9 5962816.98 69R 27.00 (Anadrill (c)98 1809BP3 3.2b.5 4:28 PM D) DS18-09B (P3) 14 Apr 1998 Page 2 PROPOSED WELL PROFILE Z1 STATION IDENTIFICATION MEASURED INCLN DEPTH ANGLE 12034.38 73.78 12040.00 74.35 12050.00 75.37 12060.00 76.43 12070.00 77.51 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA = ............... == ........ 326.54 8688.00 8640.00 328.00 8689.54 8641.54 330.59 8692.15 8644.15 333.15 8694.59 8646.59 335.69 8696.85 8648.85 SECTION DEPART ........ 1662.65 1667.21 1675.54 1684.12 1692.93 COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 1625.62 N 6969.56 W 1630.17 N 6972.48 W 1638.46 N 6977.41 W 1647.02 N 6981.98 W 1655.80 N 6986.19 W 684397.95 5962820.40 684394.92 5962824.87 684389.78 5962833.04 684384.99 5962841.47 684380.57 5962850.15 TOOL DL/ FACE 100 68R 27.00 68R 27.00 67R 27.00 67R 27.00 66R 27.00 END 27.00/100 CURVE CURVE 27.00/100 END 27.00/100 TGT1 (BSL) TURN 0.23/100 12080.00 78.62 12090.00 79.74 12100.00 80.89 12110.00 82.05 12120.00 83.23 12130.00 84.42 12140.00 85.61 12150.00 86.82 12160.00 88.03 12167.84 88.99 12420.55 88.99 12424.31 90.00 12424.31 90.00 12424.31 90.00 12500.00 90.00 12600.00 90.00 12700.00 90.00 12800.00 90.00 12900.00 90.00 13000.00 90.00 338.21 8698.91 8650.91 1701.95 1664.81 N 6990.02 W 340.71 8700.79 8652.79 1711.16 1674.00 N 6993.46 W 343.19 8702.47 8654.47 1720.55 1683.37 N 6996.52 W 345.65 8703.96 8655.96 1730.09 1692.90 N 6999.17 W 348.10 8705.24 8657.24 1739.76 1702.56 N 7001.42 W 350.54 8706.32 8658.32 1749.54 1712.33 N 7003.26 W 352.97 8707.18 8659.18 1759.40 1722.18 N 7004.69 W 355.39 8707.84 8659.84 1769.33 1732.11 N 7005.70 W 357.81 8708.29 8660.29 1779.31 1742.08 N 7006.30 W 359.70 8708.50 8660.50 1787.14 1749.91 N 7006.47 W 359.70 8712.97 8664.97 2039.82 2002.59 N 7007.79 W 359.70 8713.00 8665.00 2043.57 2006.34 N 7007.81 W 359.70 8713.00 8665.00 2043.57 2006.34 N 7007.81 W 359.70 8713.00 8665.00 2043.57 2006.34 N 7007.81 W 359.52 8713.00 8665.00 2119.27 2082.03 N 7008.33 W 359.28 8713.00 8665.00 359.05 8713.00 8665.00 358.81 8713.00 8665.00 358.58 8713.00 866-5.00 358.35 8713.00 8665.00 2219.26 2319.26 2419.25 2519.24 2619.21 2182.03 N 7009.37 W 2282.02 N 7010.83 W 2382.00 N 7012.69 W 2481.97 N 7014.97 W 2581.94 N 7017.65 W 684376.51 5962859.05 684372.83 5962868.16 684369.54 5962877.45 684366.64 5962886.90 684364.14 5962896.50 684362.05 5962906.22 684360.38 5962916.03 684359.11 5962925.93 684358.26 5962935.88 684357.89 5962943.71 684350.14 5963196.25 684350.02 5963200.00 684350.02 5963200.00 684350.02 5963200.00 684347.58 5963275.65 66R 27.00 65R 27.00 65R 27.00 64R 27.00 64R 27.00 64R 27.00 64R 27.00 63R 27.00 63R 27.00 HS 27.05 HS 0.00 90L 27.00 90L 27.001 90L 27.00~ 90L 0.24 684343.98 5963375.58 90L 0.23 684339.98 5963475.49 90L 0.23 684335.57 5963575.39 90L 0.23 684330.75 5963675.27 90L 0.23 684325.53 5963775.12 90L 0.23 7 Z 13100.00 90.00 13200.00 90.00 13300.00 90.00 358.11 8713.00 8665.00 2719.18 2681.89 N 7020.74 W 357.88 8713.00 8665.00 2819.14 2781.83 N 7024.24 W 357.64 8713.00 8665.00 2919.08 2881.75 N 7028.15 W 684319.89 5963874.96 90L 0.23 684313.84 5963974.77 90L 0.23 684307.39 5964074.55 90L 0.23 (Anadrill (c)98 1809BP3 3.2b.5 4:28 PM D) DS18-09B (P3) 14 Apr 1998 Page 3 PROPOSED WELL PROFILE STATION MEASURED IDENTIFICATION DEPTH .......................... END 0.23/100 TURN TD TGT2 (ESL) 13400.00 13500.00 13576.43 13671.48 13671.48 BSAD INCLN ANGLE ...... DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA ..... 90.00 90.00 90.00 90.00 90.00 SECTION DEPART COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 357.41 8713.00 8665.00 3019.01 2981.66 N 7032.47 W 357.17 8713.00 8665.00 3118.92 3081.55 N 7037.20 W 356.99 8713.00 8665.00 3195.27 3157.88 N 7041.09 W 356.99 8713.00 8665.00 3290.21 3252.80 N 7046.07 W 356.99 8713.00 8665.00 3290.21 3252.80 N 7046.07 W 8718.00 8670.00 684300.53 5964174.31 684293.26 5964274.04 684287.43 5964350.24 684280.02 5964445.00 684280.02 5964445.00 TOOL DL/ FACE 100 90L 0.23 90L 0.23 HS 0.23 0.00 0.00 ANADRILL AKA-Dr'C APPROVED FOR PERMITTING ONLY PLAN -~.~ ..... ~ _ (Anadrill (c)98 1809BP3 3.2b.5 4:28 PM D) 5O 8500 ARCO ALASKA ]]NC Anadr J ] ] Schlumberger DS18-OgB (P3) PLAN VIEW CLOSURE · 7761 feet at Azimuth 294.78 IDECLINATION.: +28.294 (E) SCALE ....... : 1 inch = 1000 feet DRAWN ....... : 14 Apr 1998 Marker Identif ication MD N/S E/H A) TIE-IN SURVEY 11925 1557 N 6895 B) KOP/CURVE 27,00/100 11947 1568 N 6912 C) END 27.00/100 CURVE 12168 1750 N 7006 D) CURVE 27.00/~00 $2425 2003 N 7008 E) END 27.00/~00 ~2424 2006 N 7008 F) TGT~ (BSL) ~2424 2006 N 7008 G) TURN 0.23/100 ~2424 2006 N 7008 ~ H) END 0.23/~00 TURN ~3576 3~58 N 704~ TG '2 (ESL) (Point) I) TD ~3671 3253 N 7046 ~ J) TGT2 (ESL) 1367~ 3253 N 7046 I ANADRILL AKA-D?C ~ ........ arr~t~v ~u ~,Ti (BSL) (Point) [:OR ~ERNiITT NG ~ ~LAFI ~~ ~B 8000 7500 7000 6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 t500 1000 500 0 500 <- WEST' EAST-> (AnaOri]] (c)gB 18098P3 3.2b.02 4:32 PM 0) i A'F::qCO A_ASKA TNC' I Marker Identification MD N/S E/N B) KOP/CURVE 27.00/:J00 :1:~947 :IS§B N PLAN VIEW c) E~o ~.oo/,oo cu,vE ,~,~, ,~o, ~oo~ CLOSURE · 7761 feet at Azimuth 294.78 ' T F) TGT$ (BSL) !DECLINA ION.' SCALE ' TD ~367~ 3253 N 7046 DRAWN · AnadrJ 11 $ch]umberger 3450- - 3300-- ~2 '~' ANAl)RILL AKA-D C 3,50 .... " /.~,'P-ROg=-I'' J,L7 F OR i:~ERMITTING ~ooo-- '~NEY U 2850 - , , ' 2700-- 2§§0 , ' 2,100 ~- 2250 ' i i 2100 - T,;T! (E ;L) (Poirl:) I, ~950 _ i ,,, " ~00 1650 , ~§0 7800 7650 7500 7350 7200 7050 6900 6750 6600 6450 6300 6150 6000 5850 5700 <- WEST (AnaOr]]l [cj98 ~8098P3 3.2D.02 4:33 PN O] ARCO ALASKA Marker Identification MD BKB SECTN INCLN A) TIE-IN SURVEY 11925 8649 1594 65.6t B) KOP/CURVE 27.00/100 11947 8658 1605 66.57 C) END 27.00/100 CURVE 12168 8708 1787 8B.99 D) CURVE 27.00/100 12421 8713 2040 88.99 E) END 27.00/100 12424 B713 2044 90.00 F) TGT1 (BSL) 12424 8713 2044 90.00 G) TURN 0.23/100 12424 B713 2044 90.00 H) END 0.23/100 TURN 13576 8713 3195 90.00 I) TD 13671 B713 3290 90.00 J) TGT2 (ESL) 13671 8713 3290 90.00 INC I Anadrill Schlumberger DS18-OgB (P3) VERTICAL SECTION VIEW Section at: 359.70 TVD Sca]e.' 1 inch = 300 feet Dep Scale · 1 inch = 300 feet Drawn · 14 Apr 1998 ANADRILL AKA-Dr'C APPROVED FOR PERMITTING ONLY 'LAN :fl: T Z3 8400 ___~ 'z~' - i]'4~- ~~- ~"-= - - -- ........... ,~. %; ¥7 ?r-,~' ~- ~, ~,,~ '~' -- A'r/~ ...... = ....... -~ %, ...... ~.~- ~ ....... [] -- ,~ _~_ ;_ ,_~,~_,~_~.. ~,,~ ............ i~ H I ~200 ~350 ~500 ~.650 ~800 ~950 2~00 2250 2400 2550 2700 2B50 3000 3'150 3300 3450 3600 3750 3900 Sect ion Departure (Anadr~l] (c)9B 1809BP3 3.2b.02 4:30 PM 0) I , ARCO ALASKA ]]NC I o-- I 0S18-098 (P3) ~oo-- ! VERTICAL SECTION VIEW Sect ion at: 359.70 TVD Scale.' ! inch = ~200 feet ~2oo=_ ,Oep Scale.' ~ inch = ~200 feet Ora~n · ~4 Apr ~998 ~800- - ~nadr~ ]1 $ch]u~b~rger Narker Identification NO BKB SECTN ~ INCLN 2400- ~ ' A) TIE-IN SURVEY 11925 8649 1594 65.6! B) KOP/CURVE 27.00/100 ~947 8658 ~605 66.57 C) END 27.00/~00 CURVE 12~68 8708 1787 88.99 3000-- i D) CURVE 27.00/100 1242! 8713 2040 88.99 E) END 27.00/I00 12424 8713 2044 90.00 F) TGT! (BSL) 12424 87~3 2044 90.00 !T G) TURN 0.23/~00 12424 8713 2044 90.00 V 3600- H) END 0.23/~00 TURN ~3576 8713 3J95 90.00 I) TO ~367! 87~3 3290 90.00 O J) TGT2 (ESL) 13671 8713 3290 90.00 4200--- I 4800 I ~ J 5400 j ANI~DRJLL kPPROVE ) AKAfDrC ir 6000 6600 I . ~ , 7200 *~ ' i 7800 ~~ ~--: ..... .-::::i~::::: __t ...... 9600 10200 0 600 t200 t800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Section Departure (AnaOrill (c)98 18098P3 3.20.02 4:29 PM O) I 60/40 i I TrplxI Ext. Fuel Shop Boiler s Water Pump Room /~Pipe rac,~ Fire Ext. Fire Ext. Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drillina Drilling Wellhead Detail Methanol Injection Otis 7" WLA Quick Connect- ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination CuttedBlinds Slip/Pipe Rams Manual Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Va. lve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus · WELL PERMIT CHECKLIST COMPANY ,~,/"-~L._~ . WELL NAME ,,~,,~../'~-~',~ FIELD & POOL ~ ~'/c'~/,~'<C2~ INIT CLASS .~/~,~-~_~/ -"" ,/"~ ~ .C// GEOL AREA PROGRAM: exp [] dev"~edrll~serv [] wellbore seg I' ann. disposal para req I~ UNIT# .,,,/,,,/~'~',..,~"<:~ ON/OFF SHORE ~_______~ ADMINISTRATION ENGINEERING f'ern~it fee attached. . . 2 t.ease ~unrber appropriate. . 3 Unique well name and numbe~ ..... 4 Well located in a defined pool .............. 5 Well located proper distance from drilling unit boundary .... 6, Well located proper distance from other wells ........ 7. Sufficient acreage available in drilling unit ..... 8 If devialed, is wellbore plat included 9 Operator only affected pady .... 10 Operator has appropriate bond in force.. 11 Permit can be issued without conservation order .... 12 Permit can be issued without administrative approval 13 (.;a~ pelrnit be approved before 15-day wait ...... Y N Y N Y N Y N 'Y N Y N Y N Y N Y N Y N Y N Y N Y N REMARKS 14 Conductor string provided .............. Y N"'~ ,. t5 Surface casing protects all known USDWs. Y N 16 CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CIvl'T vol adequate to tie-in long string to surf csg ........ 18. CM'I wilt cover' all known productive horizons .......... ~NN 19. Casing designs adequate for C, T. B & permafrost. . . N 20. Adequate far'lkage or reserve pit ................ NN'~_~i~~ 21 If a re-drill, has a 10-403 for abandonment been approved.. 22. Adequate wellbore separation proposed ..... 23 If diveder required, does it meet regulations ...... 24 Drilling fluid program schematic & equip list adequale ~~""NNN 25. BC)P[:_",'~. do they"meet regulation .... ,.--- N ' 26. BOPE press rating appropriate: test Io '"~'z:>-'t.) __psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ...... 28. Work will occur without operation shutdown ........ 29 , Is presence of H:,S gas probable ................................................................................................................... GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N,~""~ j.,~ . 31 Data presented on potential overpressure zones .... ~ /~~_~ .................................................................................................................................... 32 Seismic analysis of shallow gas zones ....... /Y N ' 33 Seabed condition su~ey (if off-shore) ......... / Y N 34 Contact ~ame/phone for weekly progress repods . . /.. Y N [exploratory only] ....... ::.:r, · ...::..~ .: :: : ============================ ..................................................................... GEOLOGY: ENGINEERING' COMMISSION: · ' ........... CO ~ --_ Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . . ............................ * ....... SCHLUMBERGER ....... . ............................ * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 18- 09B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 500292156602 REFERENCE NO : 9853 6 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/22 ORIGIN : FLIC REEL NAME : 98536 CONTINUATION # : PREVIOUS REEL COM~IENT : ARCO ALASKA INC., PRUDHOE BAY~ 18-09B, #50-029-21566-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/22 ORIGIN : FLIC TAPE NAME : 98536 CONTINUATION # : 1 PREVIOUS TAPE : COf4~ENT : ARCO ALASKA INC., PRUDHOE BAY, 18-09B, #50- 029 -21566- 02 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 18-09B API NUMBER: 500292156602 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22-0CT-98 JOB NUMBER: 98536 LOGGING ENGINEER: J. SPENCER OPERATOR WITNESS: G. SARBER SURFACE LOCATION SECTION: 24 TOWNSHIP: liN RANGE: 14E FNL: 488 FSL: FEL: 341 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 48.00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 5. 500 11970.0 17. O0 2ND STRING 2.375 13636.0 4.50 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CNL LDWG CURVE CODE: GR RUN NI]AI~ER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 11842.0 11817.0 11755.5 11695.0 11679.5 11649.5 11530.0 11495.0 11440.0 11375.5 11351.5 11321.5 11311.5 11264.0 11256.0 11233.0 11221.0 11203.0 11194.5 11191.5 11185.5 11183.0 11154.0 11139.5 11072.5 11067.0 11062.5 11054.5 11035.5 10986.5 10803 5 10788 0 10753 0 10737 0 10732 5 10707 5 10684.0 10677.0 10634.0 10602.0 10594.5 10561.0 10547.5 10545.0 22-0CT-1998 17:05 ATLAS WIRELINE EQUIVALENT UNSHIFTEDDEPTH .......... GRCH 88888.0 11842.0 11816.5 11755.0 11694.5 11679.0 11648.5 11529.5 11494.0 11439.0 11374.5 11350.0 11320.5 11310.5 11263.0 11255.0 11232.0 11220.0 11202.0 11193.0 11191.0 11185.0 11182.0 11152.5 11138.5 11071.5 11066.5 11061.0 11053.5 11034.5 10985.5 10802.0 10786.5 10753.0 10736.0 10730.5 10704.5 10682.5 10675.0 10632.5 10600.5 10593.0 10559.0 10547.0 10544.5 MCNL 88888.0 11842.0 11816.5 11755.0 11694.5 11679.0 11648.5 11529.5 11494.0 11439.0 11374.5 11350.0 11320.5 11310.5 11263.0 11255.0 11232.0 11220.0 11202.0 11193.0 11191.0 11185.0 11182.0 11152.5 11138.5 11071.5 11066.5 11061 0 11053 5 11034 5 10985 5 10802 0 10786 5 10753 0 10736.0 10730.5 10704.5 10682.5 10675.0 10632.5 10600.5 10593.0 10559.0 10547.0 10544.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 10525.0 10523.5 10523.5 100.0 98.5 98.5 $ REMARKS: CONTAINED HEREIN IS THE MCNL DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 18~09B ON 25-JUL-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE MAIN PASS GRCH TO THE BASELINE GANfl~A RAY PROVIDED BY THE CLIENT (GR. CNL) ABOVE THE KICK-OFF POINT FOR THE SIDETRACK; AND THE MAIN PASS NRAT TO GR.CNL ABOVE THE KICK-OFF POINT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13592.0 10506.0 MCNL 13602.0 10506.0 $ CURVE SHIFT DATA - PASS TO PASS (I~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH MCNL THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNLMAIN PASS. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. THIS DATA HAS BEEN DEPTH CORRECTED TO DS 18-09A AND IS NOW CONSIDERED TO BE THE PRIMARY DEPTH CONTROL DATA FOR DS 18-09B. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALD-E 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NU~iB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13602.000 NRAT. CNT 6.244 DEPT. 10504.500 NRAT. CNT 27.909 GRCH. CNT -999.250 NCNT. CNT 7669.568 FCNT. CNT GRCH. CNT 76.257 NCNT. CNT 2056. 764 FCNT. CNT 595.499 79.596 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center ._ 22-0CT-1998 17:05 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUM24ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13592.0 13306.0 MCNL 13602.0 13306.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH MCNL 88888.0 88889.0 88888.5 13587.5 13588.0 13583.5 13583.0 13582.0 13583.0 13581.5 13581.5 13572.0 13572.0 13570.0 13569.5 13563.5 13564.5 13561.5 13563.0 13557.0 13557.0 13552.5 13554.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 13547.5 13546.0 13539.0 13537.5 13528.0 13526.5 13524.0 13513.0 13512.5 13502.0 13499.0 13494.0 13492.0 13484.5 13474.5 13471.0 13451.0 13438.0 13426.0 13421.5 13421.0 13410.5 13405.5 13396.0 13382.5 13377 5 13370 5 13361 5 13360 5 13355 5 13350 5 13342 5 13341 0 13335 5 13328.5 13325.5 13318.0 13310.0 100.0 $ 13549.0 13538.5 13528.0 13524.0 13513.0 13502.0 13494.5 13474.5 13447.5 13438.0 13421.5 13383.0 13370.0 13362.0 13342.5 13337.0 13331.0 13318.5 13312.0 102.0 13545.5 13538.0 13526.0 13513.5 13499.5 13492.0 13485.5 13472.5 13428.0 13422.5 13410.5 13405.5 13398.0 13376.0 13361.5 13357.0 13350.5 13342.0 13322.5 97.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNL REPEAT PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE REPEAT PASS GRCH TO THE MAIN PASS GRCH; AND THE REPEAT PASS NRAT TO THE MAIN PASS NRAT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE N-RAT SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 7 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13602.500 GRCH. CNT NRAT. CNT 7.437 DEPT. 13303.000 GRCH. CNT NRAT. CNT 12.930 -999. 250 NCNT. CNT -999. 250 NCNT. CNT 7742.664 FCNT. CNT 6669.317 FCNT. CNT 570.776 400.871 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS MCNL $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 9 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNAV GAPI 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 CVEL CNAV F/HR 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNAV CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNAV CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNAV 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13602.000 GRCH. CNAV -999.250 CVEL.CNAV FCNT. CNAV 583.393 NRAT. CNAV 6.778 29.149 NCNT. CNAV 7707.169 DEPT. 10504.500 GRCH. CNAV 76.257 CVEL.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 NRAT. CNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13612.5 10492.75 MCNL $ LOG HEADER DATA DATE LOGGED: 25-JUL-98 SOFTWARE VERSION: O031A TIME LOGGER ON BOTTOM: 1353 25-JUL-98 TD DRILLER (FT) : 13591.0 TD LOGGER (FT) : 13607.0 TOP LOG INTERVAL (FT) : 10504.0 BOTTOM LOG INTERVAL (FT) : 13604.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~E4A RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER GR MCNL 11970.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 11 FLUID RATE AT WELLH~ (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THE~) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -40 FAR COUNT RATE HIGH SCALE (CPS): 2160 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO ARCO PDC LOG DATED 19-MAY-98. THIS FILE CONTAINS THE RAW MCNL DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 CVEL FLD F/HR 0000000 GR FLD GAPI 0000000 RCNT FLD CPS 0000000 RCFT FLD CPS 0000000 RTNR FLD 0000000 ETIM FLD MIN 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 ! 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13612.451 CVEL.FLD 0.000 GR.FLD -999.250 RCNT. FLD RCFT. FLD -999.250 RTAFR.FLD -999.250 ETIM. FLD -999.250 DEPT. 10492.750 CVEL.FLD -999.250 GR.FLD -999.250 RCNT.FLD RCFT. FLD -999.250 RTArR.FLD -999.250 ETIM. FLD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 13 DEPTH INCREMENT: 0.1000 FILE SU~K4ARY VENDOR TOOL CODE START DEPTH MCNL 13612.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAI~4A RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH 13292.2 25-JUL-98 O031A 1353 25-JUL-98 13591.0 13607.0 10504.0 13604.0 1800.0 NO TOOL NUMBER GR MCNL 11970.0 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : -40 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE: 14 FAR COUNT RATE HIGH SCALE (CPS): 2160 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO ARCO PDC LOG DATED 19-MAY-98. THIS FILE CONTAINS THE RAW MCNL DATA FOR THE REPEAT PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NOW~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO-M~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 CVEL REP F/HR 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 GR REP GAPI 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT REP CPS 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT REP CPS 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR REP 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 ETIM REP MIN 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-0CT-1998 17:05 PAGE 15 ** DATA ** DEPT. 13612.500 CVEL.REP 0.000 GR.REP RCFT.REP -999.250 RTNR.REP -999.250 ETIM. REP DEPT. 13292.201 CVEL.REP -999.250 GR.REP RCFT.REP -999.250 RTNR.REP -999.250 ETIM. REP -999.250 RCNT.REP -999.250 -999.250 RCNT.REP -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION . O01CO1 DATE . 98/10/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME .. EDIT DATE : 98/10/22 ORIGIN : FLIC TAPE NAME : 98536 CONTINUATION # : 1 PREVIOUS TAPE : CONk4ENT . ARCO ALASKA INC. , PRUDHOE BAY, 18-09B, #50-029-21566-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/22 ORIGIN . FLIC REEL NAME · 98536 CONTINUATION # : PREVIOUS REEL : CONk4ENT : ARCO ALASKA INC., PRUDHOE BAY, 18-09B, #50-029-21566-02
