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Home My WebLink About201-222STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LOG By Samantha Carlisle at 7.03pm,Jun09, t071 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 0 Development ❑ Exploratory ❑ Service 0 Stratigraphic Test ❑ 2. Operator Name: 6, Date Comp., Susp., or Aband.: 14. Permit to Drill Number/Sundry Hilcorp North Slope, LLC 5/22/21 201-222 321-020 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 12/25/2001 50-029-23054-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 12/28/2001 PBU V-201 g Ref Elevations KB 82.1 17. Field/Pool(s): Surface: 4838' FSL, 1775' FEL, Sec. 11, T11N, R11E, UM Top of Productive Interval: 692' FSL, 2239' FEL, Sec. 02, T11 N, R11 E, UM GL 53.6 BF Surface Prudhoe Bay, Schrader Bluff Oil 10. Plug Back Depth(MD/TVD): 18. Property Designation: ADL 028240 ' Total Depth: 798' FSL, 2104' FEL, Sec. 02, T11N, R11E, UM Surface 4b. 41b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 590526 y- 5970085 Zone - ASP4 5270'/ 4892' 00-001 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MDrFVD: TPI: x- 590047 y- 5971213 Zone - APS4 Total Depth: x- 590181 y- 5971321 Zone - ASP4 None 1900' (approx) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 Water Depth, if Offshore: 21. Re-drill/Lateral Top Window 113. MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MIRES, LWD, MWD, CMR, FMI, DIPOLE SONIC 23' CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 3o" x 20" 91.5# H-40 Surface 109' ' Surface 109' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 Surface 3001' Surface 2752' 12-1/4" 596 sx AS III Lite, 244 sxClass'G' 7" 26# L-80 Surface 5257' Surface 4879' 8-3/4" 283 sx Class'G' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom, Perforation GRADE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number, Date Perfd): 3-1/2" 9.2# L-80 4136' 4077'/ 3759' Abandonment Date 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 • Per 20 AAC 25.283 (i)(2) attach electronic and printed 5/22/2021 HEW information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Surface in OA 18 -gal 15.6-ppg HES Arctic C cement 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke. Size Gas -Oil Ratio: Test Period �1 Flow Tubing Press Casing Press: Calculated 24 Hour Rate �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Sr Pet EngMGR08JUL2021 Sr Pet GeoDLB 06/17/2021 Sr Res Eno Form 10-407 Revised 3/2020 RBDMS HEW 6/11/2021 SFD 6/24/2021 Submit within 30 days of Completion, Suspension, or Abandonment xG 28. CORE DATA Conventional Core(s) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 4725' 4375' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Na 4548' 4207' Nb 4573' 4231' Nc 4618' 4273' OA 4725' 4375' OBa 4797' 4443' OBd 4838' 4482' OBc 4897' 4538' OBd 4950' 4589' OBe 5017' 4652' OBf 5060' 4693' Base of OBf 5114' 4744' Formation at total depth: Base of OBf 5114' 4744' 31. List of Attachments: Daily Operations Reports, Photo Documentation, Wellbore Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Stan Golis B igned by Stan Golis Authorized Name: Stan Golis DN:—Stan Golis (BBo, Contact Name: Oliver Sternicki o=usa Data :2021.08.0918:1336-0B00Contact Email: Oliver.Sternicki@hilcorp.com Authorized Title: Sr. Area Operations Manager Authorized Signature with Date: Contact Phone: 907.564.4891 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Daily Report of Well Operations PBU V-201 ACTIVITY DATE SUMMARY ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 50'. Begin excavation 5/2/2021 to 2.5' below pad elevation. No sign of marker plate. Barricade excavation. LDFN. ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 47'. Continue excavation, find marker plate 3' below pad elevation. Remove float plate and cement around insulated conductor. Excavate to 12' below pad elevation, 5' below tundra 5/3/2021 elevation. LDFN. ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 47'. Clean up sides of excavation, final depth 13' below pad elevation, 6' below tundra elavation. Set shoring 5/4/2021 box and rig mats. Move excavator to S-108. LDFN. ***P&A In Progress*** Pad Elevaton=54'. Tundra Elevaton= 47'. Cut window in insulated conductor to able to fitt Super -D Wacks saw. Rig up saw and start to cut at 3" below tundra elevation. Did not finish cut, will return in the morining. Job In 5/15/2021 Progress. ***P&A In Progress*** Cut Cemented strings 3' below tundra. Sent Pictues to AOGCC Adam Earl. Performed cement top job on 9-5/8" x 7" annulus with 18 gal of 15.6 ppg HES Arctic C cement. Welded marker plate and sent pictures to Adam Earl. 5/19/2021 Removed shoring box and covered excavation with rig mats. Will return to back fill. 5/22/2021 ***P&A Complete*** Backfill and delineate excavation. i.• r e 1 6' - i �• - Ams w' ;n. r TREE = 3-112" CIW ABANDONED WELLHEAD FMC ACTUATOR NA 20" COPD, 1�,., REF ELEV = 82.1' g1.5#, 1+40, 130';,,�20 BF. ELEV = SURFACE Conductor KOP ----- 900' D= 19.124" M_ax Angle = 36' Q 2380' TBG & CSG 1300' - 1310' Datum MD.= 4838' PUNCH,6 SPF, Datum TVD - 4400' SS (01/30/18) E-LNETAGGED TOC (01/30/18) -2068' 9-5/8" CSG, 40# L-80 BTC, ID = 8.835" 3001' TOC 3700' — Minimum ID = 2.812" @ 2201' 3-1/2" CAMCO SSSVN FULL ABANDONMENT - ALL STRINGS CEMENTED TO SURFACE & CUT 3' BELOW TUNDRA (05/22/21) 3-1/2" TBG, 9.3#, L-80_0087 bpf, ID = 2.992" 1-] 4136' PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: 32" @ 2775' NDte: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-1/2" 6 2775-2780 S 01/14/18 2" 6 2870-2875 S 01/14/18 2-1/2" 4 4750-4765 S 03/03/07 2-1/2" 4 4810-4830 S 03/03/07 2-1/2" 4 4845-4855 S 03/03/07 2-1/2" 4 4954-4989 S 03/03/07 PBTD —L 5157- 7" CSG, 26#, L-80, D = 6.276" 2267' NOTES:SAFETY - • tSURFACE CASING LEAK' 9+�tliAiiq,eN0/11111111E. •• 4 1825' I, 1111111171w _. yx ox, 6 /1 1t /111111144,#--0,4 ►ifif��' 1 �i14 1i1i�i1i1i1i1i1i�iL�O��i I3-1/2" BKR CMD SLD SLV W/ BX PROF. D = 2.812' 4062'ELM I -I JET CUT (03/07/07) 4077' 7" X 3-1/2" BKR PREMIER PKR, D = 2.869" 4102' -13-1/2' HES X NP, ID = 2.813" 4123' 3-112" HES X NP, ID = 2.813" 4136' -1 3-12" WLEG, ID = 2.992" BOTTOM OF HPZ1 4434'SLM TOP OF CEM911T (03/06/07) 4358' 4600' TOP OF CEMENT (03/04/07) T O P O F D PZ1 4690' 7" MARKER Jr (20') W! RA TAG 4549' 4871' 1-17" MARKER JT (20') W/ RA TAG 4977' J-1 TOP OF FLL (03/4/07)„ O T T O M OF D P Z1 5111' ORION UNIT WELL: V-201 PERMIT No: 2012220 API No: 50-029-23054-00 SEC 11, T11N, R11 E, 4838' NSL & 1775' WE DATE REV BY COMMENTS DATE REV BY COMMENTS 01101/02 CHIKAK ORIGINAL COMPLETION 06/25/18 JNUJMD ADDED REF & BF ELEV 12/15/07 TW/PJC PERF CORRECTIONS 01/16/19 AW/JMD EDITS TO SUSPENDED WBS 01/16/18 DS/JMD CEMENT PLUG 01/14/18 06/21/19 JNUJMD ADD COND, BF ELEV - DELETE 01 02/01/18 MS/JMD TBG/CSG PUNCH & EL TAGGED 1 06/26/19 JNUJMD CORRECTED TBG DEPTH I 02/08/18 GPUJMD CMT TO SURFACE 02/06/18 05/28/21 RCB/JMD FULL ABANDONMENT 05/21/21 BP Exploration (Alaska) 06/13/18 AB/JMD SUSPENDED WELL 05/31/18 1a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service Hilcorp North Slope, LLC 14. Permit to Drill Number/Sundry 201-222 12/25/2001 12/28/2001 GL 4a. Surface: Top of Productive Interval: Total Depth: 4838' FSL, 1775' FEL, Sec. 11, T11N, R11E, UM 692' FSL, 2239' FEL, Sec. 02, T11N, R11E, UM 798' FSL, 2104' FEL, Sec. 02, T11N, R11E, UM Zone -5970085 ASP4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 5/22/21 15. 50-029-23054-00-00 16. PBU V-201 Well Name and Number: Surface 53.6 17. Zone -APS45971213 Zone - Surface: x-590526y- TPI:x-590047y- Total Depth: x-590181y-ASP45971321 5270' / 4892' None DNR Approval Number:19. 00-001 5. Directional or Inclination Survey:Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, LWD, MWD, CMR, FMI, DIPOLE SONIC CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 7" 91.5# 40# 26# L-80 L-80 Surface Surface 5257' Surface Surface 4879' 8-3/4" 260 sx Arctic Set (Approx.) 283 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 3-1/2" 9.2# L-80 4136' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: N/A N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: Open to production or injection?Yes No24. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): H-40 109'42"20" 9-5/8"Surface 3001'12-1/4"596 sx AS III Lite, 244 sx Class 'G'Surface 2752' 4077' / 3759' 18-gal 15.6-ppg HES Arctic C cement Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 109' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes NoWas hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028240 321-020 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3. Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 82.1 Water Depth, if Offshore:13. N/A 0 API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: N/A 1900' (approx) Submit within 30 days of Completion, Suspension, or Abandonment Prudhoe Bay, Schrader Bluff Oil Surface in OA By Samantha Carlisle at 7:03 pm, Jun 09, 2021 RBDMS HEW 6/11/2021 Abandonment Date 5/22/2021 HEW xGDSR-6/11/21MGR08JUL2021 30" X SFD 6/24/2021 DLB 06/17/2021 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Oliver Sternicki Contact Email: Oliver.Sternicki@hilcorp.com Authorized Name:Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature with Date: Contact Phone:907.564.4891 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 4548' 4573' 4618' 4725' 4797' 4838' 4897' 4950' 5017' 5060' 5114' 4207' 4231' 4273' 4375' 4443' 4482' 4538' 4589' 4652' 4693' 4744' Na Nb Nc OA OBa OBd OBc OBd OBe OBf Base of OBf Base of OBf 28.CORE DATA Conventional Core(s)Yes No Sidewall Cores Yes No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 5114' 4744' Top of Productive Interval 4725'4375' NoPermafrost - Top TVDMDNAME 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 31. Daily Operations Reports, Photo Documentation, Wellbore SchematicList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.09 16:13:36 -08'00' Stan Golis (880) FULL ABANDONMENT - ALL STRINGS CEMENTED TO SURFACE & CUT 3' BELOW TUNDRA (05/22/21) 30" x 20" Thermocase Conductor ACTIVITY DATE SUMMARY 5/2/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 50'. Begin excavation to 2.5' below pad elevation. No sign of marker plate. Barricade excavation. LDFN. 5/3/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 47'. Continue excavation, find marker plate 3' below pad elevation. Remove float plate and cement around insulated conductor. Excavate to 12' below pad elevation, 5' below tundra elevation. LDFN. 5/4/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 47'. Clean up sides of excavation, final depth 13' below pad elevation, 6' below tundra elavation. Set shoring box and rig mats. Move excavator to S-108. LDFN. 5/15/2021 ***P&A In Progress*** Pad Elevaton=54'. Tundra Elevaton= 47'. Cut window in insulated conductor to able to fitt Super -D Wacks saw. Rig up saw and start to cut at 3" below tundra elevation. DId not finish cut, will return in the morining. Job In Progress. 5/19/2021 ***P&A In Progress*** Cut Cemented strings 3' below tundra. Sent Pictues to AOGCC Adam Earl. Performed cement top job on 9-5/8" x 7" annulus with 18 gal of 15.6 ppg HES Arctic C cement. Welded marker plate and sent pictures to Adam Earl. Removed shoring box and covered excavation with rig mats. Will return to back fill. 5/22/2021 ***P&A Complete*** Backfill and delineate excavation. Daily Report of Well Operations PBU V-201 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: P. I. Supervisor`l �� FROM: Adam Earl SUBJECT: Petroleum Inspector 5/30/2021 Surface Abandonment PBU V-201 - Hilcorp Alaska North Slope LLC PTD 2012220 Sundry 321-020 " 5/18/2021: 1 traveled out to PBU V-201 to inspect the surface abandonment. Matt Linder was the Hilcorp rep on location. The well had hard cement in all strings and was cut off approximately 5 feet below tundra grade. The marker plate information was % correct. Attachments: Photos (2) 2021-0518—Surface—Abandon PBU V-201 ae.docx Page 1 of 2 Yr 'Ef•-a`�� T` tee. p. L s � Xy �� co k4 -j r4l, co -j r4l, ' f" k� / Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:201-222 6.API Number:50-029-23054-00-00 PRUDHOE BAY, ORION / SCHRADER BLUFF OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028240 Property Designation (Lease Number):10. N/A 8. PBU V-201 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon 5 Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG 5 Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 5270 Effective Depth MD: L-80 11. 2/15/2021 Commission Representative: 15. Suspended Contact Name: Oliver Sternicki Contact Email: oliver.sternicki@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 4892 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 4077, 3759 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program Surface - 3001 34 - 2752 14. Estimated Date for Commencing Operations: BOP Sketch Surface - 109 Structural Proposal Summary 13. Well Class after proposed work: 3-1/2" Baker Premier Ret. Pkr None 3-1/2" 9.2#Surface - 4136 Production Surface Surface Surface None Surface - 109 470 9-5/8" Contact Phone:(907)564-4891 Date: ~75 149020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface ~2969 5750 Intermediate ~5226 7" 34 - 5257 34 - 4879 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 0 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:47 am, Jan 13, 2021 321-020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2021.01.12 16:13:32 - 09'00' Stan Golis DSR-1/19/21MGR15JAN2021 10-407 SFD 1/13/2021 Photo document as described. Yesn Required? Comm 1/20/21 dts 1/20/2021 JLC 1/20/2021 RBDMS HEW 1/26/2021 Plug and Abandon Well: V-201 PTD: 201222 API: 50-029-23054-00 V-201 Plug and Abandon Well Integrity Engineer: Oliver Sternicki, (907)350-0759 Operations Engineer: Brian Glasheen, (907)545-1144 Expected Start Date: 02/15/2021 History Schrader Bluff- Orion well V-201 (PTD# 201222) was originally drilled and completed in 2002. A surface casing leak was found in 2007 and the well was suspended on 1/25/2008. Work was completed in 2018 under sundry #317-252 where all strings were cemented to surface and the wellhead was cut and temporarily capped approximately 1 foot below pad grade. Objective Excavate and cut off all casings 3’ below original tundra, permanently install well name cap, and backfill excavation. Procedure 1. Excavate and Cut off all casings 3’ below original tundra level. 2. AOGCC witness of cut-off casings before any top job commences. 3. AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld marker cap on outermost casing string. Photodocument all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope LLC V-201 API No. 50-029-23054-00 PTD No. 201222 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 201-222 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service 0 1 6. API Number. 50-029-23054-00-00 7. Property Designation (Lease Number): ADL 028240 8. Well Name and Number PBU V-201 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. SCHRADER BLUF OIL 11. Present Well Condition Summary: RECEIVED Total Depth: measured 5270 feet Plugs measured Surface feet true vertical 4892 feet Junk measured None feet f fit [ Effective Depth: measured Surface feet Packer measured 4077 feet JUN 2 6 2Q19 We vertical Surface feet Packer true vertical 3759 feet A®GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor -75 20" Surface -109 Surface -109 1490 470 Surface -2969 9-5/8" Surface -3001 Surface -2752 5750 3090 Intermediate Production -5226 7" Surface -5257 Surface -4879 7240 5410 Liner Perforation Depth: Measured depth* None feet True vertical depth : feet Tubing (size, grede, measured and true vertical depth) 3-1/2" 9.2# L-80 Surface - 4136 Surface - 3815 Packers and SSSV (type, measured and 3-1/2" Baker Premier Ret. Pkr 4077 3759 true vertical depth) 12. Stimulation or cement squeeze summary. Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 1 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: (reouire t ner2a nnc 25.07025071. s 25.255) 15. Well Class after work. Daily Report of Well Operations 51 Exploratory ❑ Development ❑ Service m Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ 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: WA Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: Specialist Contact Email: Travis.Montgomery(d/bp.com Authorized Signature: Date: W*t1 Contact Phone: +1 907 564 4127 Farts 10-404 Revised 3412017 4x0f ki P- W q ABDMS*" JUN 2 8 2019 Submit Original Only Daily Report of Well Operations V-201 ACTIVITYDATE SUMMARY TWO = N/A. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 SV, WV = C. IA, OA = OTG. 11:30 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: V-201 Field/Pool: _Prudhoe Bay / Prudhoe Oil Permit# (PTD): 2012220 API Number: 50-029-23054-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/31/2018 Surface Location: Section: 11 Twsp: 11N Range: 11E Nearest active pad or road: V Pad 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: Pad or location surface: Clean Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: 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: Cellar description, condition, fluids: NIA Rat Hole: N/A Wellhouse or protective barriers: N/A Well identification sign: NIA Tubing Pressure (or casing if no tubing): N/A Annulus pressures: NIA Wellhead Photos taken (# and description): No Operator Rep (name and signature): Josh Prowant ,jam AOGCC Inspector: Adam Earl Other servers: Inspection Date: 6/2/2019 AOGCC Notice Date: Time of arrival: 11:30 AM Time of Departure: Site access method: Access Road 6/1/2019 11:40 AM A OOF �D L IGNIKBIKUhl11 C u04 L-221 1J L-109 , L-108 V!l�PB1 V L-220 3 104 tOr 1 O V-1fl3 i Uqq..., �! L Fp L - 20L1 1!221 "Z_MPBi '7 L-104 L-201LL? L-03 'v 120 L, 21 'J -203L4 TV -123 V22g7L1 _ V-2030 TV -210 V-207LI�•�207 L- L-2d4La t29 -JL +V--nO --- V!202L1� 04' 0 T204L2 �"1 V -202L2 L! oe' V213PB 1 �� T V=2SI2 V- 106A V-10ftA1�81 ^Vc T"JP.AP83 0 L-107 1! 102TAPHf V-06 t,! 207PB 1 1!2* V-102 712214PB2 A 21903 1!2d7L4%2 L!214P83 Vt\4204L3 12204'2 �`'224 V-229 V- L7 T 14213 V -214P84 �V!105 u204PB2 —Vta11 2 1 V!1MF'B1 _ WKIYPST-01 T F',t104 j; V-204L1PB1 Veit . V!101 ,20_. ... V-V7L4PB1 'J-`20'312 'TF2dgLi V V! L -12tH V-201 'd-2041.2 1 Vi204PB'1f V!212 C V!11-1' L! i1�P81 C Vc ip7 111 PE°-,, 111PB1 -- 1B 1R 1107IX V -224P81 1t 115'2'! .,,� � ,g C 121118 V-21443$1 V D !1F709PS2. 39 FE i V-21- T1!il %yr C V- 109,V. -115P8.1 114=. 10 11 1_ 115 V' 114APB2 11 y },;- . V! 114APp 1 — .. Z- 328 b!ci5 V-115L'� V-114 � — 'u -117P61 Z-32SPB1 `- V-1' .7P82 z-10.1 C Z-IaA r' V. 117 Z-32BPB2 _ Z-10 Z-35 r z -_n Z-078 TREE=' 3-10CNV SUSPENDED WELLHEAD = RAC ACTUATOR= NA REF ELEV = - 82.1' _- BF. ELE7 = SURFACE KOP= Max Angle = 900' 36" @ 2380' Datum MD= 4838' Datum ND = 4400' SS 20-COND, 109' 915#, 11-40, D - 19.124' V_2OSAFETY NOTES:—WELL HAS SHALLOW L SURFACE CASING LEAK— 975' 9-5l6' TAM PORT COLLAR W�� iiow=011 ,t■■��i 1� X111 P111# 1 •.i 91' 11'1111' ® •• B-61 SSS r 1 1. .1 #000#00-44446� 1 ME I�l/�1�1�1�1�1�1�1�1�1�eei1� 11LiPI=SM Minimum ID =2.812"@ 2201' 3-112" CAMCO SSSVN 3-12" TBG, 9.3#, =2.992" I--] 4136' PERFORATION SUMMARY REL LOG: ANGLEATTOPPERR 32"@2775' NDte: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/&v DATE 2-12" 6 2775-2780 S 01/14/18 2' 6 2870-2875 S 01/14/18 2-12' 4 4750-4765 S 03/03/07 2-12" 4 4810-4830 S 03/03/07 2-12' 4 4845-4855 S 03/03/07 2-12' 4 4954-4989 S 03/03/07 BX PROF, 1[3=2.812' 1 4102' 1-13-112' HES X NIP, ID = 2.813• I BOTTOM OF HPZ1 ED 4358' ED TOP OF DPZ1 BOTTOM OF DPZ1 5111' ORION UNIT WELL: V-201 PERMIT No: 2012220 AR No: 50-029-2305400 SED 1 i, T11 N, R11 E, 4838' NSL & 1775' WEL DATE REV BY COMMENTS DATE REV BY COMMENTS 01/01A2 CHIKAK ORIGINAL COMPLETION 0625/18 JNL/JMD ADDED REF& BF ELEV 12/15/07 TWIPJC PERF CORRH:TIDNS 01/16/19 AWNJMD EDITS TO SUSPENDED WBS 01/16/18 DS/JMD CEMENT PLUG (01/14/18) 0621/19 JNUJMD ADD ODND, BF B -EV - DE-EfE OKB 02/01/18 MS/JMD TBG/CSG PUNCH & EL TAGGED 1 0626/19 JNL/JMD CORRECTED TBG DEPTH 02/08/18 GPUJMD GMT TO SURFACE (02106118) BP Exploration (Alaska) 06/13/18 AB/JMD SUSPENDED WELL (05/31/18) Susp6nded Well Inspection Report InspectNo: susAGE190618092552 Date Inspected: 6/2/2019 Inspector: Adam Earl Well Name: PRUDHOE BAY UN ORIN V-201 Permit Number: 2012220 Suspension Approval: Sundry tt 317-252 Suspension Date: 5/31/2018 Location Verified? If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Wellhead Condition NA Condition of Cellar NA Type of Inspection: Subsequent ' Date AOGCC Notified: 6/1/2019 Operator: BP Exploration (Alaska)Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? ❑/ Photos Taken? ❑� Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑ OA: VR Plug(s) Installed? ❑ Surrounding Surface Condition well is buried, no sheen or trash, area looks clean Comments location verified by pad map Supervisor Comments Photos(3)attached Tuesday, August 13, 2019 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sidewall Cores Yes ® No ❑ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Care dale reported with previous 10407, Dated 04/24/2002 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost -Top Well Tested? Yes ❑ No IZ Permafrost - Base If yes, list intervals and formations tested, briefly summarizing lest results. Attach Top of Productive Interval 4725' 4375' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. NA 4548' 4207' Nb 4573' 4231' Nc 4618' 4273' OA 4725' 4375' OBa 4797' 4443' OBd 4838' 4482' OBc 4897' 4538' OBd 4950' 4589' OBe 5017' 4652' OBf 5060' 4693' Base of OBf 5114' 4744' Formation at total depth: Base of OBf 5114' 4744' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Worthington, Area J Authorized Title: SI pe ialist Contact Email: Aras.Worthington@bp.com Authorized Signature: JVVDate: /f $ Contact Phone: +1907 564 4102 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Ia. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item lb. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23, Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WELL NAME: V-201 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used Surface 2.65 Bbls Arctic Set I, 2 Gal SqueezeCrete 2058' 31 BblsClass'G' 1300'- 1310' Tubing / Casing Punch Surface 107 Bbls Class'G' Surface 9 Bbls Class'G' Daily Report of Well Operations V-201 ACTIVITYDATF SI IMMARY TWO = SSV/0/0. Temp = SI. Clean conductor (assist Special Projects). Flow line & scaffold removed. Evac'd -3 gal of water from the conductor & 0.5 bbls of water from the cellar. There is 92" from top of conductor to what feels like a hard gravel bottom. Upon arrival there was 31" from top of conductor to top of RG -2401, w/ a total of 75" of RG -2401 in the conductor. Removed -12 gal of RG -2401, there is now 48" from the top of conductor to top of the RG -2401, w/ 44" of RG -2401 still remaining in the conductor. Heater installed in well house w/ door open. 9/2/2017 SV, WV = unable to reach. SSV = C. MV = O. IA, OA = OTG. 15:30 TWO = SSV/0/0. Temp = SI. Clean conductor (assist Special Projects). Flow line & scaffold removed. There is 92" from top of conductor to what feels like a hard gravel bottom. Upon arrival there was 44" from top of conductor to top of RG -2401. Removed -18 gal of RG -2401, there is now 69" from the top of conductor to top of the RG -2401, w/ 23" of RG -2401 still remaining in the conductor. Heater installed in well house wl door open. 9/3/2017 SV, WV = unable to reach. SSV = C. MV = O. IA, OA = OTG. 15:30 0/0/0 No FL Suspended well. Job Scope: Cement conductor and SSSV lines for P&A. Condition conductor using steam for placement of cement Work top of conductor with 220 deg. F steam down to a depth of 120" inches with 200 deg. F Pumped 2.5 gallons hydraulic fluid down control line to confirm free. Attempted to pump down balance line with no luck. Shut down for day and resume in morning. ...Job in progress... 9/5/2017 0/0/0 No FL Suspended well; Job Scope: Cement contuctor to surface and SSSV control line. Mix and dump 2.65 bbls of 15.7 ppg Arctic Set 1 cement into conductor to surface. 9' 6:" Inject 2 gallons of 14 ppg SqueezeCrete into SSSV control line. Single line completion to SSSV nipple. Balance port mechcanically plugged at tubbing hanger. Need to pressure 9/6/2017 test control line in >48 hours. No red line required ***Job complete*** T/I/O = SSV/O+/O+. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor was not set up all the way. Heater installed in WH and is working properly. ***OPS has further questions/concerns about the integrity of cement due to V -pad subsidence issues.*** SV, WV = unable to reach. SSV = C. MV = O. IA, OA = OTG. 03:30 9/7/2017 T/I/O = SSV/O+/O+. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor is in a gelatin state, but firm enough to press a finger nail mark in it. Heater installed in WH & is working properly. 9/7/2017 SV, WV = unable to reach. SSV = C. MV = O. IA, OA = OTG. 15:10 TWO = SSV/O+/2. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor is firm but when pressed will leave impression in surface, Cement sample in bucket inside the wellhouse has solid thin crust but still soft under the crust. Heater installed in WH & is working properly. SSV doesnt have a rupture disk installed and is disconnected from the panel. 9/8/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 10:00. TWO = SSV/O+/2. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor is firm but when pressed will leave impression in surface, Cement sample in bucket inside the wellhouse has solid thin crust but still soft under the crust. Removed heater in WH and released. 9/9/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 12:40 9/9/2017 Cost placeholder for marker plate Daily Report of Well Operations V-201 T/I/O = SSV/0/0. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor is hard, when pressed does not leave impression. Cement sample in bucket inside well house has thin solid crust but still soft under crust. 9/10/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 02:30 T/I/O = SSV/0/0. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor is hard, when pressed does not leave impression. Cement sample in bucket inside well house is solid but will leave an impression when pressed into. 9/11/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 04:00 T/I/O = SSV/0+/0+. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement condition is unchanged from 04:00 this morning. 9/11/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 21:30. TWO = SSV/0+/0+. Temp = SI. WHPs (eval cement). No flowline & scaffold removed. Cement in conductor and in bucket appears to be fully cured.. 9/12/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 23:00. TWO = SSV/1/3. Temp = SI. WHPs (eval cement). No flowline. Scaffolding removed. Cement in conductor and in bucket appears to be fully cured.. 9/14/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 13:30. TWO = SSV/1/3. Temp = SI. WHPs (eval cement). No flowline. Scaffolding removed. Cement in conductor and sample in bucket is fully cured. Note: Inline check valve installed on IA CV @ 3 o'clock position. 9/15/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 20:30. TWO = SSV/1/3. Temp = SI. WHPs (eval cement). No flowline. Scaffolding removed. No changes in WHP's or cement condition from 3/15/17. 9/18/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 01:30. TWO = SSV/0+/0+. Temp = SI. WHPs (eval cement). No flowline or scaffolding. Conductor cement is set up. 9/19/2017 SV. WV. SSV = C. MV = O. IA, OA = OTG. 1200 hrs. TWO = SSV/0/0. Temp = SI. PT Control Line PASSED to 2949 psi. (P&A). Max = 3000 psi. No flowline or gas lift lines. Used hydraulic oil to pressure up control line from 0 psi to 3000 psi. Loss 49 psi in 15 min. Bled control line to 0 psi. Hung tag. Final WHPs = SSV/0/0. 11/2/2017 SV, SSV, WV = C. MV = O. IA, OA = OTG. 13:30. ***SLB Fullbore Pump*** Job Scope: Pump cement down TBG & up IA/OA plug #2 of 3 Pumped 5 bbl meth spear at slow rate varifying returns form IA then OA. Continued with 9.8 ppg brine putting 15 bbls in IA then 15 bbls in OA, Pumped 31 bbls of 15.8 ppg class G cement followed by 14 bbls of 9.8 ppg brine then 4 bbls of 60/40 methanol in tubing for freeze protect. Cement volumes TBG/IA/OA 4/13/14 bbls = -2300' MD Foam balls @ 2070' MD Well head and tree secured tags hung. Grease crew called out to service valves. Pad 1/14/2018 Op notisfied. ***Job Complete*** ***WELL S/I ON ARRIVAL*** (SLB ELINE - DRIFT/ PERF) INITIAL T/I/O = 0/0/0. RIH W/ 1-3/4" SAMPLE BAILER. OAL = 38', CAW = 410 LBS, MAX OD = 2.125". TAG TOC Coil 2058', RECOVER CEMENT SAMPLE. RIH W/ 1-3/4" SAMPLE BAILER. DAL = 38', CAW = 410 LBS, MAX OD = 2.125". TAG TOC @ 2049, RECOVER CEMENT SAMPLE (AOGCC WITNESSED). RIH W/ 2" x 10' HYPERJET HSD, 6 SPF, 60 DEG PHASE. CAL = 27' OAW = 250 LBS, MAX OD = 2.125" PERFORATED INTERVAL = 1300' -1310'. OP SHOT = 9.33', CCL STOP DEPTH = 1290.67' ALL LOGS TIED INTO TUBING TALLY 06-JULY-2014. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 0/0/0 1/30/2018 ***JOB COMPLETE 30-JANUARY-2018** Daily Report of Well Operations V-201 T/I/O = SSV/0/0. Temp = SI. Measurements (P&A). Circ-out rigged up to IA & OA. Measurement from BFE to top of landing ring = 29". BFE to top of conductor = 43". BFE to pad grade -6' in front of wellhouse door = 38.75". 2/1/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. T/I/0= 0/0/0 Injectivity test (Post E-Line TBG Punch) Pumped into TBG with 6 bbls 60/40 MW, taking returns up OA to open top tank to verify TBG punch. Pumped 6 bbls 60/40 MW down TBG taking returns up IA to open top tank to verify TBG punch. Final WHP'S 125/0/0 2/4/2018 SV,WV,SSV,OA = Closed MV=open IA=OTG. Pad OP notified on departure. **SLB Fullbore Pump*** Job Scope: Pump cement TxIAxOA to surface Plug #3. Pumped 30 bbls 60/40 Meth spear at slow rate verifying returns from ONIA taking returns to tank. Pump 30 bbls FW w/ U67 Musol + F-103 Surfactant down TBG out OA to returns tank. Pump 28 bbls FW w/ U67 Musol + F-103 Surfactant down TBG out IA to returns tank. Pump 23 bbls FW spacer down TBG out IA to returns tank. Mix 107 bbls 15.8 ppg Class G Cement and pump 57 bbls down TBG and out OA taking returns to tank. Good quality CMT returns observed and samples were taken by Guy Cook w/ AOGCC. _Pump 50 bbls 15,8 own TBG and out IA taking returns to tank. Good quality CMT returns observed and samples were taken by Guy Cook w/ AOGCC. 107 bbls total cement pumped. Shut in TxIAxOA and wash up surface lines and SLB equipment. Job complete RDMO. 2/6/2018 Cemented Tb xlAxOA 1300' to surface. Closed Swab Valve, SSV, IA and OA on cement T/I/O = SSVNACNAC. Temp = SI. WHPs (eval for P&A). Flowline removed. Cellar it full 5/17/2018 of ice. 20" conductor. T/I/O = SSVNACNAC. Temp = SI. WHPs ( eval for P&A). Well house and flowline,swab platform removed. Cellar it full of ice. 20" conductor. Installed visqueen hooch over cellar 5/18/2018 and installed heater. T/I/O = ONACNAC. Temp = SI. WHPs (eval for P&A). Well house and flowline,swab platform removed. Tag TOC @ surface in tubing. Heater in cellar working fine, cellar full of water vac truck called. 5/19/2018 SV, WV, SSV = C. IA, OA = OTG. 14:30 T/I/O = 0/0/10. Temp = SI. Excavate Around Wellhead (P&A). All WH strings cemented to surface. Bled OAP to 0 psi in 10 seconds. Excavated -5 cy of gravel @ 6 o'clock side of well cellar. Sloped the gravel 2/1 to cellar floor (-10' out from cellar). Cut cellar box (CMP) - 5' wide x -3.5' deep to cellar floor. Excavation Tag hung on barricades. Work area 5/26/2018 barricaded off and Open Excavation signs out. T/I/O = ONac/Vac. Temp = SI. Cut & Remove Wellhead (P&A). Used Hydraulic Crane to swing in Super-D Guillotine Saw and attach to wellhead. Rigged up crane to wellhead for removal after cut. Used Super-D Guillotine Saw to cut wellhead off @ -1' below pad grade. Staged wellhead on pad and cleaned up work area. Placed barricades around excavation 5/27/2018 and cellar. Strap TOC & Demobe (P&A). Used a weight and string to tag the TOC inT, IA & OA on cut off well. 3 1/2" T=170' (1.5 bbls), 3 1/2"x7" IA=115' (2.7 bbls), 7"x9 5/8" OA=45' (1.2 bbls). 5/28/2018 Load cut wellhead onto bed truck and haul to WS Valve Shop. Clean up work area. Cement Top of Cut Wellhead ()P&A). SLB Cement Crew mixed and pumped -9 bbls Class G Cement into T, IA & OA voids for top off job. 5/29/2018 Off location 16:00 JAOGCC Cut Off 4" TBG Top Post Wellhead Cut & Dress Wellhead for AOGCC Inspection (P&A). Used a battery powered sawzall to cut off remaining 4" of the TBG post wellhead cut and cement top job. Mixed and poured ASI concrete into top of cut to dress wellhead for 5/30/2018 inspection on 5-31-18. Installed temporary marker plate over casing stub (pictures taken). Cement and marker 5/31/2018 plate witnessed by Bob Noble (AOGCC). Daily Report of Well Operations V-201 Pull Cellar Box and Backfill (P&A). Used an excavator to pull the CMP cellar box and wood timbers. Backfilled cellar hole with —30 cy of gravel and compacted with the excavator 6/1/2018 bucket. Off location 18:30 TRff= 3-1/2"CJW WELLHAD= FMC ACTUATOR= NA KB. E EV = 82.1' BF. HEV = 53.15' KOP= 900 Max Angle = 36° @ 2380 ixen D= 4838' Datum TVD= 4400'SS SUSPENDED 8 CSG 1300' -13' 0'(6 SPF, 0/18) L-80 BTC, D Minimum ID = 2.812" @ 2201' 3-1/2" CAMCO SSSVN 13-1/2- TBG, 9.3#, L-80..0087 bpf, D = 2.992" PEWORATION SUMMARY REF LOG: ANGLEAT TOP P ERF: 32° @ 2775' Note: Refer to Production DB for historical pert data SIZE SPF MERVAL Opn/Sng DATE 2-117 6 2775-2780 S 01/14/18 2' 6 2870-2875 S 01/14/18 2-1/2" 4 4750-4765 S 03/03/07 2-1/T 4 4810-4830 S 03/03/07 2-1/2" 4 4845-4855 S 03/03/07 2-1/2" 4 4954-4989 S 03/03/07 L-80. D V— O SAFETY NOTES: —WELL HAS SHALLOW 1 SURFACE CASING LEAK... 976' 9-5/B' TAM PORT COLLAR CAMCO B-61 SSSV N, 2776' --278W 2-1/2', 6 spf, PERF THRU TBG 8 CSG 2870' - 2876' I OEV 2", 6 spf, PERF THRU TBG 8 CSG I VLV GAS LFT MANDRELS STJ MD I TVD I OEV I TYPE I VLV I LATCHI PORT 047E 3 12/15/07 TW/PJC PERF CORRC[;TIONS 12/04/O6 RAC/TLH TREECORREr-WN 19 MMG DMV RK 0 09/23/03 2 13814�34261 3904 3511 19 MMG DMY RK 0 01/01/02 1 3997 3597 19 MMG DMY RK 0 04/27/02 BX PROF, D = 2.812" HES X 13-1/2'WLEG.D=2.992- I W/ RA TAG 17- MARKER JT (20') VW RA TAG = 2.869" I ORION LUT WELL: V-201 PRIAT No: 2012220 API No: 50-029-23054-00 SEC 11, Tl l N, Rl l F 4838' NSL 8 1775' WEL DATE REV BY COMMENTS DATE REV BY COMMENTS 01101102 CHKAK ORIGINAL COMPLETION 11/30/07 TW/JPJC SHALLOW CSG LEAK SFTY NOTE1 04/01/05 ?"fTLH JETRJM/PKRS PULLED II/04 12/15/07 TW/PJC PERF CORRC[;TIONS 12/04/O6 RAC/TLH TREECORREr-WN 01/16118 DS/JkD CEMENT PLUG(01/14/18) 03/04/07 SRB/TLH PSA 02/01118 MS/JMD TBGICSG PUNCH 8 EL TAGGED TOC 03/08/07 GJB/PAG JET CUT@ 4062' ELM (03/07/07) 02108/18 GPUJMD CMT TO SURFACE (02106/18) BP Exploration (Alaska) 03/2507 JDA/PJC PERFORATIONS 06/13/18 ABIJMD SUSPENDED WELL (05/31/18) ♦ ♦ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ( 1 (4'stiQ DATE: 5/31/18 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector PBU V-201 . BP Exploration Alaska, Inc. PTD 201-222, Sundry 317-252 5/31/18: I traveled to BP's PBU V-201 to inspect the cut of the well, site and marker plate. AOGCC previously witnessed the cutoff and cement to surface on this well — but no marker plate installation —on February 6, 2018. On arrival, I met with BP rep Orvill Bass. All strings of pipe were full of good hard cement. The marker plate was a temporary, bolt-on type so that when they cut the well off to proper grade they can use the same marker plate. The cut off was 3 feet below pad grade, not tundra grade as required by the AOGCC. I inspected the wording and numbers on the plate. PBU V-201 will be considered suspended, not plugged and ,.- abandoned, as noted in the approved sundry. Attachments: Photos (3) SCANNED JUN 21 2018 2018-0531_Surface_Abandon_T emp_PBU_V-201_bn.docx Page 1 of 2 • 0 • 1 ., mak' ,\1 ` t - , , t �� " iy "°�i.. �g • w ,_ .. -$,.;''rir .Mtf•"T-.7 -A X:d'" \, , C -41T44, -4*2.40b"-- ,r "- . 4,. ... . .. ..;...44—...e. ''',-",a..,p,?-• 4.-,. , ei,-,,,' -„. U U O Kr._ 2. "„�'"'.. d` "�, t -r,( •iir 1 40 1 '< t: 4 t 7 t r .. cz`- :1 #5 r o ( , , j to q1, :IcV ct N''' .;`b h. +{gip J (; c. �. ). . .a s O S ( as . � r : if '^'tea , , N I f` , 4 N CZ r ilir ;� , iti Z !"it , ir vs n D3 ,u R , ":,,,','•+jj�� II o It ti F .may{ c$ " �.%r t . C r �'� {.V,�, y V cn 4 ' is k r i t4 O (NJ A%. r,� , • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (�� ZI6 10 DATE: 2/06/18 j1 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector PBU V-201 BP Exploration Alaska PTD 201-222 Sundry 317-252 2/06/18: I arrived on location at approximately 13:15 pm and met with Greg Lewis with BP. We talked about the job and discussed what was to be accomplished. They were currently having issues with freezing with their hardline and were taking steps to solve the issue. The plan was to pump cement to surface in the outer annulus first and then do the same in the inner annulus. Once the pumping started and the cement had reached surface from the outer annulus, I retrieved a sample of good cement from a sample port located in the choke trailer. The pumping was paused briefly to switch over to the inner annulus and then pumping started again. Once the cement had reached surface from the inner annulus I gathered another sample. Both samples of cement looked good to me. I took pictures of the uncured cement p samples and left location. fcasings at will include cut-offo Note: This is part of a partial surface abandonment that approximately 1 foot below the surface of the gravel pad (instead of 3 feet below original ground level as required by regulation) and installation of a temporary cap with well identification information. The well will continue in a Suspended status pending final cutoff and permanent marker plate installation per regulation. Attachments: none ill 2018-0206_Surface_Abandon_temp_PBU_V-201_gc.docx Page 1of1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission r TO: Jim Regg zil'r'S DATE: 1/30/2018 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Verification Petroleum Inspector PBU V-201 BPXA PTD 201-222; Sundry 317-252 1/30/2018: I traveled to BPXA's PBU V-201 well to witness a tag to locate the top of cement for an abandonment plug. When I arrived, I met with BPXA representative Mike Shaw. We went over the plugging work completed and discussed how they were going to tag the cement top. Mike told me that they had pumped 31 bbl of 15.8 ppg Class G cement. They had a Schlumberger E-line unit rigged up and pressure tested when I arrived on location. Mike told that they had 400 lbs of weight bar above the tool string. They also had a 1 3/4" flapper type bailer on the bottom of the tool string. They ran in the well and tagged the cement top at 2059 feet. I inspected the returns in the bailer after retrieving the tools from the well. The sample was the consistency of modeling clay. It had the feel, smell and color of cement. Attachments: none SCANNED ,. 2018-013 0_Plug_V erification_PBU_V-201_bn.docx Page 1 of 1 • S oF t // 7 e THE STATE Alaska Oil and Gas 41 � Of i0 L1SIKI\ Conservation Commission -,- n •ft Sit#_=__ 333 West Seventh Avenue *, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .. R Q, Main: 907.279.1433 A .SFax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Interventions & Integrity Engineer SCANNED JU�. 172 6 � BP Exploration(Alaska), Inc. P.O. Box 196612 • Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU V-201 Permit to Drill Number: 201-222 Sundry Number: 317-252 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 821CC—t Hollis S. French Chair DATED this day of July, 2017. RBDMS t,✓JUL 1 1 2017 STATE OF ALASKA ',ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend H ` Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Additional Suspend H 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-222 Exploratory 0 Development 0 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-23054-00-00 • 99519-6612 Stratigraphic 0 Service H, 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No H PBU V-201. RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: JUN 2017 ADL 028240 . PRUDHOE BAY,SCHRADER BLUFF OIL • � 1 f! 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Juhk no 5270 , 4892 ' 4434 4099 4434 None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 32-112 32-112 1490 470 Surface 2973 9-5/8" 32-3005 32-2755 5750 3090 Intermediate 5231 7"26# 29 5260 29-4883 7240 5410 Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2775-2875 5228-2642 3-1/2"9.2# L-80 27-4139 Packers and SSSV Type: 3-1/2"Baker Premier Ret.Pkr Packers and SSSV MD(ft)and ND(ft): 4080/3762 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H 14.Estimated Date for Commencing Operations: July 1,2017 - 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended H 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington,Aras J be deviated from without prior written approval. Contact Email: Aras.Worthington@bp.com Authorized Name: Worthington,Aras J Contact Phone: +1 907 564 4102 Authorized Title: Interventi ns&Integrity Enginee Authorized Signature: 1. ." Date: ec/ /...2-69, , ��'G• COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 t 7-- z.sZ. Plug Integrity b BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: /1/4, 17 / 4--C c..„ c G /n.,, ,pe c J- I' ✓ tO ✓-i 2-'' t 1 5 5 Gt 5 vl o J �t . 11 Yeo f"--L.-°I Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No Il Subsequent Form Required: /r - b APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 1 ( \1 CP/ , V`TL- 7-1 q-/[3- (1 RBDIIS til_ 1 1 2017 i, i ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate by • • V-201 Suspend Well Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Eric Zoesch (907) 564-4695 History GPB Well V-201 was initially drilled & completed in 2002 in the Schrader Bluff as a producer. The reservoir was P&A'd in 2007. The tubing was jet cut and the well was suspended. Subsidence drifts in 2016 had difficulty passing at several points between 500' and 2300' indicating possible subsidence casing/tubing deformation. The well has multiple integrity issues, is Not Operable as a result, and is reservoir abandoned. The tubing is cut at 4062' MD, and there are perfs through the tubing and casing if-2775'-2875' MD. A surface casing leak also exists. These integrity issues make this well unviable as a sidetrack candidate, so this well has no future utility. Objective Place cement plugs in the well. The well will remain in suspended status until final removal of the casings and welding of marker plate 3' below original Tundra level. Procedural steps DHD/Special projects 1. Cement SSSV Nipple control and balance lines. Fullbore 1. Pump cement down tubing, through perforations @ 2775' MD, and up OA to -2300' MD, then up IA to -2300' MD, and displace cement down tubing to -2300' MD via the following pump schedule: ➢ 31 bbls 15.8 ppg Class G cement ➢ Foam Ball ➢ 2 bbl FW spacer ➢ 18 bbls 9.8 ppg brine i. Take returns from the OA until 38 bbls total fluid away then SI OA and swap to taking returns from IA ii. Take returns from IA until 51 bbls total fluid away then SD pumping • • • Cement Design: BHST- 30 deg F BHCT-40 deg F a. Cement: Class G Unislurry cement- mix on the fly b. Density: 15.8 ppg c. Thickening time: 3 to 5 hrs d. API Fluid Loss: 150-250 cc (75-125 cc/30 min) e. Compressive Strength: Minimum of 2000 psi f. Pump time: 30 minutes at assumed rate of 1 bpm g. Volume: 31 bbls (pumpable) Slickline 1. Tag TOC, /ro fi ' "l .�1" a G-c C C fv ✓v f-1-'-e S S 2. Perforate through 3-1/2" tubing and 7" casing at 1300' MD. Fullbore 1. Pump cement down tubing, through perforations @ 1300' MD, and up OA to surface, then up IA to surface via the following pump schedule: ➢ 100 bbls 15.8 ppg Class G cement (18 bbls excess) i. Take returns from OA until clean cement returns are observed (est -10 bbls of returns from OA/58 bbls total fluid away). Then SI OA and swap to taking returns from IA. ii. Take returns from IA until 100 bbls total fluid away and SD pumping (approx. 8 bbls of returns from IA at that point). ✓1f, f'r yi c C r h 5 p tv Cement Design: '.e 55 C `mac`' t to 5 C �✓fa pi- a c- /- Ce`"'fnd BHST-20 deg F a Ste✓ Ft P—e. BHCT-40 deg F a. Cement: Class G Unislurry cement- mix on the fly b. Density: 15.8 ppg c. Thickening time: 3 to 5 hrs d. API Fluid Loss: 150-250 cc (75-125 cc/30 min) e. Compressive Strength: Minimum of 2000 psi f. Pump time: 30 minutes at assumed rate of 3 bpm g. Volume: 100 bbls (pumpable) 11b fio clvcvf� t wt� ✓k '' pp 1�5� aoc p ��-e s- cl�dc ; ap ✓ate� xhla k. Special Projects Vj'�'" Z z Tb-st 201 --2 1. Cut off all casings and we lhead -1' below pad level. Top off all annuli and tubing with cement as needed. Install marker'cap on outermost casing string. A-Pt Pt �o--aZ4 23 -oaf' Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. at� Gil� G v wi e- t 5" l 2 III IIII 1-Rli= 3-1/2"CIW SAFETY NOTES:**int ELL HAS SHALLOW VVELHEAD= FMC V-201 Current SURFACE CASING LEAK*** ACTUATOR= NA KB.ELEV= 83.5' BF.ELEV = 60.3 ... u75' H9-5/8"TAM FORT COLLAR ..._ KOP= 900' Max Angle= 36 @ 2380' ----- Datum AID= 4838' I 2201' H3-1/2"CAACO B-6I SSSVN,ID=2.812" Datum TV D= 4400'SS 0 . _ , .., _,, 2775'-2780'H2-1/2".6 spf,PERF TFIRU TBG&CSG I i ; , (//,'' main@ A 2870' -2875'H2",6 spf,PERF THRU TBG&CSG 9-5/8"CSG.404 L-80 BTC,ID=8.835' —I 3001' 1-41 IL GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3814 3426 19 MIViG DMY RK 0 09123/03 Minimum ID =2.812" @ 2201' 2 3904 3511 19 WAG DMY RK 0 01/01/02 3-112" CAMCO SSSVN 1 3997 3597 19 WAG DMY RK 0 04/27/02 II I I 4052' I—3-1/2"BKR CMD SLD SLV W/BX PROF,ID=2.812" 4062'ELM H JET CUT(03/07/07) I X I 4077' HT'X 3-1,7 BKR PREMIER FKR El=2.869' I I 4102' H3-1/2"FES X NP,13=2.813" I I 11---1 4123' H3-1/2"HES X NE 10=2.813" I 13-1I2 TBG,9.3#.L-8C,.0087 bpf.ID=2.992" H 4135' / \ I 4141' H3-1/2"WLEG.ID=2.992' I 7,14434S LM H TOP OF Ct3ENT(03/06/07) I PERFORATION SLAW RY Rif LOG: effeefeffe 4500' TOP OF CEMENT(03/04/07) ANGLE AT TOP PERF: 32 @ 2775' •••••••••• 0.......** Note:Refer to Production DB for historical perf data ••1*...S... 1.4..141 t-- 4690' H7'MARKER JT(20)W/RA TAG I •••••••••• SIZE SPF INTERVAL OpniSqz DATE 1••••••11. .111...... 2-1/2" 6 2775-2780 0 03/25/07 14•41.1**0 2" 6 2870-2875 0 03/25/07 •••••••1..... •••••••• 1 •••••••••• 2-1/2" 4 4750-4765 S 03/03/07 ••••••1.111 •••••••••• 2-1/2" 4 4810-4830 S 03/03/07 •••••••••01 •••••••••• •••••••••• 2-1/2' 4 4845-4855 S 03/03/07 .0..444410 2-1/2" 4 4954-4989 S 03/03/07 •••••••••• 1••••••••0•' 4871' -7-MARKER JT(20)W/RA TAG •••••••••• ........1* ......•••• .........V ••••••••14 1•••••••••4 I 497'7' H TOP OF FILL(03/4/07)I PBTD 5157' Ov.V.V•VOY •••••••••• •••••••••• ••••••••14 kl letytttat MI T'CSG,26#,L-80,ID=6.276" H 5257' WAMIVA•AvAvAvAvA,A7 DATE REV BY COMMENTS DATE REV BY CON/VENTS I ORION UNIT 01/01/02 CH/KAK ORIGINAL COMPLETION 11/30/07 TW/JPJC SHALLOW CSG LEAK SFTY NOTE WELL: V-201 04/01/05 ?T.1/TI_H JET PUMRPKRS RJLLED 11/04 12/15/07 TW/PJC PERF ORI TONS PERMIT No: 2012220 12/04/06 RAGTLH TREE CORRECTION - AR No: 50-029-23054-00 . . 03/04/07 SREVTLH P&A SEC 11.T11N,R11E.4838'NSL&1775 WEL 03/08/07 GJB/PA 0 JET CUT @ 4062'ELM(03/07/07) 03/25/07 JMF/PJC PERFORATIONS BP Exploration(Alaska) _. .... . 3 • • TREE= 3-1/2"GW V201 Suspended IOTES: CASING LEEAKKL HAS SHALLOW - WELLHEAD= FMC .., ACTUATOR= NA KB.ELEV= 83.5' �,� BF.ELEV= 60.3' ( fitJ KOp_ , Fullbore cement from Surface to Max Angle= 36 @ 2380' j111g Datum nn 4838' f' 1300' MD in tbg, IA, and OA Datum TVD= 4400'SS Ell Fullbore cement from 2300' MD to ' 2800' MD in tbg, IA, I9-5/8"CSG,40#L-80 BTC,U=8.835" H 3001' '—A and OA © ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3814 3426 19 MIG DMY RK 0 09/23/03 Minimum ID =2.812" @ 2201' 2 3904 3511 19 MMG DMY RK 0 01/01/02 3-1/2" CAMCO SSSVN 1 3997 3597 19 MMG DMY RK 0 04127/02 I 4052' u 3-112"BKR CID SLD SLV f W/BX PROF,D=2.812" /\/t/ 14062'ELM H JET CUT(03/07/07) 1 S X- 4077' H 7"X 3-1;2"BKR FRIMER PKR,U=2.869" ' I I 4102' H3-1/2"HES X NIP.U.=2.813" ' I I 4123' H3-1/2"HESXNP,D=2.813" I 3-1/2"TBG,9.34,L-80,.0087 bpf,D=2.992" H 4135' i \ 4141' —13-1/2"WLEG.D=2.992" 1 "714434'SLM HTOPOF CENENT(03/06107) I PERFORATION SUMMARY REF LOG: 1111141111 I 4500' HTOPOF CEMHfT(03/04/07) ANGLE AT TOP PERF: 32 @ 2775' +�/�..�.�.�.�.�.�1 Nate:Refer to Production DB for historical perf data 11141111114411411411t-• 4690' 7"MARKER JT(20')W/RA TAG SIZE SPF INTERVAL Opn/Sqz DATE 11111111114141114111 H 2-1/2" 6 2775-2780 0 03/25/07 11411111114111114111 2" 6 2870-2875 0 03/25/07 1111111111111111111. 00..00 2-1/2" 4 4750-4765 S 03/03/07 11141/11111111411414 2-1/2" 4 4810-4830 S 03/03/07 11111111111111111114 2-1/2" 4 4845-4855 S 03/03/07 11111111111111111411 2-1/2" 4 4954-4989 S 03/03/07 11111111111111111111 11141114111414111111 4871' H7"MARKER JT(20')W/RA TAG 14141114111444141411 1 � 1�1�11•1�111� . 1�1• 11111111114 4977' TOP OF FLL(03/4/07) PBTD —i 5157' 1'1141191 .' 11111114411111111111 111111111111111111114 7"CSG,26#,L-80,U=6.276" —I 5257' 1.1.4.1.1.1.1.1.1.1.4; DATE REV BY COMMENTS DATE REV BY COMMENTS I ORION UNIT 01101/02 CH/KAK ORIGINAL COMPLETION 11/30107 TWIJPJC SHALLOW CSG LEAK SFTY NOTE WELL. V-201 04/01/05 ???/TLH JET PUMP/PKRS FULLED 11/04 12/15/07 TW/PJC PERF CORRECTIONS PERK T No: 2012220 12/04/06 RAC/'TLH TREE CORRECTION API No: 50-029-23054-00 03/04/07 SRB/TLH P&A SEC 11,T11N,R11E,4838'NSL&1775'WEL 03/08/07 GJB/PAG JET CUT @ 4062'ELM(03/07/07) 03/25/07 JMF/PJC PERFORATIONS BP Exploration(Alaska) 4 . • Loepp, Victoria T (DOA) From: Worthington,Aras J <Aras.Worthington@bp.com> Sent: Wednesday,July 05,2017 1:36 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU V-201(PTD 201-222, Sundry 317-252)Suspend Follow Up Flag: Follow up Flag Status: Flagged Victoria, My apologies for the delayed response, I was out of the office on Monday and Tuesday this week. Yes the cement plug on V-201 was tagged and PT'd as follows: Hard tag on 3/4/2007 with CT and 2.3" Nozzle @ 4500' CTM MITT Passed on 3/5/2007 to 2000 psi Aras Worthington Well Interventions & Integrity Engineer BP Alaska Inc. Office: (907) 564-4102 Cell: (907)440-7692 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,July 03, 2017 9:12 AM To: Worthington, Aras J Subject: PBU V-201(PTD 201-222, Sundry 317-252) Suspend Aras, When the reservoir was abandoned in 2007,was the TOC tagged and PT? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(c�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victorialoepo@alaska.gov 1 •u of T„ • , ,,,,,,„„. THE STATE ye' .-s='�.�,�► Alaska Oil and Gas h: �„ ? � °fALA�KA ato Conservation Commission OM ii + ”` 333 West Seventh Avenue rti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 01' Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 15, 2016 Ryan Daniel Well Integrity Engineering Team Leader BP Exploration (Alaska), Inc. SCANNED APR 2 8 2017; P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: OTH-16-038 Prudhoe Bay Unit (PBU) Well Plug and Abandonments for 2017 By letter dated November 2, 2016, BP Exploration (Alaska), Inc. (BPXA) proposed a multi-year well plug and abandonment(P&A) program. The Alaska Oil and Gas Conservation Commission (AOUCC) approves the P&A program for the wells listed below for the calendar year 2017. p �b Zot2ZZo 1. V-201 Rig P&A 2. J- Non rig P&A 3. R-01 Non rig P&A 4. C-38 Non rig P&A 5. 18-34 Non rig P&A 6. 05-18 Non rig P&A This program was developed as an alternative to P&A's required due to the suspension expiration this year of 18 wells (20 AAC 25.110). BPXA has proposed a level loaded P&A program that prioritizes all P&A candidates based on well mechanical condition and the associated risks with impaired barriers. The wells are assumed to have no future utility to be considered P&A candidates. The process proposed for development and AOGCC approval of the P&A program for future years is described as follows. Prior to or during the fourth quarter of each year, BPXA will propose to the AOGCC the P&A candidates for the upcoming calendar year as well as a plan for the two subsequent years. The AOGCC will review the proposal considering number of P&A's proposed, the number of rig decompletion P&A's planned versus non rig P&A's as well as the P&A well stock composition and number. The pace of the P&A program approved by the AOGCC may require adjustment based on the number and status of P&A stock wells. BPXA has the option to return to performing the required P&A's based on suspension expiration date if agreement cannot be reached on the level loaded pace and composition. ' Docket Number: OTH-16-038 • • December 15,2016 Page 2 of 2 Approximately 90 wells are suspended and will require P&A in the next 10 years. To facilitate the level loaded approach based on risk, the AOGCC is requesting that the following information for suspended wells be provided in table format before March 31, 2017. 1. Well name 2. Permit to Drill (PTD) number 3. Date suspension expires 4. Mechanical condition of the well 5. Qualitative assessment of risk 6. Future Utility 7. Rig decompletion required for P&A or nonrig P&A 8. Comments It is understood that this table will be dynamic and updated as information becomes available. It is recommended that BPXA start the annual process well in advance to allow co-owner review and approval of AOGCC requirements prior to year end and to also allow the P&A's to be accomplished during the following calendar year. Please direct any comments or questions to Victoria Loepp at Victoria.loepp@alaska.gov. Sincerely, aiee / 'tom-- Cathy P. Foerster Chair, Commissioner . • • Colombie, Jody J (DOA) From: Regg,James B (DOA) Sent: Friday, November 04, 2016 2:28 PM To: Colombie,Jody J (DOA) Subject: FW: Request for approval to implement well plug and abandonment strategy Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907-793-1236 orjim.regg@alaska.gov. From:Carlisle,Samantha J (DOA) Sent:Wednesday, November 02,2016 2:32 PM To: Foerster,Catherine P(DOA)<cathy.foerster@alaska.gov>; French, Hollis(DOA) <hollis.french@alaska.gov>;Seamount, Dan T (DOA)<dan.seamount@alaska.gov>; Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>; Davies,Stephen F(DOA) <steve.davies@alaska.gov>; Quick, Michael J (DOA)<michael.quick@alaska.gov>; Regg,James B(DOA)<jim.regg@alaska.gov>; Roby, David S(DOA)<dave.roby@alaska.gov>; Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov>; Wallace,Chris D(DOA) <chris.wallace@alaska.gov> Cc: Ballantine,Tab A(LAW)<tab.ballantine@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: Request for approval to implement well plug and abandonment strategy I scheduled for December 1st at 10am.If that doesn't work,please let me know. From: Foerster,Catherine P (DOA) Sent:Wednesday, November 02, 2016 2:17 PM To: French, Hollis(DOA)<hollis.french@alaska.gov>;Seamount, Dan T(DOA)<dan.seamount@alaska.gov>; Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov>; Davies,Stephen F(DOA)<steve.davies@alaska.gov>; Quick, Michael J (DOA) <michael.quick@alaska.gov>; Regg,James B(DOA)<iim.regg@alaska.gov>; Roby, David S(DOA)<dave.roby@alaska.gov>; Schwartz,Guy L(DOA)<guv.schwartz@alaska.gov>;Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc: Ballantine,Tab A(LAW)<tab.ballantine@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Carlisle, Samantha J (DOA)<samantha.carlisle@alaska.gov> Subject: FW: Request for approval to implement well plug and abandonment strategy All, Victoria has been working with BP on their request to have a different P&A priority than simply going off suspended date. Their proposal is attached. They request approval by year-end; so we can take care of this upon Victoria's return, but I'd like you all to consider if there is any downside to accepting this proposal in lieu of requiring them to P&A all suspended wells. Sam, please calendar a time for us to discuss when Victoria and I are both back. Thanks. Cathy 1 • • From: Daniel"-Ryan [mailto:Ryan.Daniel@bp.com] Sent:Wednesday, November 02,2016 2:01 PM To: Foerster,Catherine P(DOA)<cathy.foerster@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Quick, Michael J (DOA)<michael.quick@alaska.gov> Subject: Request for approval to implement well plug and abandonment strategy Dear Chair Foerster, Please find attached an email copy of a letter requesting approval to implement the PBU well plug and abandonment strategy that we have been discussing and reviewing with your staff since mid-year.The signed original is in the mail. Let me know if you have any questions Sincerely Ryan Daniel (Wells Intervention and Integrity ETL for BPXA) 2 • • bp BP Exploration(Alaska)Inc. Ryan Daniel,Well Integrity Engineering Team Leader Post Office Box 196612 Anchorage,Alaska 99519-6612 RECEIVED NOV 022016 November 2nd, 2016 AOGCC Cathy P. Foerster Commission Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Request for approval to implement well plug and abandonment strategy Dear Chair Foerster, BP Exploration (Alaska) Inc. (BPXA), as operator on behalf of the Prudhoe Bay Unit (PBU) working interest owners, requests approval to implement a multi-year well plug and abandonment (P&A) program in lieu of AOGCC requirements regarding P&A of certain observation and suspended wells. Currently, AOGCC sundry approvals and other orders require P&A plans of the wells listed in Attachment 1 by the end of 2016. BPXA requests approval, in lieu of that requirement, to institute a multiyear level loaded P&A program that prioritizes P&A well candidates based on: (a) well future utility benefiting PBU hydrocarbon recovery, and (b) well mechanical condition and associated risk factors. Two technical meetings have been held with AOGCC engineering staff members in the last few months to review the proposed P&A program. Subsequently, AOGCC Senior Petroleum Engineer Victoria Loepp requested, by email on 9/20/2016, submission of a written request. If the AOGCC approves this request, then BPXA will submit a 3 year forward looking P&A plan to the AOGCC in the 4th quarter of every year. The plan would include a review of the status of the previous year's plan. The wells listed in the P&A plan could change from year to year, as the well population is dynamic in nature, and assessments of future well utility benefiting PBU hydrocarbon recovery and well conditions and risk factors may change with time. • • IP BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 2 of 6 BPXA proposes, as the initial annual P&A plan, the following: Year 1: To be scheduled in the 2017-2018 time frame List Well Name Well Status Scope 1 V-201 Suspended Rig P&A 2 J-26 Not Operable Non Rig P&A 3 R-01 Not Operable Non Rig P&A 4 C-38 Not Operable Non Rig P&A 5 18-34 Not Operable Non Rig P&A 6 05-18 Not Operable Non Rig P&A Year 2: To be scheduled in the 2018-2019 time frame List Well Name Well Status Scope 1 B-02 Suspended Rig P&A 2 05-18 Not Operable Non Rig P&A 3 15-03 Not Operable Non Rig P&A 4 15-10 Not Operable Non Rig P&A 5 18-25 Not Operable Non Rig P&A 6 13-10 Not Operable Non Rig P&A Year 3: To be scheduled in the 2019-2020 time frame List Well Name Well Status Scope 1 G-03 Not Operable Rig P&A 2 H-04 Not Operable Non Rig P&A 3 N-03 Not Operable Non Rig P&A 4 D-27 Not Operable Non Rig P&A 5 Y-12 Not Operable Non Rig P&A 6 Y-08 Not Operable Non Rig P&A While it is BPXA's intention to P&A these wells as scheduled, efforts may be impacted by well status changes and by environmental and other risk factors and restrictions affecting the P&A program. A multiyear level loaded P&A program ensures that BPXA has the flexibility to preserve well stock that has potential future utility benefiting PBU. It is also both more efficient in terms of implementation and execution over time with available contractor Rig/Non Rig intervention equipment and workforce, and establishes a more "fit for purpose" and risk based approach to end of life well stock management. For information purposes Attachment 2 contains a list of all currently suspended PBU wells. • • ! BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 3 of 6 In summary, BPXA believes the proposed multiyear level loaded P&A strategy provides a more beneficial, efficient and risk based approach to management of "end of life" well stock than a P&A strategy based on suspended well renewal dates. BPXA respectfully requests AOGCC approval to implement the proposed P&A program in lieu of progressing the P&A plans for wells listed in Attachment 1 by the end of 2016. If you have any questions, please call me at 748-1140 Sincerely, /47/ Ryan Daniel BPXA Wells Integrity Engineering Team Leader • • ! BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 4 of 6 Attachment 1: AOGCC Required P&A list List Well Name Well Status Scope 1 BP-03-11-13 Observation Non Rig P&A 2 BP-01-10-14 Observation Non Rig P&A 3 BP-02-10-14 Observation Non Rig P&A 4 BP-11-10-14 Observation Non Rig P&A 5 BP-17-10-15 Observation Non Rig P&A 6 BP-13-10-14 Observation Non Rig P&A 7 BP-14-10-14 Observation Non Rig P&A 8 BP-19-10-15a Observation Non Rig P&A 9 BP-19-10-15b Observation Non Rig P&A 10 BP-19-10-15c Observation Non Rig P&A 11 WGI-01 Suspended Non Rig P&A 12 2-30 Suspended Non Rig P&A 13 G-13 Suspended Non Rig P&A 14 V-201 Suspended Non Rig P&A 15 S-14 Suspended Non Rig P&A 16 W-09 Suspended Non Rig P&A 17 Y-25 Suspended Non Rig P&A 18 J-30 Suspended Non Rig P&A f f ~ ` • • BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 5 of 6 Attachment 2: Suspended well list dated 24th Oct 2016 Suspended Wells -AOGCC Suspend PTD BP Exploration (Alaska) Inc Suspended Number: Renewal Wells Expires: PRUDHOE BAY UNIT K-13 1871010 1/6/2020 PRUDHOE BAY UNIT B-02A 1961110 3/1/2020 PRUDHOE BAY UNIT 04-12 1780180 3/15/2020 PRUDHOE BAY UNIT Y-22A 1881150 9/2/2020 PRUDHOE BAY UNIT R-36 1941440 9/2/2020 PRUDHOE BAY UNIT H-12 1800670 9/2/2020 PRUDHOE BAY UNIT U-01 " 1920110 9/2/2020 PRUDHOE BAY UNIT H-10A 1971900 9/2/2020 PRUDHOE BAY UN LIS L3-01 1890750 9/3/2020 PRUDHOE BAY UNIT Y-37A 2020460 9/27/2020 PRUDHOE BAY UN WBH WBST-03 1760340 9/27/2020 W BEACH ST 1-A 1860560 9/27/2020 PRUDHOE BAY UNIT 07-27 1870820 9/27/2020 PRUDHOE BAY UN PTM 12 1910370 9/27/2020 PRUDHOE BAY UNIT S-10A 1911230 11/2/2020 PRUDHOE BAY UN PTM P2-55 1920820 11/2/2020 PRUDHOE BAY UN NIA NK-41A 1971580 11/2/2020 PRUDHOE BAY UN NIA NK-11A 2020020 ! 11/2/2020 PRUDHOE BAY UNIT 04-04A 1950240 11/19/2020 PRUDHOE BAY UNIT 14-39 1881380 11/20/2020 SOURDOUGH 3 1960080 1/5/2021 PRUDHOE BAY UN BORE 02-01 1980350 1/5/2021 PRUDHOE BAY UN NWE 04-01 2020520 1/5/2021 PRUDHOE BAY UNIT 06-17 1820900 3/4/2021 PRUDHOE BAY UNIT A-41 1941580 3/18/2021 PRUDHOE BAY UNIT H-15 1810610 3/30/2021 PRUDHOE BAY UN PBU L2-18A 1981060 9/7/2021 PRUDHOE BAY UNIT 15-47 1951740 12/24/2021 PRUDHOE BAY UNIT 09-44/09-44A 2091570 3/19/2022 PRUDHOE BAY UNIT OWDW-SW 1002380 4/9/2022 PRUDHOE BAY UNIT F-11 B 2041940 5/27/2022 PRUDHOE BAY UN LIS LGI-08 1860570 9/5/2022 PRUDHOE BAY UNIT 13-05 1811030 11/24/2022 • BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 6 of 6 PRUDHOE BAY UNIT 07-10 1980160 12/13/2022 PRUDHOE BAY UNIT 04-26 185314 6/16/2023 PRUDHOE BAY UNIT Y-02 2011730 9/24/2023 PRUDHOE BAY UNIT 09-07 1990220 2/26/2026 DRILLPAD Z NO 08A 1931280 10/2/2023 PRUDHOE BAY UN LIS L4-02 1891040 11/14/2023 PRUDHOE BAY UNIT Z-70 2131330 1/18/2024 E BAY STATE 1 " 1740060 4/24/2024 PRUDHOE BAY UNIT 13-98 1822070 4/24/2024 PRUDHOE BAY UNIT M-05A 1970810 6/6/2024 PRUDHOE BAY UNIT 18-09 1980790 7/7/2024 PRUDHOE BAY UNIT G-30 2091510 7/27/2024 PRUDHOE BAY UNIT Z-68 2130930 8/26/2024 PRUDHOE BAY UNIT F-12 1791070 7/1/2025 PRUDHOE BAY UNIT 15-24 1911280 9/11/2025 AURORA UNIT S-108 2011000 9/11/2025 PRUDHOE BAY UNIT Y-38 1950460 9/11/2025 PRUDHOE BAY UNIT WGI-01 1790310 10/31/2025 PRUDHOE BAY UNIT 02-30B 2001260 10/31/2025 PRUDHOE BAY UNIT G-13A 2001630 10/31/2025 PRUDHOE BAY UN ORIN V-201 2012220 10/31/2025 PRUDHOE BAY UNIT S-14A 2040710 10/31/2025 PRUDHOE BAY UNIT W-09A 2041020 10/31/2025 PRUDHOE BAY UNIT Y-25A 2081400 10/31/2025 PRUDHOE BAY UNIT J-30 2140750 11/17/2025 PRUDHOE BAY UNIT E-18B 2041390 12/31/2025 PRUDHOE BAY UN NIA NK-14A 2060310 12/31/2025 DRILLPAD I NO 100 2050100 12/31/2025 PRUDHOE BAY UNIT 04-07 1750770 3/29/2026 STATE OF ALASKA IDALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Sus Well Inspection Rpt 10 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 201-222 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-23054-00-00 7. Property Designation(Lease Number): ADL 0028240 8. Well Name and Number: ORIN V-201 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUF OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 5270 feet Plugs measured 4434 feet 1 4 true vertical 4892 feet Junk measured feet N O V 2016 Effective Depth: measured 4434 feet Packer measured 4110 feet true vertical 4099 feet Packer true vertical 3791 feet u C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 2973 9-5/8"40#L-80 32-3005 32-2755 5750 3090 Intermediate 5231 7"26#L-80 29-5260 29-4883 7240 5410 Production Liner Perforation Depth: Measured depth: 2775-2780 feet feet 2870-2875 feet 4750-4765 feet 4815-4818 feet 4818-4830 feet 4845-4855 feet 4954-4989 feet True vertical depth: 2558-2562 feet feet 2638-2642 feet 4399-4413 feet 4461-4463 feet 4463-4475 feet 4489-4499 feet 4592-4626 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 27-4169 27-3847 Packers and SSSV(type,measured and 3-1/2"Baker Premier Ret.Pkr 4110 3791 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 3 IH17, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 226 162 0 2020 329 Subsequent to operation: Shut-In 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development ❑ Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 1/73 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R'(Wipro) Title PDC Principal Engineer Signature /;j4�,.� Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 V71 Z` I 1 ,46// RBDMS '-"NOV 1 6 2016 Submit Original Only • • N O >- m < E a) z aL Q 70 5 O d N O = I L � 0OU QI cn m W N Q 0 >-• O to m • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Pad V No 201 Field/Pool: Prudhoe Bay Field/Orion Schrader Bluff Permit#(PTD): 2012220 API Number: 50-029-23054-00-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended 1/25/2008 Surface Location: Section 11 Twsp: 11N Range: 11E Nearest active pad or road: L-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Gravel Pad, Ongoing subsidence work, crews and equipment on location Pad or location surface: Level Gravel Pad Location cleanup needed: Concrete pieces behind wellhouse from flowline support Pits condition: N/A- No pits on V-pad Surrounding area condition: Good Water/fluids on pad: Frozen Puddles Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Gravel Road Photographs taken (#and description): 3 photos-Wellhouse, Concrete debris, area behind wellhouse 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 Production Tree, no flowline, blinded, subsidence well, landing ring sitting out of conductor 1' Cellar description, condition, fluids Gravel with metal walls, water in cellar no hydrocarbons Rat Hole: none Wellhouse or protective barriers: Wellhouse, good condition Well identification sign: Yes Tubing Pressure(or casing if no tubing): SSV Closed no hydraulic panel Annulus pressures: IA=Opsi, OA=Opsi Wellhead Photos taken (#and description) 2 photos -wellhead/tree Work Required: Subsidence repairs, area needs cleanup post pad work. Operator Rep(name and signature): Joshua Stephens AOGCC Inspector: Jeff Jones Other Observers: Inspection Date 10/10/2016 AOGCC Notice Date 10/9/2016 Time of arrival 3:53 PM Time of Departure: 4:05pm Site access method Pickup Truck • • (..,, 0.05 0.025 0 0.05 Miles 0 b , ,i‘ , ^v-264 P B 1 \\\\1 Ii‘ \ ;°- V-N)I : 1'-3 'l \\\ - e Legend )1100K077,, / ::; :::::: %:?"101011111°":"7 /fir I.' r, , ' ,,, \ iptio040° —WA(; Noi.,_ iifti ''''. —Water `"' —Relief —Utility ...0 Unknown G, c& % 41. —Selected Pipelines L 0 7, - •. — J 4 k ,,•41. `'7a 1 .4' g, a `r. 1. ^.lk V-217 _ Author: �"�w 14 November,2016 BP1\catrgl ©BP Exploration(Alaska)Inc.Alia rights reserved.rhes map is informational in nature and is presented without representaeons or Product of BPXA Atlas Enterprise GIS. alaska- is.b web.b .com a.as m accuracy,completeness,or use for any purpose P 9 P P TREE= 3-1/2"CIW • SA"NOTES:***WELL HAS SHALLOW WELLHEAD= ACTUATOR= FNA V_2 0 MC SURFACE CASING LEAK*** KB.ELEV= 83.5' BF.ELEV= 60.3' 975' —19-5/8"TAM PORT COLLAR KOP= 900' Max Angle= 36©2380' Datum MD= 4838' 2201' H 3-1/2"CAMCO B-61 SSSVN, ID=2.812" © Datum TVD= 4400'SS 0 fl 'I 2775' -2780' —12-1/2",6 spf,PERF THRU TBG&CSG I I 2870'-2875' —12",6 spf,PERF THRU TBG&CSG 9-5/8"CSG,40#L-80 BTC,ID=8.835" — 3001' —41 GAS LIFT MANDRELS Li ST MD TVD DEV TYPE_ VLV LATCH PORT DATE 3 3814 3426 19 MMG DMY RK 0 09/23/03 Minimum ID = 2.812" @ 2201' 2 3904 3511 19 MMG DMY RK 0 01/01/02 3-1/2" CAMCO SSSVN 1 3997 3597 19 MMG DMY RK 0 04/27/02 I I I 4052' F—3-1/2"BKR CMD SLD SLV W/BX PROF, ID=2.812" /\/V 4062'ELM H JET CUT(03/07/07) R 4077' --17"X 3-1/2"BKR PREMIER PKR,ID=2.869" 4102' —3-1/2"HES X NIP, ID=2.813" I I 4123' —I 3-1/2"HES X NIP, ID=2.813" 3-1/2"TBG,9.3#,L-80,.0087 bpf, ID=2.992" H 4135' 4141' —13-1/2"WLEG,ID=2.992" 4434'SLM I—TOP OF CEMENT(03/06/07) PERFORATION SUMMARY REF LOG: 11111111111 4500' H TOP OF CEMENT(03/04/07) ANGLE AT TOP PERE: 32©2775' 11111111111111111111 Note:Refer to R-oduction DB for historical perf data 111/1111111111111111 4690' 7"MARKER JT(20')W/RA TAG SIZE SPF INTERVAL Opn/Sqz DATE 11111111111111111111 2-1/2" 6 2775-2780 0 03/25/07 11111111111111111111 2" 6 2870-2875 0 03/25/07 11111111111111111111! 1111111111 2-1/2" 4 4750-4765 S 03/03/07 1111111111111/111114 2-1/2" 4 4810-4830 S 03/03/07 11111111111111111111' 2-1/2" 4 4845-4855 S 03/03/07 11111111111111111111 1111111111 2-1/2" 4 4954-4989 S 03/03/07 .1/111111111111111111 4871' H7"MARKER JT(20')W/RA TAG 111111111111111/11111 111/111111111/1/111. 1/111/1111111111111. �� 4977' H TOP OF FILL(03/4/07) PBTD 5157' 1111111111 11111111111111111111 111111111111111111111 7"CSG,26#,L-80,ID=6.276" --I 5257' 1.1.1.1.1.1.1.1.1.1.1. DATE REV BY COMMENTS 1 DATE REV BY COMMENTS ORION UNIT 01/01/02 CH/KAK ORIGINAL COMPLETION 11/30/07 TW/JPJC SHALLOW CSG LEAK SFTY NOTE WELL: V-201 04/01/05 ???/TLH JET PUMP/PKRS PULLED 11/04 12/15/07 TW/PJC PERF CORRECTIONS PERMIT No: 2012220 12/04/06 RAC/TLH TREE CORRECTION AR No: 50-029-23054-00 03/04/07 SRB/TLH P&A i SEC 11,T11N,R11E,4838'NSL&1775'WEL 03/08/07 GJB/PAG JET CUT @ 4062'ELM(03/07/07) 03/25/07 JMF/PJC PERFORATIONS BP Exploration (Alaska) 1 •, IIF a 0 t 0 p f ', { rtL x' r X51 rt 4. ''',';''''''''':i',.4*.:1 '' lists , . ; ,.. . at z est . , ... .113kil...,, ,.,. .:.,...- ;.....--._, ',.::.0.,, yy u� v mow. § ^ • gym 1► { M .. w ft 4040 ^ , m.. Itj 1 . WELL N, 1 4 ;il'1 ftAl?,tt 4 r.r'I u,fanitl 11 k 'J)I: I'f'AlI,)N , Iii'li Itir, Pi kFAI I i P. s' I ‘0,„'' ' ''m„ it ii't ,..,, . '... . ' . , . I , , .., , , . .. • k . ng r p ._ , . sr •�#'. 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'''''''''' ' '''' • •, '" a -y .. ti . �, .t , rc s` ftYa`r T:" • ♦ }$s, t I �/ A�J"�, t, -:',':; le-1, TT yM r ' Y „ t 7 a I,. , Y,,y.s 3 ,p • -.. i a a 'S w - - Y ... , a , , ,,..,,, . .......-, ,VIZi'''''..*' '.0,'''''' (1) i., ..„. a .,,,,,.,„:,,,r,..;:.,,,,,i,4y(4.,,,,, ,,•,,,,,41.,,,,,o..,-..,,,,,,tsv-,0,-.140...v.,011.4,,,,,„14,;,,,,.....s ,„...,.....i.,,,,,r,,„, 4.,:...,,,, „..,„ T!.„. .,._ .. . ., .. .1.1.,k,.;1:':16i.'.....;Eii..c., •,. . .',.1..'..1 .......',..'I'' .'-' . .. .... . .. .. ti,„. ..„6.,...„iiir.v.„-,ity,„•:_ . --,: mil: , .,. . .. ,„ . ....... .. _ , .„ . „,,?4,.. .......„:„_.„..... „.. . . , . ,,._..z.:,„. ...„...,, ., ,,, .:,,.., . . ..,,,....,,,,•....„. .4 -.°4 - • ,, .,.-4- ... .., '''''' 4.--, •-,-.- if ,...50:4:::,,,z„:".e.s:".. ,.....:::4.,,,,,,,,, at? ,,, ,,,tliti, , ,_,,,,,,,, :,, „"'''' „,,,, ,....., , ( '''''*, • -' '' '''..-''''':, .,..,, , - ,.....,, ,..... .„.„,„ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU V-201 • Oper. Rep: J.Stephens PTD No.: 2012220 Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: ioshua.steohens(cabo.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 01/25/08 Date AOGCC Notified: 10/09/16 Sundry No.: Well Completion Report Type of Inspection: Subsequent ' Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: Good condition,wing valve,master valve,SSV closed&hydraulics disconnected.Outlet is blinded.Surface casing landing ring out of conductor(subsidence). Condition of Surrounding Surface Level gravel pad with road access,no visible hydrocarbon residue.Some concrete chunks behind wellhouse.Wellhouse in good Location: condition. Follow Up Actions Needed: Investigate&mitigate wellhead subsidence issue.Clean up concrete behind wellhouse. Comments: Well identified by pad map and well sign permanently attached to wellhouse.Mr Stephens took photos at my direction&they are attached to his report. Attachments: none - S(�At4NED j N 0 8 2 f!' REVIEWED BY: aivrr+�� Insp.Supry J 1(110I 1L, Comm PLB 12/2015 2016-1010_Suspend_PBU_V-201 jj.xls F 1714' y • O 4 s THE STATE • % Alaska Oil and. Gas �� ►"'��—.�� of / SKA Conservation Commission .Ex 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1 02 r. Main: 907.279 1433 ALAS Fax: 907.276.7542 sCi N E NOV 1 ca 2015 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity & Compliance Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 ,Q Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, ORIN V-201 Sundry Number: 315-579 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r4t-vik_ Cathy . Foerster Chair DATED this 2-a day of October, 2015 Encl. RBDMS NOV 0 2 2015 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 5 v$/21N , h:r k1-Gev�_l 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-222 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612Stratigraphic 0 Service a 6. API Number: 50-029-23054-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No D ORIN V-201 . RECEIVED Property 9. ADL O 28240 Designation(Lease Number): 10. Field/Pools: BAY,SCHRADER BLUF OIL • J E P 2015 11. PRESENT WELL CONDITION SUMMARY °l S �� Z3//S• Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Jtin Peea3UY 5270 • 4892 4434 4099 4434 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 2973 9-5/8"40#L-80 32-3005 32-2755 5750 3090 Intermediate 5231 7"26#L-80 29-5260 29-4883 7240 5410 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 27-4169 Packers and SSSV Type: 3-1/2"Baker Premier Ret.Pkr Packers and SSSV MD(ft)and TVD(ft): 4110, 3791.10 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal H 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service m 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: , Oil 0 Gas ❑ WDSPL 0 Suspended H • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and o ct to the best of my knowledge. Contact Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature Phone +1 907 564 5430 Date Di, ifiZo)r COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315- 19 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 pr va / y.5 11-u - l-td co v2 /--(,--2 c-h.j- v, clev-to�wln,fv f a. Pg7f / /qF°r Ot (JSf) dee Wel/s t4vrf� nv f�h.,te vt1l1 w1�rh hv,1-715 ,--5-6. wtt/j C11,25 cv- 7,---oaba �Gruvi `hent. pri r 71-0 oO�G/ dc" c'vh-, s,-,i'S51`art,"r-z /rein p la 's i-a be- a1--vei0p-Cc1 GL r---:CA app i—U v"-ed ,1.---x,vA 1.1 r<-v7e G'vv1-, w,i ss/ 157 1Z/3r/1 - Spacing Exception Required? Yes 0 No I I Subsequent Form Required:irt +yt' p �d < c:5, Fal /vrc 71-1, Cuvvrpi7 wlth 1431:1rel_�r'r-e'err tn w� 11 r vet �l�t� � ►zr �,,nd�.�. atetti n / APPROVED BYTHE .--•Approved by: /0 . .. _ (L.� COMMISSIONER COMMISSION Date: ��'2 ' TL 10/24, // !r��777��_ ORIGINAL RBDMS—NOV 0 2 2015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /C?�L-./1 r • • a) N N m N- co 00 co CO CO N L CO V O V CO LO CO p_ N- N CO CO V CSO t.[) a M V '- CO r 0) N ❑ LC) (.0 V V V V CO ❑ N N V V `Cr "Cr V I- 0 O 1— V N co Co co CO LC) s CO N CO 10 V O V O. N- 00 C10 O M O) N 0 a) I0 co O) co CO co O) W ❑ Lf) co co V V V I > fo N N V V 'Cl- V V 0 r— W 0_ a W Z L1.1 00 O W p a a) Q Q Y U 0 O CO O O Q Y 1 t 0 LC) LO CO O L0 O) J J J Q Q (n W {J p, CO CO CO Ln CO Q Q Q W a a O Z U = a) I,- CO ti CO CO CO O 0 0 U J W W 0 N N V V V V V J_a) to _ ZOJp 0_ LLI y 00 ii I Z < < O H O 0 0 O W EtZ O Z W W W a I- I < J < C) C 2 2 2 O cn <n cn cn cn Al 4-+ N < a > 0 C Z L 100010 co L0 d- o_ OoN- ti Lr r n d- Ln N NeoNcwcwwrn }) LI ❑ N CV 'Cr V V Ni- V LN 0 a) CO 2 � (n4.1 -I _ H O- 0_ J a L 2 O cn cn cn cn cn CD CL a) 730 0 0 C 2 CC fY CO CO CO Cl) CO lG w w a_ a. a. a. a. O 0_ CLmmmmm a 0 t a) a a) H D al 1"-- r� � F a 0 O 0 0 0 0 0 0 0 W J Z 0 0 0 0 0 LI- N N N N N N O W N Li_ CCCC � pw JUpWL. NNa :DW Waw O --- CO M CO CO M CO O I ❑ W -1 -1 .7t- O W W COM M < < T) a cn LL L_ W co a a a) E at z 0 0 0 0 0 0 0 N N N N N N NW N a' a W a » < m0- Uitco cn aa> < TREE= ' 3-1/2"CM/ • SA NOTES:***WELL HAS SHALLOW WELLHEAD= FMC2 0 1 SURFACE CASING LEAK*** ACTUATOR= NA KB.ELEV= 83.5' BF.ELEV= 60.3' —I 975' -9-5/8"TAM PORT COLLAR KOP= 900' Max Angle= 36 @ 2380' Datum MD= 4838' 2201' —3-1/2"CAMCO B-61 SSSVN. ID=2.812" Datum TVD= 4400'SS 0 (I I 2775' -2780' -2-1/2",6 spf,PERF THRU TBG&CSG -A2870' -2875' H 2",6 spf,PERF THRU TBG&CSG 9-5/8"CSG,40#L-80 BTC, ID=8.835" H 3001' GAS LIFT MANDRELS LI ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3814 3426 19 MMG DMY RK 0 09/23/03 Minimum ID = 2.812" @ 2201' 2 3904 3511 19 MMG DMY RK 0 01/01/02 3-1/2" CAMCO SSSVN 1 3997 3597 19 MMG DMY RK 0 04/27/02 I I I 4052' I-- 3-1/2"BKR CMD SLD SLV WI BX PROF,ID=2.812" "/\/ 4062'ELM H JET CUT(03/07/07) • Z 4077' —17"X 3-1/2"BKR PREMIER PKR,ID=2.869" 4102' -3-1/2"HES X NIP, ID=2.813" I I 4123' -3-1/2"HES X NIP, ID=2.813" 3-1/2"TBG,9.3#,L-80, .0087 bpf,ID=2.992" — 4135' / 4141' —3-1/2"WLEG,ID=2.992" 4434'SLM -TOP OF CEMENT(03/06/07) PERFORATION SUMMARY REF LOG: 1111111111 4500' —TOP OF CEMENT(03/04/07) I ANGLE AT TOP PERF: 32 @ 2775' 11111111111111111111 Note: Refer to Production DB for historical perf data 1111111111/1/1111111 - 4690' —7"MARKER JT(20')W/RA TAG SIZE SPF INTERVAL Opn/Sqz DATE 11111111111111111111 2-1/2" 6 2775-2780 0 03/25/07 11111111111111111111 2" 6 2870-2875 0 03/25/07 11111111111111111111! 2-1/2" 4 4750-4765 S 03/03/07 1111111111111111111 111111111111/111111 2-1/2" 4 4810-4830 S 03/03/07 1111111111 2-1/2" 4 4845-4855 S 03/03/07 111111111111111111111 00.000 2-1/2" 4 4954-4989 S 03/03/07 111111111111/1111/11 - 4871' —7"MARKER JT(20')W/RA TAG 11111111111111111/11• 1111111111111111111. 111111/1/11011/1 �a��at�� 4977' —TOP OF FILL(03/4/07) PBTD — 5157' 1111111111 11111111111111111111 111111111111111111111 7"CSG,26#,L-80,ID=6.276" - 5257' I !'.1.1.1.1.1.1.1.1.1.1. DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 01/01/02 CH/KAK ORIGINAL COMPLETION 11/30/07 TW/JPJC SHALLOW CSG LEAK SFTY NOTE WELL: V-201 04/01/05 ???/TLH JET PUMP/PKRS PULLED 11/04 12/15/07 TW/PJC PERF CORRECTIONS PERMIT No: 2012220 12/04/06 RAC/TLH TREE CORRECTION API No: 50-029-23054-00 03/04/07 SRB/TLH P&A SEC 11,T11N, R11E,4838'NSL&1775'WEL 03/08/07 GJB/PAG JET CUT @ 4062'ELM(03/07/07) 03/25/07 JMF/PJC PERFORATIONS BP Exploration (Alaska) • • BP Exploration(Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells 4, Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 ' August 28, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Orion Unit Well V-201 (PTD # 2012220) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Orion unit well V-201 on 07/27/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition Orion unit well V-201 was suspended on 01/25/2008. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is secured with cement across and above the perforated interval. The top of cement is —300' above the top set of perforations and was pressure tested after the cement was placed. Based on these conditions and the inspection on 07/27/2014 Orion unit well V-201 meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Orion unit well V-201 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. Sincerely, • • Douglas A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • • Orion Unit Well V-201 (PTD 2012220) Technical Justification for Renewal of Suspended Status August 28, 2015 Well History and Status Orion Unit well V-201 (PTD 2012220) was suspended effective 01/25/2008 after a surface casing leak was discovered while prepping for a sidetrack. The well is secured with cement across and above the perforated interval. The top of cement is -300' above the top set of perforations and was pressure tested after the cement was placed. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Orion Unit well V-201 is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= 0/0/0 psi recorded on 07/27/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for V-201. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name PBU V-201 heldtPool Prudhoe Bay Field Orion Schrader Bluff Permit ft(PTD) 2012220 API Number 50-029-23954-00-00 Operator BP EXPLORATION(ALASKA)INC Date Suspended 1+25/2008 Surface Location: Section: 11 Twsp 11N Range 11E Nearest active pad or road' L pad Take to 1.,,Qtation Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges,fittings,tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of tne surface location,including discoloration fluids or sheens visible on the ground or in any nearby water, 2)photograpns showing the ooneition of the location surrounding the well General location condition: Clean active well pad Pad or location surface: level gravel pad Location Cleanup needed: None Pits condition: Clean,dry Surrounding area condition clean Water/fluids on pad some rain water Dtscoloraton,Sheens on pad, pits or water: None Samples taken. None Access road condition: Good Photographs taken if/and description) Yes,well house,surrounding area condition of Wellhead AOGCC require-5 1)a description of the condition of the wellhead,2)well pressure readings where practicable, 3j photographs showing the wellhead condition Wellhead/tree/valve description, condition: Intact,clean,and in good condition No'towline,blinds installed with gauges,fluted hanger not landed in conductor Cellar description,condition,fluids clean water Rat Hole N/A Wehihouse or protective banners Yes,good condition Well identihcat on sign Yes Tubing Pressure(or casing if no tubing) N/A SSV closed Annulus pressures IMO psi OM 0 psi Wellhead Photos taken(#and description). Yes,wellhead and tree Work Required None Operator Rep(name and signature): Laurie Clime AOGCC Inspector Bob Noble odWr ObserversRyan Hayes Inspection Date 7,1712014 AOGCC Notice Date 7/25/2014 Time of arrival 1 00 PM Time of Departure. 115 PM Site access method. Truck 0 • TREE= 3-1,2CIW SAFETY NOTES:'''W al HAS SHALLOW WELLHEAD= F MCSURFACE CASING LEAK** * AC1 LA I OH= NA V 20'1 KB ELEV= —I 975' H9-113*TAM PORT COLLAR .... KOP= 900' Max Anglo= 36 10 238.0' Datum MD= 4838 1 It-TI --1 2201' H - 2 CAMCO B-6I SSSVN,0=zaiz Ctituln TVD= 4400 SS I I 14775'-2780'H2-1,7,6 spI,PERF THPU TG&CSG I 1 2075*H2-,6 sof,PERF TFRU 113G&CSG 19-543'CSG,401 1-80 MC,ID=B835' H 3001' 1-41 I i GAS LF T MANDRELS ST MD TV D DEV TY FE VIV LATCH PORT CA TE 3 3814 3426 19 MM3 DMY f0( 0 '09,2343 Minimum ID=2.812" ,To 2201' 2 3904 3511 19 MM3 MAY Ric 0 01/01112 3-1/2"CAMCO SSSVN 1 3997 3597 19 MMG AMY RC 0 042702 II I I 4O F.3-07 BKR Ch13 SID SLV W BX KC+,ID=Z817 4062-ELM HJET CUT 010707) I X <-.-----1 4077' hr X 3-07 BIG1 F &4ER RS.R ID=2.869 I I 1 -----I 4102- H3-17 HES X II',ID=2813' I I I I. 4123- H.3-1,7 PIES X NIP,ID=2813' I 13-02"TBG,B.341.L-80 0087 I.D=2997 H 4138. / \ I 4141' H3-1.2"WLEG,ID=2.F ' I 74 4434•91J0 H TOP CI COVENT 1010607i I FERE ORA 11ON SLIMP4I.R1 REF LOG fivAvefeee47 4500* TORO+CF_MENT 1010407 I ANGLE 41 TOP PER- 32 14 Z77 5 4.1•041/4.1 ••••011•10 46goy HT.,...,RKER J11201 IN RA TAG Wale Relorr Iv Producoon CC Icy Ocsion,ro poll •1314 ......11.11 ••••001.10 **•$.44.41 SIZE SPF INTERVAL Ovi.S.yz DA TE 410441.10 *......1.0 2-1,7 6 2775-2780 0 1312507 ..1.1411•1. 2' 6 2879-2875 0 012540 7 .....*••444 *01.1101.1 2-117 4 4750-4765 S mac 7 44411.11414 .64.1104.1 2-177 4 4810-4830 S 010107 .1.00.141.1 ....0..... .01110111.1 2-12' 4 4845-4855 S Cr3.0142 7 ••••••••10 .1•14•1•0. 2-07 4 4954-4989 S nacr3,41 7 ..4•1**1•I ....•••••tt 4871' H7.MARKER IT 120'i Yi RA TAG I 4.00141..0 .0.0..1..1 4.14$4..... ....11011114 *0014.1400 0,1,01,41,1VA% I 497T I--ITOP Of FILL 1,0 3,4'0 7 I I PH ID 5157' I 1141....... 1.1+11.4.1 4..104..4 4411.11.4.0 .1.11411•01. 1.1.010,.....At I 7'csa 2150 L-80 ID=5 2 75' H 925-T DATE REV BY CUNNIENIS DATE REV BY COPAAENTS 1 ORION UNIT 0 1AI1/02 CHNAK ORIGINAL COIN PLETPON 1113517 INV...P.IC SHALLOW CSG LEAK SFTY NOTE WELL V-201 1411)1115 ,,,cTLF1 JET PLIMPPKRS FILLED 11,14 12:1507 RN'RIC PERF CORRECTIONS FERMI No 2012220 12.04116 RA 0 TLFI TREE CORRECTION API No: 50-029-23054-00 310407 SREVTLF1 P&A SEC 11,Ti 1N,R1 IL 4838 Na&1775 W'EL 0301107 L,..PBPAG JET CUT g 4062'EL M I a3e3 TC 7 I 012107 .A.1F,PJC PERFORATIONS BP Eqp/oration(Alas kaj 1 • • Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp, Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells, of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally,as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options (wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loecioa_alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [ ] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L(ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities) and still in the very early scoping stage. They are not funded or approved yet,and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim, and the Suspended well renewal applications submitted by Oliver are also separate (discrete and unrelated)activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [ lto:victoria.loepp@alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells; fit in the program? Thanx, Victoria 1 s • From: Sternicki, Oliver R [mailto:Oliver.Sternicki@ bp.com] Sent:Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki WO obt,i0 wells arsamea meow Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki a(�bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory,development,or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • State of Alaska • • Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeoi ialaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.Sternicki@bp.com] Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory,development,or service well; no wells meet the (B)criteria. Regards, Oliver Sternicki w Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(a�bp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me,or come and discuss if we have an issue. Thanks Ryan 3 • S From: Loepp, Victoria T(DOA) [ .,nilto:victoria.loepp@alaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory,development,or service well; (B) is a viable candidate for redrilling;or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A) and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp{CDa laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.go, 4 Irn e Project Well History File Cov~ Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;;; Q 1 -:J..!l:J.... Well History File Identifier Organizing I'!nn"\ RESCAN o Two-Sided o Rescan Needed o Color items: DIGITAL DATA ~ Diskettes, No. I OVERSIZED (Scannable) o Maps: o Grayscale items: o Other. NofType o Other items scannable by large scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds NOTES: B'(: BEVERLY ROBIN VINCENT SHER'(L ~IND'( o Other DATE1j4 Olf Isl VIti' ~ Project Proofing ~ VVl~ = TDTAL PAGES Lf7 V11.0 I:H: BEVER LV ROBIN VINCENT SHERYL~WIND'( DATE:~ Off/s' Scanning Preparation J x 30 = 'I~() + J Ç1 BY. BEVERLY ROBIN VINCENT SHER'(~WIND ( DA TE 4 ¿J¿,j D'F' Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: .- :)0 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: 1./"" YES NO 'I BY: BEVERLY ROBIN VINCENT SHER'(L MARIA WIND( DATE 7/J1/[Jf 151 Ii Stage 2 IF NO IN STAGE 1 PAGE(S) DISCREPANCIES WERE FOUND: YES NO B'(: BEVERL,' ROBlr~ VINCENT SHER (L MARIA WIND'( DATE. 151 (SC MIPlIII(1IS COMPLETE AT THIS POIPlT UI ¡LESS SPECIAL A "EIITION IS REQUIRED or I All If IDIVlDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) ReScanned /III/Ii' "II'." fa HI . ".{"·'/.1/ ,>11"""1"'1;' ',I 1.)"":" ",'Wp{l'i'·(I,I RESCANNED S'(: BEVERLY ROBIN VINCENT SHER (L MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (,1"111' I 12/1 O/02Rev JNOTScanned wpd • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU V -201 - Oper. Rep: Jack Winslow PTD No.: 2012220 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 01/25/08 Date AOGCC Notified: Sundry No.: 307 -057 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing SSV closed Photos Taken? Yes IA 0 by Operator `*/ OA 0 Condition of Wellhead: Well house in place, full tree with closed SSV, flow line removed and blinded. Surface casing hanger not landed in conductor. Condition of OK Surrounding Surface Location: Follow Up Actions none Needed: Attachments: None REVIEWED BY: Insp. Supry „lie— 0 17'It Comm PLB 08/2010 2010- 0911_Suspend_PBU_V- 201_cs.xls ~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~y ~~ 1 i ~`( '~ ~~~~i ~ ~`~a~}" ~~k~~+~ . , v l .3 ~~ J ~r~ August 14, 2009 ~~ bp ~~~ ~ ~~~ ~ ocT a ~ zao9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~s Oil & Gas Cons. ~amm~~~i~n Artchor~pe ~, Q `_ ~~",2,. ej~~~l Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ i BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 v-t00 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-t01 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 v-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA t3.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-1t9 2040410 50029232010000 NA 2 NA t8.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-20i 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA t3.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA t8.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-2i5 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-2t6 2041300 50029232160000 NA 1.5 NA t3.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 L~-2~8 2080200 50029233830000 NA 1.75 NA ~5 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Hubble, Terrie t_ [Teme.Hubble@bp.com] Sent: Monday, February 04, 2008 2:20 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B; Peltier, Brandon Subject: V-201 (201-222) Hi Tom, have discussed this with both Rob and Brandon. This was a unique situation and unfortunately is likely to happen from time to time. However, we will do our best to keep our reporting more timely. Where the breakdown occurred is when the pre-rig work was conducted and unforeseen problems were discovered (surface casing leak), the decision was made to remove this well from the current drilling plans. Therefore the Drilling Engineer felt that no further attention (by him) was required. I continued to watch the well work going on for this well so that I could capture the date when the final step was completed as was approved in the Application for Sundry Approval (#307-057). In fact, there was to have been significant work done by the rig prior to milling the new sidetrack window, which also fell on the Application for Sundry Approval. I did not realize that the well had been removed from the drilling schedule, due to the problems encountered, I just thought it had been pushed further out on the schedule. The Drilling Engineers will be reminded that better communication needs to occur between them and myself to prevent this lapse in reporting from occurring in the future. Please accept our apologies. ,~~~ MAY ~ ~ 2008 Sincerely, Terrie Hubble From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 29, 2008 9:54 AM To: Peltier, Brandon; Tirpack, Robert B Cc: Hubble, Terrie L; Jim Regg subject: V-201 (201-222) Brandon and Robert, I am reviewing the 407 recently submitted for suspending the well. The last message in our well file is dated March 19 when Brandon transmitted information on the work accomplished and the passible path forward. I do not have any other correspondence regarding this well. Based on the summary with the 407, rigless intervention to place kill fluid in the OA was accomplished. Based on the date the work was accomplished, this 407 should have been submitted at about the end of April. A 403 should have also been submitted signifying the intent to suspend the well. I would appreciate your providing any additional comments you might have on the well operations, the absent 403 and tardy 407. Gall or message with any questions. Tom Maunder, PE AOGCC 2/5/2008 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COM SION ~"' WELL COMPLETION OR RECOMPLETION REPORT AND LOG~~~ ~ ~ ~ppg 1a. Weli Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended zoAACZS.~os 2oAaczs.>>o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero I ^ DevaCf>d~9^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp. Aband. 007 ~~ -f~ 12. Permit to Drill Number 201-222 307-057 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/25/2001 S 13. API Number 50-029-23054-00-00 4a. Location of Well (Governmental Section): Surface: 4838' FSL 1775' FEL SEC 11 T11 N R11 7. Date T.D. Reached 12!2812001 14. Well Name and Number: PBU V-201 , , . , , E, UM Top of Productive Horizon: 692' FSL, 2239' FEL, SEG. 02, T11 N, R11 E, UM 8. KB (ft above MSL): 82.1' - Ground (ft MSL): 53.6' 15. Field 1 Pool(s): Prudhoe Bay Field /Polaris Pool Total Depth: 798' FSL, 2104' FEL, SEC. 02, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 5157 4785 4b. Location of Welf (State Base Plane Coordinates, NAD 27): Surface: x- 590526 y- 5970085 Zone- ASP4 10. Total Depth (MD+TVD) 5270 ~ 4892 - 16. Property Designation: ADL 028240 _ __ TPI: x- 590047 y_ 5971213 Zone- ASP4 Total Depth: x- 590181 y- 5971321 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, LWD, MWD, CMR, FMI, DIPOLE SONIC 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTNG DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED ' 34" x 20" 91.5# H-40 Surface 107' Surface 1 7' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 28' 3001' 28' 2751' 12-1/4" 596 sx AS III Lite 244 sx Class'G' 7" 26# L-80 26' 5257' 26' 4880' 8-3/4" 283 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. ` TUBING RI=_coRD If Yes, IISt each Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 3-112", 9.3#, L-80 4136' 4077' MD TVD MD TVD (Cut at 4062') 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (~~`' ~~~ ~ ~ 208 ~`~~`~ DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 4434' P&A Perfs w/ 30 Bbls Class 'G' Cement (03/03/07) 2870' - 2875' & Pert in order to obtain communication between IA 2775' - 2780' and OA (to circ kill weight fluid in OA) (03/25/07) 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfeSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-SBL: OIL GRAVITY-APi (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ®Yes ^ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resu{ts per 20 AAC 250.071. ~,~cL ~7/~ LLB Sr 4 ~ ' .:.. Core data reported with previous 10-407, Dated 04/24/2002. f1~~ 6 ~~~~~ ~-; L" ..... r, ~ ~.... , l.,a .F- Form 10-407 Revised 02/200T ~~ ~~~ ~ UED ON REVERSE SIDE ~~~~~~ /~~~/ /~/ i/~ w "[ !`/ fv' 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. NA 4548' 4207' None N B 4573' 4231' NC 4618' 4273' OA 4725' 4375' O Ba 4797' 4443' OBb 4838' 4482' OBc 4897' 4538' O Bd 4950' 4589' OBe 5017' 4652' OBf 5060' 4963' Base OBf 5114' 4744' Formation at Total Depth (Name): Base OBf 5114' 4744' 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~ /~ Signed Terrie Hubble Title Drilling Technologist Date ~~ PBU V-201 201-222 307-057 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Drilling Engineer: Brandon Peltier, 564-5912 Permit No. / A royal No. INSTRUCTIONS GeNerLat: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. lreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). lreM 20: Report true vertica4 thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only by Terrie Hubble Technical Assistant Drilling & Wells January 23, 2008 ~~~ :~~ ~iS :~~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-23054-00-00 Direct: (907) 564-4628 Terrie.hubble~bp.com Permit # 201-222, PBU V-201 To Whom It May Concern: PBU V-201 was scheduled to be sidetracked in 2007. Applications for Sundry Approval (#307-057) and a new Permit to Drill for V-201A (#207-024) were submitted and approved. As part of the pre-rig operations, the perforations were cement squeezed (TOC at about 4434' md). Integrity testing was also done on the tubing, cement plug, IA and the OA. The tubing and IA pressure tested successfully, but when 2000 psi was applied to the OA, the pressure bled down, and fluids were venting out of the surface casing conductor ports, suggesting a leak in the 9-5/8" OA x surface casing. The leak is believed to be shallow, not more than a few feet below the cellar floor. Diagnostics has shown the leak is most likely at or just below the collar on the 4' pup joint. A thread leak or corrosion leak is suspect because the TOC is 5.5' below the flutes, which would have allowed water to corrode this portion of the casing. As part of the safeout procedures due to this surface casing leak, perfs were shot through the tubing and 7" casing at the base of the surface casing in order to circulate kill weight fluid into the outer annulus. Therefore, since the well is adequately secured, we believe the status of V-201 should be Suspended. In the future, a plan may be developed to repair this surface casing leak and then sidetrack this well to a new bottom hole location. Sincerely, '~~~J ~- ~ Terrie Hubble xc: Well Fifes PDC Taylor West, Petroleum Engineer Digital Well File ~ ~ Page 1 of 4 Well: V-201 Well History Well Date Summary V-201 2/17/2007 T/IA/OA=1000/700/100 Pre rig well head W/O MIT Bled trapped pressure on THA from 700 psi to 0 psi. All LDS were able to function.No signs of bent or broken pins. Pressured void to 5000 psi for 30 minutes ( PASSED) Bled THA void off to 0 psi re installed Alemite cap IC void. Installed bleeder tool to test void was @ 150 psi bled to 0 psi .packed void until we got fresh returns. pressured up IC to 3000 psi for 30 minutes (PASSED) all LDS were able to move freely no signs of bent or broken pins. Bled IC test void off to 0 psi removed bleeder tool re installed Alemite cap. V-201 2119!2007 "*WELL S/l ON ARRIVAL*"" (pre sdtrk / p&a) DRIFT TUBING 2.5" CENT, TEL, SAMPLE BAILER. TAG TT @ 4,114 SLM (4,141' MD) = 27' CORR. TAG TD @ 4,977' MD. 12' FILL. BOTTOM PERF @ 4989' MD. (SAMPLE BAILER HAD .25 CUP FRAC SAND) MADE SBHP GAUGE STOPS @ 60 MIN. STOP @ 4,838' MD (4808 SLM) MADE 15 MIN STOP C~ 4,732' MD (4705' SLM) MADE 15 MIN. STOP @ 4,627' MD (4600' SLM) .GOOD DATA. TURN WELL OVER TO PAD-OP ***WELL LEFT S/I*" V-201 3/2/2007 CTU # 8, P&A, Travel to location, Rig up -- Continue on 03/03/2007 V-201 3/2/2007 CTU # 8, P&A, Travel to location, Rig up, MU BHA 31 1.90" OD CTC, 2" OD stinger, 2" OD XO, 2.31" BDNS L= 8.916' '***Continue on 03/03!2007 `** V-201 3/3/2007 CTU # 8, Plug &Abanndon - ****Continued from 03/02107*'**. TIH with BHA # 1 fluid packing well while TIH. Tag up at 4944'. Did not establish circulation. Wait on Cementers V-201 3/3/2007 CTU # 8, P&A; Continued from 03/02/07 ... RIH with BHA # 1 fluid packing well while RIH. Tag up at 4944'. Could not establish circulation. POOH. Wait on Cementers. RBIH with 2.3" BDN BHA. Tapped TD and corrected depth to 4977' and based on slickline corrected tag. PUH 10' and flag pipe. Pum 5 bbls n to neat cement s cement with 12#/bbl a re ate 10 bbls neat cement. La ed cement i 4190' and with no returns. PO H. O . Go to weather standby at midnight ... V-201 3/3/2007 CTU # 8, Plug &Abanndon -Continued from 03102!07.. V-201 3/4/2007 CTU # 8 Plug & Abandon perfs. V-201 3/4/2007 CTU # 8 Plug & Abandon perfs. *** Continued from 03/03/07*** V-201 3/4/2007 CTU # 8, P&A; Ended weather standby at noon. Cont' job from WSR 3/03/07 ... PT lubricator to 250(4000 psig. RIH with 2.3" BDN assy. Tagged TOC at 4500' md. Confirmed hard tag. POOH. FP well to 2500' `` with 60/40 methanol. Pressure test cement plug to 1500 psig. RD CTU #8. * * Job Complete *** V-201 3/5/2007 T/I/0= 160/680/100. Well was S/I upon arrival. MIT-T to 2000 psi. (PRE SDTRCK /POST CEMENT PLUG) ***PASSED*** on 1st attempt. Lost 100 psi / 1st 15 min & 40 psi 12nd 15 min. Pumped 1 bbl of 24* diesel o ac ii~'eve test pressure. ***WSR continued on 3/06/07*** V-201 316!2007 T/1/0= 1 011 70/0. Temp= SI. (eval SC leak) Cellar is 35" deep to the top of the grating floor. Hasa 20" conductor & exposed 33" above gravel floor. Cellar has a 8 x 8' CMP. Two 4"circulation ports exposed 1' above gravel floor. Has open flutes 5' 6" deep, to a muddy diesel bottom. Cellar gravel is saturated with diesel. Final WHP's 10/170/0. V-201 316!2007 '**WSR continued from 3/05/07*'* MIT-IA to 3500 si (PRE SDTRCK) **PASSED** 1st attempt. Lost 40 psi / 1st 15 min & 20 psi / 2nd 15 min. Pumpe 6~s o~'fd'~aiese o ac ieve es pressure. MIT-OA to 2000 si. **FAILED** Pumped 2 bbls of 24* diesel to achieve test pressure. Fluid came up the conductor pipe an t e pressure dropped. Bled OA to 0 psi and called supervisor. See the Log for a detailed report of OA leak. Final WHP = 0/0/0. V-201 3/6/2007 ***WELL S/I ON ARRIVAL***(pre rwo) DRIFT W/2.70 CENT, SAMPLE BAILER TO TOP OF CEMENT @ 4434' SLM. SAMPLE BAILER EMTPY. ***WELL LEFT SHUT IN*`* V-201 3/7/2007 CUT 3.5" TUBING WITH A 2.5" SCP JET CUTTER IN THE MIDDLE OF THE SECOND 10' PUP JNT A A ED A7 4077'. TUBING CUT AT 4062'. DID NOT TAG TD. WELL LEFT SHUT IN. `**Job complete*'* V-201 3/8/2007 T/I/0=150/120/0 Circ out TxIA, Load OA w/ Brine (Rig prep) -Pump 10 bbls meth, 298 bbls 1 % KCI water down tubing taking returns up IA to Well 102's flowline, Line up to pump down IA, Pump 88 bbls 70* diesel down IA taking returns up tubing to Well 102's flowline, OA ressure came u abru tl durin IA of ga s & fluidto bleed tank. su ace Ines o e w 2 pump job and vent d co nsiderable amounts ~ ~ ~ r e hhlc meth I I_t~ rho vl to n~ rt in n aro '~v ~ imn '3 hhlc moth R 'I 1 hh{e Q Rnnn hrino http:/Idigitalwellfile.bpweb.bp.com{WIInfolReports/ReportViewer.aspx 1/23/2008 Digital Well File Page 2 of 4 v....,uw.~. ,......v , ..~ ,.... ,..uy ..v v.y, «,,, .,.u...,. . .. . ....... .....YN`J ..,.~~.. down OA a~ began bubbling in conductor pipe, Cap w17 bbl sel for surface freeze protect, Bleed WHPs, DHD remaining on location to monitor WH Final WHP's=010/4 V-201 3/8/2007 TII/0= 430/600/0. Temp= SI. Install Katch Kan (Pre Rig) Installed Katch Kan. OA FL C~3 900' ??(23 bbls). Assist LRS Circ-out with open bleed on OA to open top tank. LRS finished with circ-out. Bled OAP to open top tank from 20 psi to 2 psi in 2 mins (all gas), SI OA bleed monitored for 1 hr. OAP increased to 22 psi. Continued open OA bleed. Change out with night relief. Final WHPs= 0/0/2. V-201 3/8/2007 T/I/0=0/0(2. SI. Monitor OAP (Bleed to 0 psi). OA FL 600' (15 bbls). LRS pumped 3 bbls meth and 11 bbls brine down OA. At 80 psi, conductor s a e u ing gas an wd, steady but minor. Shut down pump. Monitored 10 minutes with conductor bubbling gas and fluid. Fluid did not rise. Bled OAP to 0 psi and Bubbling stopped. Started pumping diesel down OA. At 7 bbls (500 psi) Bubbling started again. Steady but minor. Pump went from 60 psi to 500 psi in few 10ths of a bbl. Shut down pump. Bled OAP to 0 psi. 1/2 bbl back to tank. Conductor stopped bubbling. OAP increased to 2 psi in 5 minutes. Bled back to 0 psi C~ 0100. Monitored every 30 minutes. At 0600 OA FL C~3 30', OAP C~3 4 psi. Bled to 0 psi in 10 seconds. All gas. OAP increasd to 2 psi in 10 minutes. Final WHP's=0/0/2 V-201 3/9/2007 Load & road for circ out V-201 3!9/2007 Post circ out road to EOA & offload diesel V-201 3/9/2007 T/U0=0/0/0. SI. Monitor OAP. OA FL near surface. OA pressure @ 0 psi. Monitored 12 hours with no change in pressure or FL. Final WHP's=0/0/0 V-201 3/912007 T/I/O= 0!012. Temp= SI. Monitor OAP (pre Rig). Relieved night shift. No bubbling currently in conductor. Bleed OAP from 4 psi to 0 psi in 5 mins. SI monitored for 1 hr. OAP increased 4 psi. Well Support arrived on location to rig-down well house and flow line. Final WHPs= 0/014 V-201 3/10/2007 Heat 70 bbls 9.8 ppg Brine on LRS Transport # T-94 to be used C~3 V-201 to 100*f V-201 3/10/2007 T/I/0= 0/0/0. Temp= SI. Monitor OAP, OA FL near surface. Wellhouse and F/L removed. Hardline rigged up for LRS. Monitored OA for several hours. No change in pressure or FL. Final WHPs= 0/0/0. V-201 3!1012007 Circ out TxIA / OA Brine Load (Rig prep) -Standby for weather, ambient temp. -43 V-201 3/10!2007 T71lO = 0!0/0. Temp = SI. Monitor OAP (pre RIG). Relieve night shift. No change in OAP overnight. Well support arrived to rig up circ-out and remove flow line. Monitored for 12 hrs. No change in OAP. Final WHPs = 0!010. V-201 3/11/2007 T/I/O = 0/0/0. Temp = SI. Monitor OAP (pre RIG). **CURRENTLY ON WEATHER STANDBY**. No change in pressure overnight. Change out with night shift. Little Red currently rigged up to well. Monitored OAP for 12 hrs. No change in OAP. Final WHPs = 0/0/0. V-201 3/11/2007 Circ Out TxIA / OA Brine Load (Rig prep) -Standby for weather, ambient temp -43 V-201 3111!2007 Circ Out TxIA / OA Brine Load (Rig prep) -Standby for weather -45*, Pre-heat internal diesel tanks to 90*, Roll UR tank to 160* V-201 3/12/2007 Heat brine (Rig prep) Heated 9.8 brine from 35* to 100* V-201 3/12/2007 T/I/0= 0/0/0. Temp= SI. Monitor OAP (pre Rig). Relieved night shift. LRS on location to circ-out the well. LRS began circing out the well pumping fluid down the IA, and taking returns up the TBG of V-201 to prodution (V-102) with an open bleed on the OA of V-201. Started taking returns to the open top tank (trickel). No fluid or bubbling in flutes. Circ-out complete. Started pumping down OA vaccing returns out of catch can (1.5 bpm). Night crew showed up. V-201 3/12/2007 T/U0= 0/O/0. Temp= SI. Monitor OAP. OA FL near surface. Monitored OA for several hours. No change in FL or pressures. V-201 3/12/2007 TII/0= 5001500!0. Temp= SI. Monitor OAP. LRS pumped 75 bbls of brine down OA takin 75 bbls returns out conductor into katch kan. Pumped 3 bbls of3ieserc3own to reeze protec . e to ing to 0 psi. Monitore OA ar several hours. 11:00 p.m. OAP ~ 0 psi and OA FL near surface. FL in conductor is above the union at 5'. No change in QA pressure or FL. Fluid in conductor did not change. Final WHPs= 0/0/0. V-201 3/12/2007 T/I/0=0/0/0 Circ Out TxIA / OA Brine Load (Rig Prep) -Pump 5 bbls meth & 130 bbls 2% KCI down lA taking returns up tubing (All returns taken to flowline of V-102), IA pressured up to 2400 psi C~ 1.4 bpm, Line up to pump down tubing, Pumped 12 bbls 2% KCI down tubing, TP increased 2000 psi C~3 1.9 bpm, Line up to pump down IA, Pump 129 bbls 2%KCI & 88 bbls diesel down IA taking returns up tubing, FP all surface lines, U-tube TxIA to put FP in place Load OA w/ Brine -Pump 75 bbls 9.8ppg brine down OA taking returns from conductor pipe to catch-can, Veco maintaining fluid level in catch-can by sucking out w/dirty vac, Getting 1 for 1 returns out conductor, Load brine to LRS tanks & restart pumping brine down OA, OAP broke over w/ 4 bbls away 2.2 bpm ~ 2875 psi, Incease rate to 3 bpm C~? 2425 psi, Vac truckunable to keep up w/ returns, l3 bbls away 2425 psi fluid ran over catch can into cellar, Begin to pump diesel down OA to FP, Diesel returns out conductor pipe C -2 bbls away, Pump additional 1 bbl (3 total) down OA, Bleed TxIAP Final WHP's=0/0/0 V-201 3/13/2007 TIRO = 0/010. Temp = SI. Monitor OAP (pre RIG). No change in OAP overnight. Monitored OAP for several hrs with no change. http:/ldigitalwellfile.bpweb.bp.comlWIInfo/ReportslReportViewer.aspx 1/23/2008 Digital Well File Page 3 of 4 V-201 3/14/2007 T/I/0= 0/0/O~p= SI. Monitor OAP. OA FL near surface. Fluid i~ductor is not visible. Monitored OAP for several hours. No change in pressures. Final WHP's= 0/0/0. V-201 3/14{2007 T/1/O = O/0/0. Temp = SI. Monitor OAP (pre RIG). No change in OAP overnight. Monitored WHPs for several hrs with no change. V-201 3/15!2007 T/1/O = 0/010. Temp = SlI. No AL. Monitor OAP. No change in OAP during the day. Monitor to continue overnight. V-201 3/15/2007 TIO = 0/0/0. Temp = SI. Monitor OAP. OA FL near surtace. No visible fluid in conductor. Monitored OAP overnight with no change in OAP. V-201 3116/2007 T/110= VacNac/0. Temp= SI. Monitor OAP. OA FL near surface. Fluid in conductor is not visible at this time. TBG &IAP went on a vac overnight. OAP no change overnight. V-201 3/17/2007 T/I!O =vac/vac/0. Temp = SI. Monitor OAP (pre RIG). No change in pressures over a 24 period. Monitored OAP for 12 hrs with no change in pressure. V-201 3!18/2007 T/t/0= Vac/Vac/0. Temp= SI. Monitor OAP (pre RIG). No change in WHP's over a 24 hour period. Monitored OAP for 12 hours with no change in pressure. V-201 3/19!2007 T/110= VacNac/0. Temp= SI. No AL. Monitor OAP (pre rig). Relieved night shift. Monitored WHP's for 24 hrs. Monitored OAP for 12 hrs with no change in pressure. V-201 3/19/2007 Load and transport diesel, methanol, and 9.8 Brine for OA thaw. V-201 3/20/2007 Heat tanker of brine (continued on 3!21107) V-201 3/20/2007 T/I/0= VacNac/0. Monitor OAP (pre-RIG) No change in WHP's over a 24 hour period. Monitored OAP for 12 hours with no change in pressures. V-201 3/20/2007 T/I/O=VacNaclO Circ out TBG & IA/ Thaw OA (Pre Rig) Pumped 190 bbls of 2% KCL to circ-out tubing & IA down V-102. Pumped 100 bbls 2%KCL and 215 bbls seawater down tubing, up IA, and into re-circ tank. Started circulating and heating ~ 22:39 hrs. ***Continued on 3-21-07 WSR*** V-201 3/21/2007 Continuous Monitor. Assist LRS for OA Thaw. See LRS **WSR**. V-201 3/21/2007 Assist LRS for OA thaw. See LRS ** WSR** V-201 3/21/2007 *'*Continued from 3-20-07 WSR***Circulating 190* seawater down tubing, up IA, and into Re-Circ tank. (2020 total bbls circulated) ***Continue on 3-22-07 WSR*** V-201 3/21!2007 (continued from 3/20/07) Continue heating tanker of brine V-201 3/22!2007 ***Continued from 3-21-07 WSR*** Continue circulating 190* seawater down Tubing, up IA, and into Re- Circ tank. Pumped 1 bbl neat meoh down OA, Fluid coming out of conductor with no pressure. Continue Re-Circulating seawater ,Down IA and up tubing. 2000 total bbls circulated **'Continued on 3-23-07 WSR*'~ V-201 3122!2007 T/I/O= VacNac/0. Monitor OAP (pre-RIG) No change in WHP's over a 24 hour period. Monitored OAP for 12 hours with no change in pressures. V-201 3/22/2007 Continuous Monitor (pre-rig). Assist LRS for OA Thaw. OA FL ®120'. See LRS **WSR**. V-201 3/23/2007 ***Continued from 3-22-07 WSR*** Continued circulating 190* seawater down IA, up Tubing, and into re- circ tank V-201 3!2312007 T/I/0=400!40012. Temp= SI Monitor OAP (pre Rig). TBGP &IAP tracking pumping unit. OAP increased from 0 psi to 3 psi. LEL detection in conductor 0. Blocked in the TBG. Pressured up the IA to 2000 psi. Monitored the IAP & OAP for 15 min. IAP & OAP unchanged. V-201 3/23!2007 ARRIVE AT V PAD. WAIT ON LITTLE RED TO CIRCULATE WELL. **'**CONTINUED ON 24-MAR-2007 ***** V-201 3/23/2007 ***Continued from 3-22-07 WSR*** Continue circulating 190* seawater down IA, up Tubing, and into Re- Circ tank Pressure tested Tx IA 2000psi- no leaks to OA Continued circulating 190* seawater (1751 bbls total)***Continue on 3-24-07*** V-201 3123(2007 T/110= Vac/Vac/0. Monitor OAP (pre-RIG) No change in WHP's over a 24 hour period. Monitored OAP for 12 hours with no change in pressures. V-201 3/24/2007 T/I/0=0/0/0. Temp=Sl. Monitor OAP (pre Rig). TBG, IA, OA & hard)-line is freeze protected with neat meth. The OA is open to the choke and has a clear path to the tank. No fluid level change in the conductor. LEL in conductor 0%. V-201 3124/2007 ***CONTINUE AWGRS FROM 23-MAR-2007 *'* ARRIVE AT V PAD. WAIT FOR LITTLE RED TO MOVE OFF OF WELL. JOB CANCELLED DUE TO WEATHER. RETURNED TO SHOP. ***JOB POSTPONED UNTIL WEATHER BREAKS*'* ***CONTINUED ON 03-24-07*** V-201 3/24/2007 ***Continued from 3-23-07 WSR*** Pump 180 bbls 9.8 brine down Tubing, up IA, taking returns down V- http://digitalwellfile.bpweb.bp.comiWlInfolReportslReportViewer.aspx 1123/2008 Digital Well File Page 4 of 4 102, 10 bblel down Tubing, U-Tube to IA. Thaw & freeze pr~d Surface lines with neat methanol. *' ntinue on 3-25-07*'* V-201 3/24/2007 T!I/O = VacNac/0. Continuous monitor (pre-rig). Monitor OAP 12 hrs, no change in pressures. V-201 3/24/2007 ARRIVE ON V PAD, RU AND HELD PJSM. CHECKED OUT TOOLS ON SURFACE AND CONTINUED RU 2" GUN. *****CONTINUE ON 25-MAR-2007***** V-201 3!25!2007 **'**CONTINUE AWGRS FROM 24-MAR-2007`**" PERFORATED A 5' 2" 6 SPF 5' PJ OMEGA 2006 HSD GUN FROM 2870'-2875', PENE 21 ", EH 0.21, IN ORDER T A I N EN H IA AND OA. LOA COMMUNICATION AFTER GUN WAS FIRE . PERFORAT A ECOND TIME WITH 2.5" PJ 5' 2506, 2775'-2780', EH 0.34", 18.7" PENE. IA X OA COMMUNICATION ESTABLISHED. LRS TO CIRCULATE. "dS~ ,,.*JOB COMPLETE*~ °~ ~~, ~~3s/3~ ~at~i~S~ 6C; ~ ~ f ~~ 1 V-201 3/25/2007 e with T/I!O = 0/OfO. Temp = SI. AL =None. Continuous monitor (pre-rig). Assisted Schlumberger Elin Perforating from TBG -> IA -> OA. Assisted LRS with pump job/WH Monitoring. See LRS '*WSR**. V-201 3!25!2007 T/I/O =01010. Continuous monitor (pre-rig). Schlumberger E-Line rigged-up on well. E-Line to run in hole and perforate TBG, IA & OA. Gun fired, no change in WHPs. Schlumberger will run another pert gun. Monitor OAP 12 hrs, no change in pressures. V-201 3/25/2007 ***Continued from 3-24-07*** Pump 1 bbls neat methanol down IA. 6 bbls neat methanol down surface lines to freeze protect, E-line shot pert guns, Circulated into IA; 216 bbls 9.8 brine @ 120` through hole C~3 2775'-2780' into OA to return tank ,followed by 15 bbls diesel. U-Tube diesel IAxOA. Freeze protected surface lines. ***All valves on tree left SI."* FWP's=010(0 Note: DHD on location to monitor WHP's...Released all surface equipment ------------------------JOB COMPLETE------------------- V-201 3/26/2007 TIO = 0/0/0. Temp = SI. No AL. Continuous monitor (pre-rig). SWS EL perfed TxIA. LRS was able to load OA, pre-rig. Maintained a continuous monitor of the surface casing during LRS pumping (SC leaked into ketch-kan and was continuously vac'd out). Monitored OAP after LRS and vac truck departed location. V-201 3/26/2007 T/I/O = VACNACNAC. Temp = SI. AL =None. Continuous Monitor (pre-rig). Monitored WHP's 9 hrs, No change in pressures. Hardline crew showed up to RD pipe from well. Final WHP's = VAClVACNAC. **All WH Valves normalized before departure** V-201 3/2812007 T/UO=Vac/0/0. Temp=Sl. Flowline & A/L dropped. WHPs (pre rig). No change in pressures. Scaffold crew has installed 2 level scaffold. Print Date: 1/23!2008 Page 1 of 1 http:!/digitalwellfile.bpweb.bp.comf WIInfo/ReportslReportViewer. aspx 1/23/2008 TREE = 3-1 /2" CM/ WELLHEAD = FMC ACTUATOR = NA KB. E1EV = 83.5' BF. E1EV = 60.3' KOP = 900' Max Angle = 36 @ 2380' Datum MD = 4838' Datum TV D = 4400' SS 9-5/8" CSG, 40# L-80 BTC, ID = 8.835" 1-I 3001' Minimum ID = 2.812" @ 2201' 3-112" CAMCO SSSVN 4Q52' E_ 3-1/2" BKR CMD SLD SL~ W/ BX PROF, ID = 2.812" 162'ELM JET CUT (03(07!07) 4077' 7" X 3-1/2" BKR PREMIE=R PKR, ID = 2.869" 4102' ~--y 3-1 J2" HES X NiP, fD = 2.813" 4123' 3-112" HES X NIP, ID = 2.813" 3-112" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~-{ 4135' PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF: 32 @ 2775' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 2775 - 27$0 O 03/25/07 2" 6 2870 - 2875 O 03/25/07 2-112" 4 4750 - 4765 S 03/03/07 2-1/2" 4 4810 - 4830 S 03/03/07 2-1/2" 4 4845 - 4855 S 03/03{07 2-1/2" 4 4954 - 4989 S 03/03/07 I TOP OF FILL 103/4/07) PBTD I-I 5157' 7" CSG, 26#, L-80, ID = 6.276" DATE REV BY COMMESITS DATE REV BY COMMENTS 01101/02 CH/KAK ORIGINAL COMPLETION 11/30!07 TW/JPJC SHALLOW CSG LEAK SFTY NOTE 04/01/05 ???ITCH JET PUMP/PKRS PULLED 11/04 12/15/07 TW/PJC PE=RF CORRECTIONS 12/04/06 RAC/TLH TREE CORRECTION 03/04/07 SRB/TLH P&A 03/08/07 GJB/PAG JET CUT @ 4062' [1M (03/07/07) 03/25/07 JMF/PJC PERFORATIONS ORION UNfT WELL: V-201 PERMfT No: 2012220 API No: 50-029-23054-00 SEC 11, T11 N, R11 E, 4838' NSL & 1775' WEL BP Exploration (Alaska) S OTES: ***W ELL HAS SHALLOW it V ~~ O ~ SU CASING LEAK**'' ~I 975' 9-5/8" TAM PORT COLLAR ® 2201' 3-1l2" CAMCO B-61 SSSVN, ID = 2.812" II I 2775' - 2780' 2-1(2", 6 spf, PERF THRU TBG &CSG 2870' - 2875' 2", 6 spf, PERF THRU TBG &CSG GAS LIFT MANDRELS i ST MD TVD DEV TYPE VLV LATCH POR7 DATE 3 3814 3426 19 MMG DMY RK 0 09/23/03 2 1 3904 3997 3511 3597 19 19 MMG MMG DMY DMY RK RK 0 0 01/01/02 04/27!02 4141' -j 3-1l2" WLEG, ID = 2.992" 4434'SLM TOP OF CEMENT (03/06/07) 4500' TOP OF CEMENT (03/04/07) 4690' 7" MARKER JT (20') W! RA TAG 4871' 1-17" MARKER JT (20') W/ RA TAG • • ~-~-~~ ~ - r- _ ~ Q`~5~~~~~E~~~~~~ Ems. v~ 0.S ~ iSCO~ c~c.~ vJ~ ~L~ S c~v~cc -~~ ~~ ~ o ~ ~ ~ P w~~~ ~ ~~ E~~ ~ t t- ~ s coM `F ~~ ~~~ ~~ t~ ~~ SEA `~E.c-r~ S v~t~~ ~ "~ov cc~.r. vv~ E rs. ~ ~. ~~ ~~ S ~~ vac'` ~JO~ ~CLl~ ~`~'~ SV h ~ ~~o~ `CJ ~ ~c ~'C MA~~ ~~ ~ -~~'`a~--~-~ 3' lay --o`~ c~c~-~C < r, C~" s~~~ ~ e c~r ~ L ~ 1~.5 ~~a aa~c7'i'~t"w2~`tS~~RFC~s°A,C~~~t"'f~fcL'd`~'~~~y Sv2S~ S Cbu~ G~Rr2 ~~ ~ Z ~` ~~tl"~'~C R v~~ ~ ~ I.~ J ~~~~c o.~ w.~be ~~~ ~o ~`e c-~co~ ~~-p~b~•-mss Pc~,~co~~~ ~r`~`~.~~-~ ~~.~ ~o~L e~ ~ f of'cfi~~v~~tr~cECES~~ ~~u~~'~ Re: V-201Ai Surface Casing Leak Procedures e e Thanks Brandon, I will look forward to receiving the updated work proposal. One thing to note, by the convention the Commission uses all the work done so far is "in" V-20l. V-201A will exist when the window is milled. Good luck, Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/19/2007 11 :07 AM:5CANNED MAR 2 0 2007 Tom Here is what happened on V-201Aí: Event Date Tech Package and SOR issued to Partners 2/2/07 Approve APE electronically 2/2/07 Develop and submit pre-rig work request to Wells Group 2/6/07 Develop and submit Sundry to AOGCC 2/6/07 Develop and submit Permit to Drill 2/8/06 Sundry approved by AOGCC 2/13/07 Partners fully approve APE 2/28/07 Start pre-rig work 2/17/07 P&A (after sundry and partner approval) 3/3/07 Found SC leak during pre-rig OA PT to 2000 psi. OA bled from 2000 3/6/07 psi to 100 psi in 15 minutes. Could smell and see diesel between 9-5/8" x 20". Attempt 1 st circ out. RU to OA and pump 11 bbls of9.8 brine and 7 3/8/07 bbls diesel down OA before fluid leak into cellar. Stop operation and try at later date. Rig release from W-210 - stand by for pre-rig work on V-20lAi. 3/9/07 Attempt 2nd circ out. RU to pump down OA, 1 to 1 returns taken from 3/12/07 4" conductor ports. Cannot bullhead 9.8 brine down OA. Divert rig to V-121 Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) 1 of3 3/19/2007 1 :08 PM Re: V-201Ai Surface Casing Leak Procedures e e Brandon. Peltier(â¿bp. com From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, March 15, 2007 11: 11 AM To: Peltier, Brandon Cc: Tirpack, Robert B Subject: Re: V-201Ai Surface Casing Leak Procedures Brandon and Rob, Since the need for V -121 was accelerated, I understand that the situation on V - 201 had changed. I'd appreciate a summary of the recent activities on V - 201. Thanks in advance. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 3/1212007 8:30 AM: Brandon, Interesting. CP AI has experienced shallow surface casing leaks on a number of wells. Their repair method has been to excavate and weld external sleeves on the surface casing. Y our case is somewhat different since there is a redrill planned for the well. Please note that the following comments are observations on the docuruent that you forwarded. They are NOT directions:on. how to proceed. BP has much greater kÍ}.owledge regarding the condition of the well and the best way to propose and conduct repair operations. I note that there are several activities you propose that would seem to need/require surface casing integrity in order to accomplish successfully and safely. Early in the work, you plan to bullhead the OA with KWF. Based on the information you have provided regarding the attempt to pressure test the OA, it would appear that the OA may be plugged. It is not clear that it was possible to inject any fluid and it seems if the intent was to pressure test the OA that there was an expectation/prior knowledge that injection would not be possible. Later in the procedure advise is given regarding catching/cleaning any spills into the cellar. That advise would seem to apply throughout the planned operations. Have you considered connecting lines to 4" outlet holes on the conductor? Call or message with any questions. Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/9/2007 1 :56 PM: Tom On Tuesday morning a very shallow leak was discoved in the surface casing of V-201Ai. I have attached a summary of events and our plan forward to fix this leak. Please review the new procedures, which are highlighed in blue. The overall scope of the work is to still eventually drill the sidetrack, but with a slightly more complicated decomplete. Please call me any time if you have questions. Brandon Peltier 20f3 3/19/2007 1 :08 PM . V-201Ai Surface Casing leak Repair Procedure: During the pre-rig operations on V-201Ai, a surface casing leak was discovered The leak was found after the well had been P&A'd and while the Wells Group was conducting pressure tests of the tubing and cement plug, the fA, and the OA The tubing and IA pressure tested successfully. When 2000 psi was applied to the OA, the pressure bled down and gas and diesel was venting out of the conductor ports. The leak is believed to be shallow, not more than a few feet below the cellar floor. Diagnostics has shown that the leak is most likely at or just below the collar on the 4' pup joint A thread leak or corrosion leak is suspect because the TOC is -S.S' below the flutes, which would have allowed water to corrode this portion of the casing. More diagnostic work is being conducted pre-rig. . ,- ,·-c..... As part of the pre-rig work the TxlA will be filled with kill weight fluid by circulating through the tubing cut The 9.8 ppg brine will be bull headed down the OA for column of KWF. The OA valve will be lined up to a bleed tank to allow for pressure and flow monitoring. Once the rig moves on, the tubing and 7" casing will be pulled as part of the pre-approved sundry operations. After pulling the 7" casing, a cement plug will be placed across the open hole and into the surface casing shoe. This plug will be tested to 2000 psi to ensure integrity. A storm packer will be placed at -2000' MD as a second mechanical barrier. See the detailed procedure below for full details: V-201Ai - De-complete, Drill, and Complete Procedure Summary - Revision 1: Surface Casing Leak Procedures. Pre-Rig Work: 1. R/U slickline. Drift 3.S" tubing (Min ID: 2.812"). Tag and record PBTD below WLEG. Note: Jet pump pulled and sliding sleeve closed 11/18/04. Removed OGL V and install DGL V 9/23/03. No SSSV installed. 2. PPOT - TxIC. Function test all LDS and repair as needed. 3. Fluid pack the T x IA 4. P&A perfs in 7", 26# casing from top of fill (4854' 1/7/0S) to 4350', which is 400' above the top perforation. RIH with coil tubing to PBTD, lay in 30 bbls of 1S.8 ppg cement Obtain squeeze, but do not exceed a BHP of 2900 psi at top of perfs. Notes: Well has been frac'ed. Assuming a water gradient to surface from the top perf and 900 psi applied fracture pressure (0.45*4400+900=2900psi) gives a max BHP of 2900 psi. If the fracture does open, there is a good chance the well will go in a vacuum. Cement Calc: .038278 bbl/ft x S04' = 19.3 bbls hole volume + 5 bbls into perfs + S bbls extra. S. Pressure test the TxlA to 3,SOO psi for 30 minutes, after WOC. Pressure test the OA to 2000 psi. Bleed all pressures to zero. 6. R/U slickline to run a full bore drift and tag the TOC. . . 7 R/U e-line to Jet cut the 35" 9.3# l-80 tubing in the middle of the 2nd 10' pup joint above the packer Estimated cut depth at 4062' md 8. Circulate the TxlA to seawater through the cut. Freeze protect the TxlA wi diesel to 2500' TVD (-2700' MD) 9. Set BPV in the tubing hanger and test, secure welL 10. Remove well houses and level the pad as needed. Provide well prep costs on hand over form. 11. Bullhead 9.8 ppg brine down OA. Monitor OA pressure. Hook up line from OA valve to bleed tank. Rig Operations: 1. MIRU Nabors 9ES. Circ out diesel FP. Retest barriers. ND tree and tubing adapter. NU BOPE and test to 4,000 psi 12500 psi annular. 2. R/U tubing spear, BOLDS, Pull Hanger. 3. Pull Tubing fl 4062' and dual control lines. RD tubing handling equipment. 4. MU 7", 26# (ID: 6.276") casing scraper, RIH to the 3.5" tubing stub. 5 CBU, POOH, lDscraper. 6. RU e-line USIT, log 7", find cut point 7. RU, run EZSV on e-line, set at 3150', POOH, RD e-line 8. PU, MU BKR csg cut assy, RIH and cut 7" casing (3101' or Mid joint above TOC). Close bag, circ wellbore w/ warm brine and detergent. POOH. Note: Potential leak/spill path through surface casing leak. 9. Spear 7" casing hanger. Pull 7" casing from cut and RD csg equip. 10. RIH w/ 4" DP and place 300' of kick-off cement on top of EZSV, POOH. WOC for compressive strength and test. New Procedures for Corrosion leak found at or below collar: 11. RIH with RTTS on 4" DP to confirm location of SC leak. Set RTTS below the 4' pup and across the first full joint of casing. Pressure up to 2000 psi below, then above the RTTS. Note: Leak expected 5-6' below Gl at first 9-5/8" coliar, but Gould be through casing hanger or due to corrosion below collar. Have catch pans lining the cellar for fluid that escapes the 4" conductor ports. The cellar is 3' deep from the top of the grating floor. The 20" conductor is exposed 33" above the gravel floor. Two 4" circulation ports are l' above the gravel floor. From the open flutes down to cement is 5'6". See attached schematic. 12. RIH and set storm packer at 2000' MD. Test packer. 13. ND BOP and ND wellhead to expose the 9-5/8" casing hanger. Note: There will be a tested storm packer, a cement plug and KWF acting as barriers prior to ND the BOP and wellhead. Retest barriers if necessary. Suck out any brine in the 9-5/8" as necessary to prevent spills. 14. NU 20" Hydril Diverter stack on 20" landing ring. This will allow for returns to the rig. This must be spotted pre-rig. 15. PU Baker mechanical cutter and cut 9-5/8" casing l' below the casing hanger. This will leave a 3' stub looking up. Remove the cut piece. LD casing cutter. 16. P/U burn shoe, two 30' joints of 16" wash-pipe (enough to swallow the 9-5/8" stub down to the collar) string mill, and DP per Baker. RIH and scrape the 20" conductor to the 7" stub. Reverse well clean with 9.2 ppg brine. Burn down to the collar, pump at high rates to ensure collar OD is clean. POH. 17. RU e-line for string shot across collar. Fire string shot, RD e-line. . . 18< R!H \t/ith Baker back-off too! BHi\ per Baker fishing rep. Locate across the 2nc¡ colla(. Back- off 9-5/8;; stub oer Baker POH \Njth back-off tool. 19. PU 2 - 9-5/8" joints and Baker screw-in SUb. Baker-lock the collar to the pin and the exposed threads on the collar. RIH and screw new collar and joints into the 9-5/8" pinlbox looking up. Apply appropriate make-up torque. Screw in test sub to top of 9-5/8" joint and test casing to 2000 psi. 20. Fill 9-5/8" x 201' annulus with -2 bbls of 15.8 G cement 21. Instail the emergency slips on the 9-5/8" casing. They will fit into the existing landing ring on the 20" conductor. 22. Use a Wachs cutter to cut the 9-5/8" above the landing ring. Cut high enough above the landing ring to leave room for the slip on bell nipple I well head. Typically 5" of the 9-5/8" will be visible between the landing ring and the bottom of the bell nipple / wellhead, this space allows room for welding. 23. Install the slip on FMC bell nipple i wellhead. Weld the outside and inside of the bell nipple as necessary. Test welds per FMC. Follow the Wellhead Welding Guidelines RP. 24. NU the remainder of the wellhead and test. NU BOPE and test. PU BHA as planned and drill production hole section. Continue With DrillinQ Production Hole: 25. MU 8-%" drilling assembly with MWD/GR/Res/Azi-Den/Neu/DWOB/DTORQ/PWD and RIH to kick-off plug. Confirm 4,000 psi cement compressive strength prior to kicking off. 26. Displace over to new 8.8 ppg LSND mud. Drill and kick-off from cement plug. Drill 20' of formation and conduct LOT. (V-201 LOT was 14.94 PPQ EMW) 27. Drill ahead to Production hole Target TD (250' MD below OBe marker). Circulate BU, back- ream, then POOH to run casing. 28. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9-%" annulus. 29. PU DPC guns and RIH wi -160' of 4.5" Power Jet 4505 5 spf, perf guns with Anadrill LWD GR/CCL for gun correlation. 30. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, OBc, and OBd. POOH LD DP and guns. 31. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 32. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 33. Run the 3-%", 9.2#, L-80, TCII completion with a 7" x 3-W' straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OA perfs. 34. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 35. Install and test FMC TWC. Nipple down the BOPE. NU tree with hydraulic actuator, test to !i nnn Mi --- - r--.. 36. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oiler, taking clean brine returns to surface. Allow diesel to u-tube into tubing. . . 37 Install BPV In tubing hanger. Install a VR plug in the Tx 3-'12 annulus valve and secure the well Assure that IA/OA are protected with two barriers 38. Rig down and move off Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves 4. Pull VR plug 5 Install wellhouse and flowlines. . . SARAH PALIN, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Orion Oil Pool, PBU V-201 Sundry Number: 307-057 d,DI~~'Y Dear Mr. Tirpack: &CANNED FEB 1 4 Z007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this /!;day of February, 2007 Enc!. 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time Extens~RCnorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 201-222 / 3. Address: o Stratigraphic ~ Service y)í r!j 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23054-00-00 ¡ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU V-201 / L~;;I Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): Or-\o,,·..... " .. ? ADL 028240 82.1' Prudhoe Bay Field / P.JllaR& Pool 14>' ...<....y. .«...... ... wELLl,;t INUI ...........,<. < ..\</<'.'/ y,\yi'yi·</:Ci.C'·.··./.i! Total Depth MD (ft): Total Depth TVD (ft):Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5270 4892 5157 4785 None None Casino Lennth Size MD TVD Burst Collaose Structural Conductor 107' 34" x 20" 107' 107' 1490 470 Surface 2973' 9-5/8" 3001' 2751' 5750 3090 Intermediate Production 5231' 7" 5257' 4880' 7240 5410 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 4750' - 4989' 4592' - 4499' 3-1/2",9.3# L-80 4136' Packers and SSSV Type: 7" x 3-1/2" Baker Premier Packer packers and SSSV MD (ft): 4077' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal o BOP Sketch o Exploratory o Development ~ Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: February 13, 2007 o Oil o Gas o Plugged ~ Abandoned 17. Verbal Approval: Date: o WAG DGINJ OWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer Signature ~- ~~ð Date d%/7 Prepared By Name/Number: Phone 564-4166 Terrie Hubble, 564-4628 'l-A -" /" Commission Use On Iv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 7ðl- /) &j "7 o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: 4'COO Ç>S C I. ~O Ç) ~~\- -rj Subsequent Form Requ;red: Llr ~ APPROVED BY Date ~8/Ír Approved By: - 7Y COMMISSIONER THE COMMISSION Form 10-403 Revised 06/2006 V ~ '-- 8Ft Submit In Duplicate G\NI L 1 ~i 2007 073 2(/ft? STATE OF ALASKA #¡ ALASKA Oil AND GAS CONSERVATION COMMlJION þJf FEB 0 8 2007 APPLICATION FOR SUNDRY APPROVAlA1a ~:>O.,& 20 AAC 25.280 s a I Gas Cons. Commission RECEIVED OR\ . . To: AOGCC Date: February 5, 2007 From: Brandon Peltier - BPXA GPB Rotary Drilling Engineer Subject: V-201 i Application for Sundry Approval - P&A Current Well Status: The V-201 i injection well was originally a hydraulically-fractured, conventional production well which was converted to injection service in February, 2005 to support the heel sections of the V-202 and V-204 multilateral production wells. Because V- 201 i was not originally desiqned as an injection well, the V-201 i well completion and location relative to the V-202 production well was not optimal, and a rapid water breakthrough occurred through the fractured V-201 i OA sand to the V-202 production well. This breakthrough occurred within a few weeks after V-201 was converted to injection. V-201 i was shut-in..in mid M::HQ...h, 2005 and has not been put back on injection service since then. Due 10 the lack of mechanical zonal isolation in this well, and its fractured status, there is an open conduit between V-201 and \[-202 that will not allow normal waterflood iniection-,- and there are no wellwork remedial options available to' return V-201 i to injection service. Proposed Sidetrack: V-201Ai will be a sidetrack well kicked off from below the surface casing shoe of the existing Orion injection well V-201 i. Before the rig moves on, the existing well needs to be plugged and abandoned and prepared for the rig. This will be accomplished by placing cement across the existing perforations and cutting the 3.5" tubing. When the rig moves onto the well, the tubing will be pulled, the 7" casing cut and pulled, and the well will be sidetracked. New 7" casing will be run and cemented in the 8.75" hole section and a 3.5" completion will be run in the new well bore. V-201 Ai - Drill and Complete Procedure Summary Pre-Rig Work: 1. R/U slickline. Drift 3.5" tubing (Min ID: 2.812"). Tag and record PBTD below WLEG. Note: Jet pump pulled and sliding sleeve closed 11/18/04. Removed OGL V and install DGL V 9/23/03. No SSSV installed. 2. PPOT - TxIC. Function test all LDS and repair as needed. 3. Fluid pack the T x IA 4. P&A perfs in 7", 26# casing from top of fill (4854' 1/7/05) to 4350', which is 400' above the top perforation. RIH with coil tubing to PBTD, lay in 20 bbls of 15.8 ppg cement. Obtain squeeze, but do not exceed a BHP of 2900 psi at top of perfs. Notes: Well has been fraced. Assuming a water gradient to surface from the top perf and 900 psi applied fracture pressure (0.45*4400+900=2900psi) gives a max BHP of 2900 psi. If the fracture does open, there is a good chance the well will go in a vacuum. Cement Calc: .038278 bbl/ft x 504' = 19.3 bbls. l- 0">' ~ ~.Y>_? ~ ~ . . ~ ~þ.. N)\ ~~M...<L~"",~<è,J. ~\~~\o..crcl ~(~~~., I:~\(¿c.-~'ì.o~u..)\ \\ \\.\a\'-( ~<L ct.~\-ö.\I)\\,,>-W 5. Pressure test the TxlA to 3,500 psi for 30 minutes. Pressure test the OA to 2000 psi. Bleed 1.0. all pressures to zero. ð)- ~ :} It::> 6. R/U slickline to run a full bore drift and tag the TOC. p«.(\ \x \ \€ c¿ II"' 7. R/U e-line to jet cut the 3.5",9.3# L-80 tubing in the middle of the 2nd 10' pup joint above the packer. Estimated cut depth at 4062' md. 8. Circulate the TxlA to seawater through the cut. Freeze protect the TxlA wi diesel to 2500' TVD (-2700' MD) 9. Set BPV in the tubing hanger and test, secure well. 10. Remove wellhouses and level the pad as needed. Provide well prep costs on hand over form. Rig Operations: 1. MIRU Nabors 9ES. NO tree and tubing adapter. NU BOPE and test to 4,000 psi I 2500 psi annular. 2. R/U tubing spear, BOLDS, Pull Hanger, rev circ 9.0 ppg brine through tube cut. 3. Pull Tubing fl 4062' and dual control lines. RD tubing handling equipment. ~~4. Test BOP wi 4" DP 5. MU 7", 26# (10: 6.276") casing scraper, RIH to the 3.5" tubing stub. 6. CBU, POOH, LD scraper. '~7. RU e-line USIT, log 7", find cut point 8. RU, run CIBP on e-line, set at 3150', POOH, RD e-line 9. PU, MU BKR csg cut assy, RIH and cut 7" casing (3101' or Mid joint above TOC), POOH 10. C/o to 7" rams, test 'v 11. Spear 7" casing hanger, close bag, Circ wellbore wi warm seawater, detergent. 12. Pull 7" casing from cut and RD csg equip. ~13. Test BOP wi 4" DP ~ l<ø:~ 'D\:)\S ~ J-L~ 14. RIH wi 4" DP and place 200' of 17# kick-off cement on top of CIBP, POOH. WOC for compressive strength. 15. MU 8-%" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to kick-off plug. Confirm 4,000 psi cement compressive strength prior to kicking off. 16. Displace over to new 8.8 ppg LSND mud. Drill and kick-off from cement plug. 17. Drill ahead to Production hole Target TO (250' MD below OBe marker). Circulate one BU, back-ream out to the surface shoe, then POOH to run casing. 18. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9-%" annulus. 19. PU DPC guns and RIH wi -145' of 4.5" Power Jet 4505 5 spf, perf guns with Anadrill LWD GR/CCL for gun correlation. 20. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, and OBd. POOH LD DP and guns. 21. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 22. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 23. Run the 3-%", 9.2#, L-80, TCII completion with a 7" x 3-W' straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OA perfs. * ~~~ ..:::.' ~ . . 24. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 25. Install and test FMC TWC. Nipple down the BOPE. NU double master valve, test to 5,000 psi. 26. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oiler, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 27. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-%" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 28. Rig down and move off. Post-Rig Work: 1. Nipple up and test the tree to 5,000 psi. 2. R/U Slickline and pull ball and rod / RHC from the tailpipe. 3. Replace the DCR shear valve with a dummy GLV. 4. Pull dummy valves in injection mandrels and replace with injection valves. 5. Pull VR plug. 6. Install wellhouse and flowlines. TREE = 3-1/2" CrN LHEAD= FMC ------~---~,._---,-_._------- CTUA TOR = NA -----------_._._~,-- KB. ELEV = 83.5' -----_.__._---_._-,---~.~._~- SF. ELEV = 60.3' -----~._---------~--- KOP = 900' ----------,------------- Wa_~_~..I1_ªI!_~.__._36 ~,~~O' Datum MD = 4838' -~._------_._---_.."----_.._----- Datum TVD = 4400' SS · V-201 .1 SAFETY NOTES: I PBTO : :~- 975' -9-5/8" TAM PORT COLLAR I 0 2201' l-i3-1/2" CAMCO B-61 SSSVN, 10 = 2.812" , I 3001' ~ ~ GAS LIFT M6.NDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3814 3426 19 M\IIG DMY RK 0 09/23/03 2201' 2 3904 3511 19 M\IIG DMY RK 0 01/01/02 1 3997 3597 19 M\IIG DMY RK 0 04127/02 I I J 4052' 3-112" BKR CMO SLD SLV 1 WI BX PROF, 10 = 2.812" ~ ~ 4077' H 7" X 3-1/2" BKR PREMIER PKR, 10 = 2,869" I I I 4102' H3-112" HES X NIP, 10 = 2.813" I . I 4123' 1-13-1/2" HES X NIP, 10 = 2.813" I H 4135' I H3-1/2" WLEG, 10 = 2,992" I 4141' 50' al perf data . ~ DATE I 4690' H7" MARKER JT (20') W/ RA TAG I 04/01/02 04101102 04/01/02 I] 03/26/02 ~ H7" MARKERJT(20') W/ RA TAG I II 4871' I) I 5157' I , I 5257' 19-5/8" CSG, 40# L-80 BTC, 10 = 8.835" Minimum ID = 2.812" @ 3-1/2" CAMCO SSSVN 13-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" PERFORA -nON SUMJlARY REF LOG: ANGLE A T TOP PERF: 18 @ 47 Note: Refer 10 Production DB for historic SIZE SPF INTERVAL Opn/Sqz 2-1/2" 4 4750-4765 0 2-1/2" 4 4810-4830 0 2-1/2" 4 4845 - 4855 0 2-1/2" 4 4954 - 4989 0 17" CSG, 26#, L-80, 10 = 6,276' DATE 01/01/02 04/01/02 08105103 09/23/03 12/20/03 05114/04 REV BY COM\IIENTS CHlKAK ORIGINAL COMPLETION JGMlKK ADPERFS DTRlKK PULLJET PUMP RWLIKK GL V C/O RLlTLH SET JET PUI\IIP (09123/03) TW/KA K DATUM MD & TVD CORRECTIONS DA TE REV BY COM\llENTS 04/01/05 ???ffiH JET PUMPlPKRS PULLED 11/04 12/04/06 RA CfTl.H TREE CORRECTION ORION UNIT WELL: V-201 PERMIT No: 2012220 API No: 50-029-23054-00 SEC 11, T11 N, R11 E, 4838' NSL & 1775' WEL 8P Exploration (Alaska) V~201 Ai Pre-Rig - TR£E = 3-1/2" CWV WELLHEAD= FMC r~~~~If~==~~~~; rsF.-a.N;---------- -'--6ïi3' lÏ<o~_::=-~~~~~~_~:~==:~§~: IlVax Angle = 36 @ 2380' [5ãfùm-rií1Ö-;-'------'-4838' röa-¡umiV5-;---'--44õõ~ss 19-5/8" CSG, 40# L-80 BTC, 10 = 8.835" H 3001' Minimum ID = 2.812" @ 2201' 3-1/2" CAMCO SSSVN Jet Cut in 3,S" tubing above packer H 4062' 13-1/2" TBG, 9,3#, L-80, .0087 bpf, 10= 2.992" 4135' ÆRFORA TlON SUrvr.llARY REF LOG: ANGLEATTOPÆRF: 18@47S0' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 4750 - 4765 0 04/01/02 2-112" 4 4810 - 4830 0 04/01/02 2-112" 4 484S - 4855 0 04/01/02 2-112" 4 4954 - 4989 0 03/26/02 ¡;:; il C{ g y/ I PBTO i 5157' 17" CSG, 26#, L-80, 10 = 6.276" H 5257' DATE 01/01/02 04/01/02 08/05/03 09123/03 12120103 05114/04 REV BY COIl.1lllENTS CHlKAK ORIGINAL COMPLETION JGM'KK ADPERFS DTRIKK PULL JET PUMP R\lVLJKK GL V C/O RLJ1lH SET JET PUMP (09/23/03) lW/KA K DATUM MD & ìVD CORRECTIONS o I I 975' 2201' ST MD 3 3814 2 3904 1 3997 ìVD 3426 3511 3597 4052' . I SAFETY NOTES: !-i9-5/8" TAM PORT COLLAR I --13-112" CAMeo B-61 SSSVN, ID = 2.812" GAS LlFTM\NDRELS DEV lYPE VLV LATCH 19 MMG DMY RK 19 II.1IIIG DMY RK 19 IIIII/IG DMY RK PORT o o o DATE 09/23/03 01/01/02 04/27/02 3-1/2" BKR CMO SLO SLV WI BX PROF, 10 = 2.812" 4017' -17" X 3-1/2" BKR PREMIER PKR, 10 = 2.869" 4102' H3-1/2" HES X NIP, 10 = 2.813" I 4123' H3-112" HES X NIP, 10 = 2.813" I 4141' -13-1/2" WLEG, 10 = 2.992" I DA TE REV BY COIl.1lllENTS 04/01/0S ???fTLH JET PUMP/PKRS PULLED 11104 12/04/06 RAClTLH TREE CORRECTION Toe -P&A w 11S.8ppg cm! -17" MARKER JT (20') WI RA TAG I - 7" MA RKER JT (20') WI RA TAG I ORION UNIT WELL: V-201 ÆRMlTNo: 2012220 API No: 50-029-23054-00 SEC 11, T11 N, R11 E, 4838' NSL & 1775' WEL BP Exploration (Alaska) · TREE=, 4-1/1S"CW WELLHEAD = FMC -,---------~-------- ACTUA TOR = Leo KB. ELEV = 82.1' ._----------~- BF. ELEV = 53.S' --------------------~- KOP = 3075 ~~______~__·~__r_~_____ Mix ~!!~~=___~~__~_ 432_?' Datum MO = 5812' -------.--.------- Datum 1V0 = 4841' ss 3-1/Z' HES X NIP, ID = 2.813" v-2Ai Prop Completiorel SAFETY NOTES: 19-5/S" CSG, 40# L-BO BTC, 10 = 8.S35" H 3001' Minimum ID = 2.813" 3-1/2" HES X NIPPLE ÆRFORA TION SlJMrtMRY REF LOG: ANGLEA TTOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE xxx 11 9-5/8" TA M PORT COLLAR - IF RUN I ST MO 7 6 5 4 3 2 1 WA TERFLOODlGAS LIFT MANDRELS 1V0 DEV TYPE VLV LATCH PORT MI.«3 DCR-1 RKP 0 WM3-W DMY RK 0 WWG-W OMY RK 0 WM3-W DMY RK 0 WWG-W OMY RK 0 WM3-W DMY RK 0 WWG-W OMY RK 0 DATE xx' H 3-1/2" HES X NIP, 10 = 2.813" I 7" X 3-1/Z' HES AHR Packer, 10 = 2.965" xx' L Phoenix Sensor Sub. 10 = 2.875" xx' l-i 3-1/2" HES X NIP, 10 = 2.S13" I xx' L 7" X 3-1/2" HES AHR Packer, 10 = 2.965" xx' H 3-112" HESX NIP, 10=2.813" I xx' ~ 7" X 3_112" HES AHR Packer, 10 = 2.965 xx' l- Phoenix Sensor Sub, 10 = 2.S75" 7" X 3-112" HES AHR Packer, 10 = 2.965' xx' H 3-1/2" HES X NIP, 10 = 2.S13" I xx' I 3-1/2" HES X NIP, 10 = 2.S13" w/RHC-m plug xx' H 3_112" HES X NIP, ID = 2,S13" I XX' H 3-1/2" WLEG, 10 = 2.905" I 13-1/2" TBG, 9.3#, L-SO, .00S7 bpf, 10 = 2,992" H 4135' I PBTD H 6732' 17" CSG, 26#, L-SO, 10 = 6.276" H 6812' DA TE REV BY COMVIENTS DA TE REV BY 01126/01 BJP Side track completion COMVIENTS ORION UNIT WELL: V-201Ai ÆRMIT No: API No: 50-029-23054-01 SEC 11, T11 N, R11 E, 4838' NSL & 1775' WEL BP Exploration (Alaska) 15'ØØ'Øø'~.D.·_ I -- -::7'- "- PLAN" . E 5200 . & Z øo ;c ~"..O<' "'"""..~.""" :4''''.........,. ..,.,..,..."""" ,'<=.....- £ 5,172 . .fØ~ . tØ5 i ! í !~ . ,I") ;~ ·...V-1Ø2 "'V-201 ;z: $'i 2; 1<11'; 2: I í ¡ I ¡ I ¡ ~ ... & - V-PAD 1Q sPItE ;to¡\)" z E 4400 NOTES 1. DATE OF SURVEY: NOVEMBER 23, 2001. 2. REFERENCE FIELD BOOK WO-01-37, PAGES 35-36. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD '27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATlON. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL PER FR BELL & ASSOCIATES. ELEVATIONS ARE BP MSL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. .- ......, VICINITY MAP N.T.S. 'SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER 23, 2001. LEGEND +- AS-BUILT CONDUCTOR . EXISTING CONDUCTOR LOCATED WITHIN PROTRACTED SEC. 11 T. 11 N. R. 11 E UMIAT MERIDIAN, ALASKA WELL ASP. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINA TES COORDINATES POSlTION(DMS) POSI TI ON(D.DD) BOX ELEV. OFFSETS V-201 5.970.085.11 10,179.89 70'19' 40. 833" 70.3280092' 53.6' 4.838' FSL 590,525.6.3 4,779.68 149'15'56.982" 149.2658280' 1,775' FEL V-102 5,970,089.06 10.179.90 70'19' 40.870" 70.3280195' 53.6' 4,842' FSL 59O,540.35 4,794.92 149'15'56.550" 149.2657083' 1,760' FEL f: ij û IMDœo sc;.u: 1'.,58' JJ LOll IIY 011< ~JìOÇl~~ ,. .'" Nlì:WCfþ 1,.11II( ~~~ . 1 M ~.HO. ~1t IS$U[ F"OR 1I1f'_1\OH IIEIIISIOH Obp WOA V-P AD AS-BUILT CONDUCTORS WELLS V-102 & V-2Ø1 SHEn· 10F . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc REC ) STATE OF ALASKA ) MAR 2 A- /LlU~ ALASKA Oil AND GAS CONSERVATION COMMISSION .! .' .,. REPORT OF SUNDRY WELL OPERATIGN8&Gas~(¡ms.,..~mm¡ssion ^nthonup, 1. Operations Performed: Abandon D \ ')....). .' RepairwellD Plug perforationsD Stimulate D Other[!] Convert to Inj Alter Casing D Change Approved Program D Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] Exploratory D WaiverD Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 201-2220 6. API Numbl 50-029-23054-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.10 8. Property Designation: ADL-0028240 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: V-201 10. Field/Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Oil Pool Service 0 Total Depth measured 5270 feet true vertical 4892.1 feet Effective Depth measured 4885 feet true vertical 4527.0 feet Plugs (measured) Junk (measured) None None Casing CONDUCTOR PRODUCTION SURFACE Length 78 5231 2973 Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 MD TVD 29 107 29.0 - 107.0 26 - 5257 26.0 - 4879.8 28 - 3001 28.0 - 2751.3 Burst 1490 7240 5750 Collapse 470 5410 3090 Perforation depth: Measured depth: 4750 - 4765, 4815 - 4818, 4818 - 4830, 4845 - 4855, 4954 - 4989 True vertical depth: 4398.83 - 4413.08,4460.58 - 4463.43,4463.43 - 4474.83,4489.06 - 4498.56,4592.45 - 4625.62 Tubinç¡ ( size, ç¡rade, and measured depth): 3-1/2" 9.3# L-80 @ 23 4136 SCANNEr! APR 1 8 200~î Packers & SSSV (type & measured depth): 3-1/2" Baker Premier TCII Packer @ 4077 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft MAR 2 9 2005 13 Prior to well operation: Subsequent to operation: Oil-Bbl 289 o Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 0.2 o o -2464 860 Tubing Pressure 283 964 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil 0 GasD Development D ServiceŒ] Signature Garry Catron Garry Catron )d~ LcYti *'^- WAG D GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Form 10-404 Revised 4/2004 ,~~~ ~ ~';. l.) ¡ \ ("'" 1. !\,.',. ..' ...-1\. ,.::>hone 564-4657 I, ! J\ ,C. . '.......,. J ,\ IJ J . .""..... Date 3/22/05 ) ) V-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/19/05 Convert to Water Injection. FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 ) TREE = 3-1 (2" FMC W8..LHEAD = FMC AcïïJArÖR;:; ...... .... ......···NÄ' kä:"äï~V';''''''''''''''''''''''8'3:!5ï BF. ELBI = 60.3' KOP = 900' Max Angle = 36 @ 2380' bätUmMb";;··'- . 4ä3â' 'batunitvÖ;;;; .. ····440Ö' S's 19-5/8" CSG,40#L-80 BTC, ID= 8.835" H 3001' ~ Minimum ID = 2.812" @ 2201' 3-112" CAMCO SSSVN 13-1/2" 1BG, 9.3#, L-80, .0087 bpf, ID = 2.992" l-i 4135' PERFORATION SUMMA. RY RB= LOG: ANGLEATTOPÆRF: 18 @4750' I\bte: Refer to A-oductbn DB for historical perf data SIZ E SPF INTER\! AL OpnlSqz DA TE 2-1/2" 4 4750 - 4765 0 04/01/02 2-1/2" 4 4810-4830 0 04/01/02 2-1/2" 4 4845 - 4855 0 04101/02 2-1/2" 4 4954 - 4989 0 03/26/02 I R31D H 5157' 17" CSG, 26#, L-80, ID = 6.276" l-f 5257' DATE 01/01/02 01/09102 04101102 04/01/02 04/05/03 06/03/03 REV BY CO Mtv'ENTS DA TE CH/KAK ORIGINAL COMPLETION 08105103 DA V IKK GL V #3 C/O, CORRECT PBTD 08/0 7103 JGtvVKK ADPffiFS 09(23/03 JGtvVKK ADPffiFS 12(20103 DRSlTP 1V D CORRECTON 05/14/04 DAClTLP CORRECf GLV, ADD DATUM MD V-201 ) I SAFErY NOTES: ---I 975' 1-19-5/8" TAM FQRT COLLAR I CD 2201' H3-1/2" CAMCO B-6ISSSVN, ID= 2.812" I ~ L ST fvÐ lVD 3 3814 3426 2 3904 3511 1 3997 3597 I I I ~~ I GAS LIFT MA.NDR8..S DEV TYPE V L V LATCH 19 MVlG DMY RK 19 I'vTv1G DMY RK 19 MMG DMY RK PORT o o o DATE 09/23/03 01/01/02 04127102 4052' ~ 3-112" BKR CMDSLD SLY WI BXPROF, ID= 2.812" 4035' I~JETRJrvPW/3-1/2"X-LOa<, OAL=60" (09/23/03) z ~ 4077' 1-17" X 3-1 (2" BKR PREMlffi R<R, ID = 2.869" 4102' 1--13-112" HES X NIP, ID = 2.813" I ~ J 4123' 1-i3-1/2" HES X NIP, ID= 2.813" 1 I \ 4141' 1~3-1/2" WLEG, ID= 2.992" I f-i 4690' 1-i7" MARKERJT (20') WI RA TAG I ~ 4871' 1--17" MARKERJT (20')W/RA TAG I ~ RBI BY COMMENTS D1RIKK PULL JET RJrvP D1RIKK GLV C/O RWL/KK GLV C/O RUTLH SET JEf PUVlP(09/23103) TW/KAK DATUM MD & TV D CORREC1l0NS ORION UNIT WELL: V-201 PERi'v1ITNo: 2012220 AA No: 50-029-23054-00 SEC 11, T11N, R11 E, 4838' NSL & 1775' WEL BP Exploration (Alas ka) MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Rø11 3/ Z4fIK DATE: Wednesday, March 23, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-201 PRUDHOE BAY UN ORIN V-201 Je"t" ~"/')"',,, ::I"~' . ':..,.-< ,ill:"~ 'ti; ',.... .,,', 'I"' FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::s~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN ORIN V-201 API Well Number: 50-029-23054-00-00 Insp Num: mitCS050317140803 Permit Number: 201-222-0 Rei Insp Num: Inspector Name: Chuck Scheve Inspection Date: 3/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-201 Type Inj. N TVD 3759 IA 300 1780 1740 1740 P.T. 2012220 TypeTest SPT Test psi 939.75 OA 120 140 140 140 Interval INIT AL P/F P Tubing 780 780 780 780 Notes: This Well was shut in prior to this MIT, it had previously been on injection. SCANNED APH ~?~ 5 'LOG5 Wednesday, March 23, 2005 Page I of 1 ,.---. ~ ~~!Æ~E [ffi} !Æ~!Æ~~~!Æ / AI,Allilli.& OILAl'WD GAS / CONSERVATION COMMISSION I I FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 23, 2004 Donn Schmohr Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~o~-~'1-L- Re: Prudhoe Bay V-201 304-304 Dear Mr. Schmohr: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ifthe 23rd day fal 'n' holiday or weekend. /' Enclosure vu&A- "ð{ '°12004 p'VS ð'/n /1--- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 r>... 1. Type of Request: D D Abandon Suspend Alter Casing D Repair Well D Change Approved Program 0 Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.10 DF 8. Property Designation: ADL-0028240 11. Total Depth MD (ft): 5270 Casing ~ STATE OF ALASKA Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 00 PerforateD WaiverD Annular DisposalD StimulateD Time ExtensionO OtherŒJ Re-enter Suspended WellO Convert to Injector 5. Permit to Drill Number: 201-2220 Exploratory D Stratigraphic D Service D 9. Well Name and Number: V-201 10. Field/Pool(s): Prudhoe Bay Field I Orion Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): IEffeCtiVe Depth TVD (ft): 5157 4702.8 Size MD TVD ITotal Depth TVD (ft): 4892.1 Length Conductor 78 Production 5231 Surface 2973 Perforation Depth MD (ft): 4750 - 4765 4815 - 4818 4818 - 4830 4845 - 4855 4954 - 4989 Packers and SSSV Type: 3-1/2" Baker Premier TCII Packer 12. Attachments: Description Summary of Proposal Œ Detailed Operations Program D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 4398.83 4413.1 4460.58 4463.4 4463.43 4474.8 4489.06 4498.6 4592.45 4625.6 BOP Sketch D July 20, 2004 Date: top bottom top 29 107 29.0 26 5257 26.0 28 3001 28.0 Tubing Size: 3.5 " 9.3 # Packers and SSSV MD (ft): 6. API Number 50-029-23054-00-00 Plugs (md): None Burst Junk (md): None Collapse bottom 107.0 1490 4879.8 7240 2751.3 5750 Tubing Grade: Tubing MD (ft): L-8<RECE1VED 470 5410 3090 4136 ðl'" n ..~ ;; .. 62004 ~i 01 t. 3rB Cona. ~11IIIørJ 4077 ~ 13. Well Class after proposed work: ExploratoryD DevelopmentD 15. Well Status after proposed work: Oil D GasO WAG 0 GINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name /) ~O~S~Oh/ Signature ~~ 0/' Vð~ Contact ServiceŒ PluggedO WINJŒ Abandoned 0 WDSPLD Prepared by Garry Catron 564-4657. Donn Schmohr Title Phone Petroleum Engineer 564-5494 7/6/04 Commission Use On Iv Conditions of approval: Notify Commission so that a representative may witness BOP TestO Mechanciallntegrity Test œI' d, - 404- Other: ....~' "",,'... . ~ :"..¡' ', "", : " -. ) ,~ rk}ì\¡{~' ,j i. 1~II'a3 2M" Form 10-403 Revised 06/2004 I Sundry N~~4 . ~Ó ~ Location Clearance 0 Dæ'r~)~ _I '~ ¡all~ 2 ¡. "'0, ....."'''" BY ORDER OF THE COMMISSION , ê~ -.l~j 11\\J~~~ OR\G\NAL. _BFI.. SUBMIT IN DUPLICATE ~ TREE = WB..LI"EA D = AClUATOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = DatumTVD= 3-1/2" FMC FMC NA 83.5' 60.3' 900' 36 @ 2380' 483S' 4400' SS 19-5/S" CSG, 40# L-BO BTC, ID = 8,835' H 3001' r-- Minimum ID = 2.812" @2201' 3-112" CAMCO SSSVN 13-1f2"lBG, 9.3#, L-BO, .0087 bpf, ID = 2,992" H 4135' I PERFORATION SUMM<\RY REF LOG: ANGLEATTOPÆRF: 18 @4750' l\i)te: Refer to A"oductbn œ for historical perf data SIZE SPF INfERV AL OpnfSqz C\6. TE 2-1f2" 4 4750- 4765 0 04l01KJ2 2-1/2" 4 4810 - 4830 0 04l01KJ2 2-1f2" 4 4845 - 4855 0 04l01KJ2 2-1f2" 4 4954 - 4989 0 03l26KJ2 ~ 5157' 17" CSG, 26#, L-SO, ID = 6.276" H 5257' DATE 01/01/02 01 f09f02 04f01 f02 04/01/02 04f05f03 06f03f03 REV BY COMM:NfS C\6. TE CH/KAK ORIGINAL COMPLETION 08KJ5f03 C\6. V fKK GL V #3 C/O, CORRECT PBTD 08KJ7/03 JGM'KK ADPffiFS 09/23f03 JGM'KK ADPffiFS 12/20f03 DRSlTP lV D CORRæTON 05f14/04 C\6.aTLP CORREGr GLV, ADD C\6.lUM MD V-201 =~ . - l - "'iT I ~ I ::8: ~ I \ 975' 2201' ST Iv[) 3 3814 2 3904 1 3997 4052' 4035' 4077' ,~ I SAFETY NOTES: H9-5fS" TAM FQRr COLLAR I H3-1/2" CAMCO £HISSSVN, ID= 2.812" I lVD 3426 3511 3597 GAS LIFT M<\NrRB..S DEV TYPE V LV LATCH 19 fvtv1G DMY RK 19 fvtv1G DMY RK 19 fvtv1G DMY RK DATE 09f23103 01f01f02 04/27/02 PORT o o o \-3-1f2" BKR CMDSLD SLV I I Wf BX PROF, ID = 2.812" HJET RJrvf' wf3-1f2" X-LOO<, OAL=60" (09/23/03) H7" X 3-1/2" BKR PREMlffi A<R. ID = 2.869' 4102' H3-1/2" HEB X NIP, ID = 2.813" I 4123' H3-1f2"HEBXNIP,ID=2.813" I 4141' H3-1/2" WLEG, ID= 2.992" I 4690' H7" MARKERJT (20') Wf RA TAG I 4871' H 7" MARKER JT (20') W f RA TAG I RBI BY COMMß\lTS D1RfKK PULL JET RJrvf' D1RfKK GLV C/O RWLfKK GL V cre RUTLH SET JEr PLMP(09f23103) TWfKAK DA lUM MD & TV D CORRECTIONS ORION Ut\IT WELL: V-201 PERMIT No: 2012220 AA No: 50-029-23054-00 sæ 11, T11N, R11 E. 4838' NSL & 1775' WEL BP Exploration (Alas ka) ~ ---- MECHANI CAL INTEGRITY REPORT . ...... :~1:G RELE;..S=:: 12/2~!2vo r [µpO L OPER Ex FIELD is P, p~ 0 n'o v.- ì..-'"ELL NUMBER V - 2-0 I ZD / ,.. 2 Z. 2- ~?UD DA'!Z: 7" C2..sing: TD: 5 2 70rID.. 4r9 l TIn j ?BTD: S J S 7 HD 4 70S TVD Shoe: 51-Sf HD 4fSo TVD¡ DV: l1D -T"vu :f'{ !;LL DATA _:":ìe~: Shoe: MD II :"Joi.:;g: 3-1/2-Packer 4077tID o~ 3¡'A J/ ~ole Size & T ana TVD¡ :OP: HD :'.[I) TVD¡ Set 2..t 41-;& 4750 I to 49891 Perfs ~c?.Þ~'n:c;.~ INTEGRITY - PllRT n Annulus Press Test: ~p 15 m~n 30 min COü:ï:8ents: ML T ~3tU~d. --- 2-ŒCH./L~ICÞ~ INTEGRITY - PART /2 Cement: Volumes :., .Amt. Liner Csg 5q bbk j DV Cült -J"ol to cover per=s ~ S bÍ;) I ~ Theoretical TOC ~S0Zf Cement Bond Log (Yes or No) 'V In AOGCC File . If CEL E val ua tion. zone above pert s E 0{ ce {I % r brnJ'{' 1-0 .-v z.,SSO' ¡)vdlCtLl1¿ ~ USET I z¡-~(Izoo/. Prociu~tion Log: Type Evaluation , ; ¡ ; i CONG.LUSIONS: \ .': ? ar; : 1: AI/. LT ¡'\t?¡ vJ ~J .. ?ar:: 12, /VI L l~dJ(~k.J /~ Ct.ut Yilt. a.u J 4P p to II ed ~r'! ':rl ~-p he 'S/AA11 C€ tAl6 ~ -«/ {OIWo4 " {jçrr. Aofl ¡µfllsV€- Vl1eWeJ, . -. -- bp ~ ~ o BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August4,2004 Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 ! ~ ~ r~ J" ! ') \ì\\i1 RE: Application for conversion to injection service: V-201 Dear Mr Aubert: Per your letter dated May 17, 2004, enclosed is additional data to support the injection conversion request on well V-201. In the interest of being complete, I have included pertinent cement isolation details on V-201 and surrounding wells similar to data supplied in similar Ala requests. Enclosed is: (1) V-201 cement bond log (per your request) (2) Map showing % mile radius wells around V-201 (per your request) (3) Summary of cement isolation details on subject wells. (4) Wellbore schematics and cementing reports on surrounding wells (5) Application for Sundry Approval Please do not hesitate to call if you require additional information to evaluate this application. Donn Schmohr Petroleum Engineer 564-5494 ".--.... ~ ~~~~E lID} ]~~~~~~ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS / CONSERVATION COlWlISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 17, 2004 Donn Schmohr BP Exploration (Alaska) Inc. 900 E. Benson Blvd. P.O. Box 196612 Anchorage, AK 99519 RE: Your request to convert Well V-201 to injection service. Dear Mr. Schmohr: AOGCC hereby denies your application to convert Orion Oil Pool Well V-201 to injection service. The denial is without prejudice. If you wish to resubmit this ap- plication, please include with your submittal the following information in support thereof: (1) a copy of the subject well's cement quality log, and (2) a list of all well penetrations within a one quarter-mile radius (the Area of Review) of the subject well's proposed injection zone. AOGCC appreciates your attention to this matter. SinCerelY~, " \;J6 ~ . Winton Au ert AOGCC 793-1231 ~ ~ V-201 Area - Top Na Structure and ~ Mile Well Spacing \ 9 588,000 589,000 590,000 591,000 592,000 Schrader Bluff Top No 5,973,000 5,972,000 5,971,000 5,970,000 5,969,000 V-201 ntegrity Details on Wells Surrounding Proposed Injector Cement Pressure Tested Bond Log y Y Full Returns Reciprocated Bumped plug Cement height above Na sand (ft) Gauge 30% over Gauge Hole Cement pumped (bbls) Service Current ) N N Y y y y y y y y y y y y y y y y 893 908 759 1054 1374 2374 1982 1767 59 96 145 121 Oil Producer Hydraulic Pump Oil Producer Gas Lift Oil Producer Gas Lift Oil Producer Gas Lift Well Field Proposed Injector V-201 I Orion 1/4 Mile Radius Wells V-107 Borealis V-111 Borealis V-202 Orion N Y Y y y y y y y N Y Y y y y 775 1007 1188 1243 2321 1786 179 157 101 Ivishak Borealis Borealis V-03 V-104* V-105* ) AOGCC Reviewed and approved for injection Note: * /""' TRB:= WB.LI-EAD= AClUATOR = KB. aBl = BF. aBl = KOP= Max Angle = Dallm MD = DallmTVD= 3-112" FMC FMC NA 83.5' 60.3' 900' 36 @ 2380' 4838' 4400' SS 19-5/8" CSG,40#L-æ BTC. 10= 8.835" H 3001' t----' ,. Minimum ID = 2.812"@2201' 3-1fl" CAMCO SSSVN 13-1/2"1BG, 9.3#, L-æ, .0087 bpf, 10=2.992" H 4135' I ÆRFORA TIO'J SUMMI\ RV RB= LOG: ANGLEA TTOP ÆRF: 18 @ 4750' I'bte: Refer to R"ocilcton œ for histaical peñ data SIZE SPF ~ AL OPIÝSqz 00. TE 2-1/2" 4 4750- 4765 0 04l0U)2 2-1/2" 4 4810 - 4830 0 04l0U)2 2-1/2" 4 4845 - 4855 0 04I0U)2 2-1/2" 4 4954 - 4989 0 03l26.u2 ~ V-201 ~ SAFElY NOTES: =~ 975' 1-f9-5/8" TAM FORT COLLAR I . I 2201' H3-1/2" CAMeo ~6ISSSVN. 10= 2.812" I - L - - I I I ~ X ~ I I \ I 4141' H3-1/2" WLEG. 10= 2.992" I 5157' I ~. 5257' ~ 17" CSG, 26#, L-80, I) = 6.276" H DATE 01/01/02 01/09/02 04/01/02 04/01/02 04/05/03 06/03/03 ÆV BY COMÞÆNTS 00. TE CHlKAK ORIGINAL COMPLETION 08,u5/03 00. V/KK GL V #3 ClO, CORÆCT PBTD 08.u7/03 .x3M'KK ADPERFS 09123/03 .x3M'KK ADPERFS 12120/03 DRsrrP lVDCORRB:TDN 05/14/04 00. CITLP COR'ŒCT GL V, A ro oo.lUM MD sl' M> lVD 3 3814 3426 2 3904 3511 1 3997 3597 GAS LFT Ml\NrR8..S œv TYPE VLV LATCH 19 t.t.1G DMY R< 19 t.t.1G DMY R< 19 t.t.1G DMY R< PORT DATE o 09/23103 o 01/01/02 o 04/27/02 4052' 1-/3-1/2" BKRCMDSLDSLV I IW/BXPR:>F,I)=2.812" 4035' H.ET RJt.P w/3-1/2" X-LOa<:, OAL=60" (09/23/03) 4077' H 7" X 3-112" BKR PÆMIER R<R, 10 = 2.869" 4102' H3-1/2" HES X NIP, 1)= 2.813" I 4123' H3-1/2" HES X NIP, 1)= 2.813" I 4690' H7"MARKERJT (20') W/RA TAG I 4871' H7"MARKERJT (20') W/RA TAG I RBI BY COMMEM'S DlRIl<K PULL.ET RJt.P DlRIl<K GL V CO RWL/I<K GL V CO RUTLH SET JET PLfJIP(09i23103) TW/KAK DA lUM MD & TVD CORÆC11Ofoß ORION UNT waL: V-201 ~rrNo: 2012220 AR No: SO-029-23054-00 SEe 11, T11N, R11E. 4838' NSL & 1775' wa BP Exptoratlon (Alaska) Current Status: Poh, lay dn 4" dp 24hr Summary: SWC, rams, test, run 7" csg 1 ant, pkf, test, rih 4" dp. 24hr Forecast: Rih 4" dp, poh laying dn, 3 1/2 anpltn. Comments: No Incidents. No Injuries. No Spills. WX: Temp: -20 Deg. Wind: 10 mph E. CF: -47Deg. HSE & Well Control All Free Days: 311612001 Operator: BP EXPLORATION Well: V-201 Field: PRUDHOE BAY Depth MD: Est. TVD: Progress: Auth Depth: Hole Size: DOUDFSlTarget: 6.7515.87/13.00 Geologist: RADELLA Engineer: MAGEE Supervisor: DECKER/MORRIS 5,270.0 (ft) 4,892.0 (ft) (ft) (ft) Days Since Last DAFWC: 1137 Last Csg Test Press.: 3,500 (psi) Last BOP Press. Test: 12127/2001 Next BOP Press. Test: 1/312002 Last Divertor Drill (03): 1212512001 No. Stop Cards: 6 LOT TVD: LOT EMW: MAASSP: Test Pressure: Kiek Tolerance: Kiek Volume: 2,763.0 (ft) 14.95 (ppg) 811 (psi) 825 (psi) (ppg) (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM at Surface: RPM at Bottom: Torq. on Bottom: Torq. off Bottom: Type: Time/Loc: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: LSND 12:oo/PIT 5,270.0 (ft) 70 (OF) 9.20 (ppg) 50 (slqt) (ppg) 11 (ep) 27 (lbl10002) 9.0 BP EXPLORATION Daily Operations Report Rig: NABORS 9ES Event: DRILL +COMPLETE Well Type: APPRAISAL Current Well Status Casing Size: 7.000 (in.) Costs in: USD Casing (MD): 5,256.6 (ft) AFE No: 5M3504 Next Casing Size: 7.000 (in) AFE Cost: 1,900,000 Next Casing (MD): 5,214.0 (ft) Daily Mud: 1,186 Next Casing (TVD): 4,834.0 (ft) Cum. Mud: 81,062 Liner (MD): Daily Well: 323,413 Liner Top (MD): Cum. Well: 1,237,556 r---. ~ Page 1 of 3 Report: 8 Date: 12130/2001 Rig Accept: 06:00 12124/2001 Rig Release: Spud Date: 12124/2001 Elev Ref: SEA LEVEL KB Elev: 83.50 (ft) Program: Tot. Personnel: 32 Cost Ahead 250,000 USD, Days Ahead 4.00 7 Last Envir. Incident: Last Trip Drill (01): Last Safety Meeting: 12129/2001 12130/2001 Last Accum. Drill (04): 12127/2001 Last Spill Drill: 1213012001 Regulatory Agency Insp: N Pump Slow Pump Rates (Cire) Stroke Rate Pressure() 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: From-To Hrs Phase Task Activity hh:mm (hr) 00:00-03:00 3.00 PROD1 EVAL SWC 03:00-03:30 0.50 PROD1 EVAL LOG 03:30-05:30 2.00 COMP CASE NU 05:30-06:00 0.50 COMP CASE BHALD 06:00-08:00 2.00 COMP CASE RU Rotating Weight: Pick Up Wt.: Slack Off Wt.: Cire. Rate Riser: Circ. Rate Hole: Cire. Off Bottom: Cire. On Bottom: Jar Hrs since Inspect: 119 (hr) Drilling Fluid 8 (lbl100ft2) Ca: 10 (lbl100ft2) K+: 4.8 (cc/30min) CaCI2: (OF) NaCI: (cc/3Omin) CI-: 2 (/32j Sand: 9.00 (ppb) HGS: (ppb) LGS: 0.15 (mL) Pf/Mf: Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate pressureO Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs: 0.00 (hr) Cum. Bit Hrs: Pump Status - Drilling and Riser Pump Type Eft. Strokes Liner Size Cire. Rate (%) (spm) (in) (gpm) 1 0 96 5.500 2 0 96 5.500 Ann. Vel. Riser: (ftImin) Ann. Vel. DC: (ftImin) Ann. Vel. DP: (ftImin) 40 (mglL) (mglL) (%) (%) 300 (mglL) 0.20 (%) 7.11 (ppb) 52.70 (ppb) 0.0510.3 (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) 6.30 (%) 2.0 (%) 91.5 (%) 1 (bbl) (bbl) (bbl) 75.0 (bbl) Operations Summary Code NPT Operation P PJSM, make up and run side wall core. 5084 - 4349 ft. POh, all shots fired ( 45 ), no debris in hole. Recover cores. Rig dn Schlum, release unit. P P Pull wear ring, set test plug, change to 7" rams, test door seals, pull test plug, set wear ring. Lay dn jars, 5" hwdp. P P Rig up for 7" csg run. PrInted: 11212002 12:09:20 PM ~ ~ BP EXPLORATION Daily Operations Report Page 2 of 3 Operator: BP EXPLORATION Rig: NABORS 9ES Report: 8 Well: V-201 Event: DRILL +COMPLETE Date: 12/30/2001 Field: PRUDHOE BAY Well Type: APPRAISAL Operations Summary From-To Hrs Phase Task Activity Code NPT Operation hh:mm (hr) 08:00-09:00 1.00 CaMP CASE RUN P PJSM. make up shoe track. test floats. 09:00-13:00 4.00 COMP CASE RUN P Follow shoe track with 7" 26#. L 80. IBT Mod prod csg to 9 5/8 shoe. 13:00-13:30 0.50 COMP CASE CIR P Break eire. pump csg volume. 7 bpm @ 630 psi. 13:30-16:00 2.50 PROD1 CASE RUN P Resume rih 7" csg to btm 5256 ft. No down drag. Up 210, dn 116 16:00-16:30 0.50 PROD1 CASE CIR P Layout Franks tool, make up cmt he! I lines. 16:30-18:30 2.00 PROD1 CASE CIR P Stage to 7 bpm, recip I eire. cond mud. No losses. 18:30-20:30 2.00 PROD1 CASE CMT P Commence cmt 7" csg per program as follows: Pump 10 bbls CW100 Test lines to 4000 psi. Begin racip csg. Pump 40 bbls CW100 Pump 10 bbls Mudpush XL. 10.2 ppg, drop btm plug. Batch mix and pump 59 bbls 15.8 ppg slurry @ 6 bpm. Drop top plug, Switch to rig pumps, displace with 198 bbls heated I filtered seawater. Bump plug at 1945 hrs with 1500psi. Hold 10 min. Bleed press. check floats. Float holding. Stop racip pipe at 1930 hrs. No losses I gains. 20:30-22:00 1.50 PROD1 CASE CMT P Remove cmt hd, Idg jt, csg equip. clear floor. 22:00-23:00 1.00 PROD1 CASE PRESS P Install 7" pkf and test 5000 psi 115 min. Test successful. 23:00-00:00 1.00 PROD1 CASE PRESS P Change rams to 3.5 X 6 variables, test seme to 3500 psi. 06:00 Update: Rih 4" dp, slip I cut drlg line, Sim-Dp LOT 9 5/8/7". cont rih 4" dp, pump pill, poh laying dn dp. Inj hot oil dn annulus during this period. Remarks Phase PRE SURF TOTALS Prod % Total 36.00 100.0% 54.00 100.0% 180.00 100.0% Materials I Consumption Usage I On Hand I Item 2808 3024 Personnel No. Hours Company No. Hours 1 24.00 BP 1 24.00 BAROID 2 12.00 NABORS Crew 26 12.00 Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW I Units GAL Units Usage I On Hand Item DIESEL Company Company No. 2 Hours 12.00 BP NABORS Supv 0.00 0.0% 0.00 0.0% Total Total Cost % Total Hours USD 36.00 54.00 0.0% 180.00 0.00 Printed: 11212002 12:09:20 PM 0.0% 0.00 0.00 0.0% 0.00 r-- Operator: BP EXPLORATION Well: V-201 Field: PRUDHOE BAY ~ BP EXPLORATION Daily Operations Report Rig: NABORS 9ES Event: DRILL +COMPLETE Well Type: APPRAISAL Cumulative Phase Breakdown Change of Scope Prod % Total NPT % Total WOW Phase PROD1 COMP TOTALS Planned Prod % Total NPT % Total WOW % Total 80.00 100.0% 10.00 100.0% 180.00 100.0% 0.00 Window Top: (ft) Mud Sys Ftg: (ft) Window Desc: CTOD: CTID: 0.0% 0.00 0.0% 0.00 0.0% 0.00 Window I Coiled Tubing Drilling (in) CT Daily Ftg: (ft) (in) CT Cum Ftg: (ft) 0.0% Page 3 of 3 Report: 8 Date: 12/30/2001 0.00 Total Total Cost % Total Hours USD 80.00 10.00 0.0% 180.00 0.00 CT Strength: (psi) CT Length: (ft) Printed: 11212002 12:09:20 PM (f~~'l ~.~ r(\ ~-r f P (IT) r r f^\ r I IÄ\ r..0J í v/ /^\ '.' ~ ¡ .. G ~ ;, : r' ¡ : I ! ! í- i W \ I! / ,~ \ -.. .! '¡ I ~" '., .r ,:::. '. :."._,. I' i r- \ ¡' I L \. I, i .: lu L· ~l\ 1-, I J \ \ , l.' I t i ',' ." i ') LJ :...,1 '.,..:, h l _:..:. ..; ..1.---'... -- ~-' -....... - - ;(,ól- ')..~J- AI,ASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. -r" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 17 2004 Donn Schmohr BP Exploration (Alaska) Inc. 900 E. Benson Blvd. P.O. Box 196612 Anchorage, AK 99519 RE: Your request to convert Well V-201 to injection service. Dear Mr. Schmohr: AOGCC hereby denies your application to convert Orion Oil Pool Well V-201 to injection service. The denial is without prejudice. If you wish to resubmit this ap- plication, please include with your submittal the following information in support thereof: (1) a copy of the subject well's cement quality log, and (2) a list of all well penetrations within a one quarter-mile radius (the Area of Review) of the subject well's proposed injection zone. AOGCC appreciates your attention to this matter. Sincerely, \AJ6 ~,/'!~ Winton A~~ert AOGCC 793-1231 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECE IVED APPLICATION FOR SUNDRY APPROVAL MAY 042004 1. Type of Request: D D Abandon Suspend Alter Casing D Repair Well D Change Approved Program 0 Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.10 DF 8. Property Designation: ADL-028240 3. Address: 11. Total Depth MD (ft): 5270 Casing Length Size Conductor Production 78 5231 2973 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perloration Depth TVD (ft~· 4399 441.. 1 4461 4463 4463 tJ 4 , .8 4489 t..4 4592 \, -6" .6 Surface Perloration Depth MD (ft): 4750 - 4765 4815 - 4818 4818 - 4830 4845 - 4855 4954 - 4989 Packers and SSSV Type: 3-1/2" Baker Premier TCII Packer 12. Attachments: 14. Estimated Date lor Commencing Operation: 16. Verbal Approval: Commission Representative: Printed Name Signature 20 AAC 25.280 Operation Shutdown 0 Plug Perlorations 0 Perlorate New Pool D 4. Current Well Class: Development Œ] MD / top 29 Alaska O~ & Gö:) CUII~. CÛllllni~si, Perlorate D Artdtg~sposa' D StimulateD OtherŒ] Re-enter Suspen d Well 0 Convert to Injector 5. Permit to Drill Number: 201-2220 ~' 29.0 26.0 28.0 ubing Size: 3.5 ' ~.3 # ~ 0 ~ \ \ 6. API Number ..- 50-029-23054-00-00 Plugs (md): None Burst Junk (md): None Collapse Stratigraphic D 9. Well Name and Number: V-201 . 10. Field/Pool(s): Prudhoe Bay Fi d / Orion Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective 4892.1 5157 bottom 107.0 4879.8 2751.3 Tubing Grade: L-80 1490 7240 5750 Tubing MD (ft): 23 470 5410 3090 4136 ~:J::I('k! I ~rs and SSSV MD (ft): (~ ~ ~3. Well Class after proposed work: 11 Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil 0 GasD WAG D G1NJO Commission Use Only Plug Integrity D Conditions of approval: Notify om mission so that a representative may witness Mechanciallntegrity Test 0 Other: Approved by: Form 10-403 Revised 12/2003 Contact 4077 Service ŒJ PluggedD WINJ~ Abandoned D WDSPLD Prepared by Garry Catron 56-1--4657. Donn Schmohr Title Phone Petro~eum Engineer 56rs~4. ~G/r ,~ -,~l 4/27/04 Sundry Number.3¿> <I-It? !' Location Clearance D BY ORDER OF THE COMMISSION Date: ~~~ ORIGINAL - NAY J '1 ,"n~ SUBMIT IN DUPLICATE ? ç'- ;iJ f . ~:], ;-j ~ :,.! DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2012220 Well Name/No. PRUDHOE BAY UNIT V-201 Operator BP EXPLORATION (ALASKA) INC ç p('1~L ) r .Þ-LL "..~ (}- t'" ( API No. 50-029-23054-00-00 MD 5270 TVD 4892 / J Completion Date 3/26/2002 -- Completion Status 1-01L Current Status 1-01L UIC N --- ----- ---- - -- ----- ----------- ----- -------- ------ --.--- --- - - --- ---- ------ -- ------- -- REQUIRED INFORMATION .---- ------------ ----- - -- -------- --- -- - - -- --- ---- __~~-r_~_ctional s_~.~-e~_- ~ y.~?- ,. Mud Log No Samples No --------- --- - ----- - -- --- ----------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital Type Med/Frmt ~,I€'[) --- C- l...ED D Electr Dataset Number Name --- ---------------.---. - -- -----. -- -- - -- 10539 I nduction/Resistivity 10745 See Notes 10540 Magnetic Resonance Log Log Scale Media Run No 1 Interval Start Stop - - --- ---- -. 110 5270 4397 4888 OH/ CH Open Case Received Comments ------------- -- 2/8/2002 4/8/2002 Coil Flag ~D C 2900 5272 Open 2/8/2002 - - - - - -- --- -- - --- ----- ----- - - Well CoreslSamples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? G / N S ~ C. c: VJ.~! Chips Receivec¥?--.:~£j W ~ .. - 0 .( ~l' ' , u - 1) L('1 Daily History Received? Y/N ~/N Formation Tops Analysis Received? WIN -- --- -- - -- ------ --- ------ --- ----- -- - Comments: Compliance Reviewed By: - -,=+-- ~ .~,,-,\ -.- -- -- - - --- - ------- - - - --- ------ . -- -- . . LI _n¡:} -._ )~'f'\J: < l ;. Date: ---L----.. ~/.)_.. _. ~ ì bp _ I - I - JßJ o ," '" ..~. I ..... . .' BP Explorallon (Alaska/lnc 900 East Benson Boulevaro PO Box 196612 Anchorage Alaska 99519-6612 (907) 561·511' I " September 30, 2003 Mark Myers, Director Division of Oil and Gas Department of Natural Resources 550 West 7th Avenue, Suite 800 Anchorage, AK 99501 RE: Orion V-201N-202 Tract Operations Status Report Prudhoe Bay Unit Dear Dr. Myers: BP Exploration (Alaska) Inc. (BPXA), Operator of the Prudhoe Bay Unit, hereby submits the status report requested in your May 14, 2003 letter approving and continuing tract operations for the Orion V-201 and V-202 Wells. The attached status report is similar in content to our April 1 0, 2003 presentation to the Division of Oil & Gas concerning the Orion V-201N-202 Wells. Any questions concerning this status report should be directed to either Gary Gustafson at 564-5304 or Jonathan Williams at 564-5854. Sincerely, ~ ,. ~_ ¿J. /... Brian Huff ' Satellite Resource Manager Greater Prudhoe Bay Attachment: Orion V-201N-202 Status Report Cc: M. Vela, ExxonMobil K. Griffin, Forest Oil D. Kruse, CPAI G.M. Forsthoff, Chevron . Gustafson, P R. Jacobsen, BPXA J. Williams, BPXA Orion V-201N-202 Status Report BP Exploration (Alaska) Inc. (BPXA), Operator of the Prudhoe Bay Unit, received approval on May 14, 2003 to continue Tract Operations of the Orion V-201 Well and to conduct Tract Operations for the Orion V-202 Well. This approval required that BPXA provide the DO&G with a status report of the V-201 and V- 202 Tract Operations on or before October 1, 2003. This status report is similar in format to the April 1 0,2003 presentation to the DO&G. Exhibit I shows the current mechanical configuration of the V-201 and the V-202. V-201 is a vertical well with multiple fracture stimulations over the entire 0 Sand interval. V-202 was drilled as a single 3000' lateral to test the productivity of the OBd interval. V-201 was put on production on April 1 0, 2002. A location map and summary of operations for V-201 is shown in Exhibit II. The well had an initial production rate of over 1,000 bId of 21.5 API oil. Operations on V-201 were problematic on gas lift as it experienced hydrate formation as a result of low wellhead temperatures. The well was converted to jet pump lift and has stable production since the conversion. V-201 currently produces over 600 bId and has a cumulative recovery of 208 mbo as of September 1, 2003. V-202 was put on production on July 4, 2003. A location map and summary of operations for V-202 is shown in Exhibit III. The well had an initial production rate of over 7,000 bId of 22.9 API oil from the OBd interval. V-202 was drilled with oil-based mud as a single long horizontal lateral in the OBd. V-202 currently produces under gas lift at a rate of over 1,700 bId and has cumulative recovery of 162 mbo as of September 1, 2003. Plans for V-202 are to drill two additional horizontal laterals in the OA and Oba in before year-end 2003 to further test the impact of oil-based mud and understand the performance of tri-Iateral wells. The historical production performance for the V-201 and the V-202 is shown in Exhibit IV. The historical performance of these wells and the current production rate of over 2,300 bId, demonstrates that the V-201 and the V-202 Wells are capable of sustained commercial production in sufficient quantities to justify development and continued production from the reservoir. Contìdential "P ~1a'.ln'I..ItI.Ii~1 ..._.. ì....~ ".~.. ,;, ~I ! "~':5 I . .:"t ~.~. .. t. 0'" ¡ ,¡...:. . r:'''...·I·..ln ,".ftJ. '" J].! ","t..rIloh :[·~'I'''r· ..n.b ~, ~:"",,'.r., '2'C II . 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H H ;r c=H H· \:·II~ ""4'''' I 1= !lIT' I'r; "':'~ ; ~~ ...:.1"",.:' HW.t: 1'1 p.: 1 L 0;"''2'[" !£71' I I I I I I I I i l.... l...... '......._. , - '............ ........... ...........- ... ~ .~. Ir,·n~ ~ß' I ~ .~7"[· 9œCI' I to".... "-'" ."". ~.,!!: !...., [of' t~, ...\:'.n::I'F.... .,.,. ~C'I: :"'1'" "T'I!,~'''L :'1'"'5", can R'r t·:.:. 1 , ¡ ij.~~"T T:C"c::fIJ" tT ~ :OJ. I ¡'J ¡ ~- ~ 1-+ ¡¡¡:.Ï/4O' t-I" .' 01 , - ~"',," ~,- .. .,. I or I: I . _ , ". r ~. ! .,! .. , ~"II":''"A n71 !-'J.t......... 1..--- . . I ~ ... -.. of , P . . &"-----I ~TH H~ y.... 1:- "'1"<'f'IDI...." c- ~ .,1:' 4941' H', ,;""~ ¡. p.,-. £'- ~III!' I 4362' ~ I r,;- t«"~ .]'1 I'" D . ~ , Jr" I L I 4002' H', \;- ..,,~r. r·-' r-- E-------I 511 og' H:'" )I E'" (I"." :\"E"'L..... T:,r['-:" ['. ~ '!.!o· . 8: - :~c: T! '" L..!i[· ["'. r 1"=' H 5'J66' I------ .:, . 'L ' 'I'. . 1'·' ':" 'I1:'J:'. IJ ,» I.~" ".~~~p- CI- J '<9'- t-I 4001' J-----7 ~ ." t-I . .HII",- .- I ----I 'fíj¡' t1' ;" 1, q ~ -----1 '1.... t-I' , * , ' ~I ~ ~~I" 1-1' .- ,., I ;. . , 'I I' .:"r.; :¡¡. ~.' '~'.. ~ : ';,' H ~In ~ :::: g: I rJllnlmu m ID = 2. 750~ .'11' 59? l' I 4-1.2~ HE5 XN rIIPPLE ""NO·GO I ~740' H"",7-Io.t~U4'c.!1.'· r-HI,-cl Ir ,'I ._"" 1." .~. _'1..r .~ "----- -'9&7' 5061 51t11' 571'" I J~.rn; ~'.'''' r.....7, t- ,T: i..... ~ L n '.\A'lJIð ~ -:;.-, ','" rd:] 1%'.' 'T're ,'L', L.,I'·':1t 1:"('1"'II'I C"'t' ... 2= ...,1·, Je. 1:.&:;': D:'I'.or ~.. H \: ~, I: ~~ ~ .IJ~~ . """ .:'" ~j.:;' [""'1' .,It. ., r ~ ,,~ ~ "~"I .'IJ ~::¡ tœ'j.; -:-r.. n~ 3; 'r,"IJ~ .., .c~~ . Uf r; '-ß:,; ~r»~ !"It' '·51 ", ISIIILCM ~ ACII, MOt USlDrct'liGL -! .""L ''':'''r .,. .. :::L IIIII.,rmn D · Utt7" g ,.." ]·112- 1:....[0 !o!!i!50''N - '. ., 'l'; 'I lit.; ,', >. 'f !II ¡ '--;:1 F'f r" .1" . _"'!'""-... v '£ , '. .. 1-:1 #'!' ; . .', ., ~~' ..~ i . -~,.... JHI" J-I I I[··~'" '=~G -e.!" L~ D' 1 :"5' H 254]' t----I I 22JT H"'-:;0.e;or (;'_'81! I H~[ ~ ~ ~" !.ì" c:'" ~W5! II" e..a·· Iij.:;r-.. \a,AnQI¡- 't. Un t.b - b.Þ.mTII: . ¡';Jj' t-I' ~ ,..~., f ~" ',,' - '. :I. - - , -11'0',:""· . .¡. ,'. ..,. <) ...ç::..,..... .. =--- 'iln.' ~'~".!.I".-,~.'_.rl -.::~.:t'·' I .,1J'TP'1«'''1O· V·201 "10 "r. .1 J. BoIIETY NJTEI!!I INC;UHATION. 70 ŒOo!' 5D7!ï HœllmNT-.L '!! ~Ul2·. - V-202 T"lr- .·1,1r--:.....· \.,n.J..J-r.....J: - "'."1: ~I!' 1- ...CTU.."."'- H.I. Œ. 11.8.' . :if ~. II." _ '.."'1" _ ~ i ~" ::. . , .t. -F- ·"~"r. .-"~:-. a";"~~"':""·_~·~~~.:;a-r..~wr--_.::.---..__.".. · Orion J . " , \~.-...-t \ / ) 7~\., ......- Exhibit I: V-201 & V-202 Well bore Schematics l Orion ~\'(.--4'~ \! ) r-\ i' \ ~_... :xhi ::>it :::: Orion V-202 0 3d Status .~ .-..-'.. - ...-- ,,",' ~. - . ~~~~~?"'"':~~Y7'~~"~r_o:-:-::-~;-." -:. , . - . .. ". . ~ -- . 'õI.~_.."'.~~~'''~......","~,p".... . V -202 Objectives 5,97B,OOO · Stand Alone Test of OBd Sand. · Usage of oil-based mud and effects on well productivity · 1 st Orion Horizontal (will be a Tri- Lateral - lats 2&3 to be drilled in Oct.) ~ __..__ .. ___......._., ._0 _'---__ __. 7"1 . _~_____._ . ......._' ; ._... ~__, .., ._-._~__.. "_ ....__ _ . _ IP (7/4/03): 7000 BOPD x OO¡oWC x 400 GOR (API = 22.9) Current Production : 1721 BOPD x OO¡oWC x 400-600 GOR (9/1/03) 162 mbo Cumulative Production to 9/1103 Completion: - 7 5/8" longstring wi 4 ~" tubing - 3000' 4 ~" slotted liner -Gas Lift Completion -Gas Lift WHT = 59F Confidential 5,976,000 5,97.\,000 5,972,000 5,970,000 \... 586.000 588,000 592,000 594,000 590,000 Schrader Bluff Top OA Depth Structure Map With Planned V-202 Multi-Lateral Producer 8/3/2003 7/3/2003 o 6/3/2003 ('"on fidentia] o · - - - - - - - - - - - - - 3000 : _u______ _______________'______________________ 7000 - - - - - - - - - - - - - - - - - - - - - - - - - - -, - - _ _ _ _ _ _ _ _ _ " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2500 G1 I :::: ~ : : : : - : : : : -- : : : : : - : : : : : : : : : ::: - - - - : : : : : : : : : : : : : : : - : ~ _ _ _ : -: : : : : : : : : : : : : : : : : : : : : :: - ~:: i w - -- -- - -- --y , _ 1000- i :::: ~ : - : : - - : : - : : _ : : : : : : : : : : _ : _ : :1: : : : : : : : : : : : : : : : : : : : : : :~_ _ ": : : : : : : : : : : : : : ~ : : : : : : - : : ~- 500 1000 - - - - - - - - - - - - V-202 8000 -, - -. -- -- -- . .- 3500 -------- -------_.-..---~-_._.--.- -----.- ------~------.- --.-- ----------..--.-." ~._----- --,.-- --. -------.._--. - ------ - --- --- -- .- - ~o . ' 200 - - - - - - - - - -r~-:-t~<J~ - - ~~~:-'^'-C::~-~~i.{-q.=-.~v/: - - - -c~~~ - ;¡ - - - - - - - - ' o _ .. I -J, - ..,~ I " 3/3/2003 4/3/2003 5/3/2003 6/3/2003 7/3/2003 8/3/2003 - 500 =ê Ù) 1000 - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - :- - - - - - - - - - - - - - + - - - - - - - - - - - - - ~ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - :c , C> :e. I - 1500 » c=: 800 - - - - - - - - - - - -. - - - - - - - ,- - - - - - - - - - - - - - ~ - - - - - - .- -,- - - ~ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - !!!. ~ 600 - - --- -- -- --- .:. - - - ! -- --- ~ -- h,::.:.:..::.:;:./ -- : --- · - - -j --- ~ - '-- ~- - 1000 ª :J 400 _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .e: õ I I I - .!. - - - - - - - - - - - - - 1- _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ ;- _ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 1200 - - - - - - - - - -" - A I' I _ 2000 ~, I I I I I ---------- 2500 --- ------ -,-- 1400 --'-.------.--------',-------'-'--,---- I V -201 --Oil -WATER -- GAS II TEST OIL ._-~......---.... .-~'oJo.,...I!":'I;.~,.~....._;:;rjf~~ ~~.s~y.c;-:"',-·~:.: -." , ,. Orion ! . '\ ' -.,/ "r---+ \\.< ) j' _\.. ......- -ests V-201 & V-202 We =xhi.:>i- :V: PB 1I Polaris and Orion Prospects Subject: PBU Polaris and Orion Prospects Date: Wed, 22 May 2002 17:53:23 -0800 From: Jack Hartz <jack_hartz@?admin.state.ak.us> Organization: AOGCC To: "Mcmains~ Stephen" <steve_mcmains@admin.state.ak.us>. "Davies, Stephen" <steve_davies@admin.state.ak.us>. "Crandall, Robert" <bob_crandall@.admin.state.ak.us> CC: "Fleckenstein. Robert" <bob_fleckenstein@admin.state.ak.us> Apparently there is some reporting and well permitting confusion regarding the Schrader Bluff formation prospects in the west PBU. I spoke \vith Don Schmohr this afternoon to clarify the situation as follo\vs: 1. Polaris - Schrader Bluff delineation/development from S and W Pads (there may be some wells from M Pad in the future) in the PBU IPA. The pool number Steve McMains uses is 640160 - Polaris Undefined. THE EXCEPTION - V-200 is a~ll drilled from a site just off the MPU road away from V Pad. V-lOO happens to be in the Polaris P A.~on SChnl0hr mentioned that it has caused confusion at BP also. 2. Orion - Schrader Bluff delineation/development from L & V pads. The pool number Steve McM uses is 640] 35 - Orion Undefined. Note to Steve McMains - the issue of reporting V-201 production to Orion Undefined Pool is correct according to the notes above. The 401 shows Polaris Pool and will have to be corrected on the PTD and in the History Database. r hope this helps. ~~,') \~M") ~ Jack I Jack Hartz <jack_hartz@admin.state.ak.us> I Sr. Petrolewn Reser\'oir Engineer L AJaska Oil & Gas Conser\'ation Commission -- , ?LÆ '·70 f /Lt¿ k Ì\ d('J~. ~ (..ç¿£~- ( 0 (¡.Lf:) r.35 I of I 5/23/02 6: 11 AM ¡¡' \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface rlè>:A~¡¡ ~ 4838' NSL, 1775' WEL, SEC. 11, T11 N, R11 E, UM . ~ ~f;ID- \ At top of productive interval .\ 691' NSL, 2239'WEL, SEC. 02, T11N, R11E, UM .3. z¿,~t2_~ ~~;, ~_~ At total depth ' ~ r. I-'~~:Ä 798' NSL, 2103' WEL, SEC. 02, T11 N, R11 E, UM .;60 -'-- . 1:: ...'...-:':::. ..;- 5. Elevation in feet (indicate KB, DF. etc.) 6. Lease Designation and Serial No. KBE = 82.10' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 12/25/2001 12/28/2001 3/26/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 5270 4892 FT 5157 4785 FT 181 Yes 0 No 22. Type Electric or Other Logs Run RES / AIT, DT / BHC, CNL, LDL, GR, Classification of Service Well 7. Permit Number 201-222 8. API Number 50- 029-23054-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number V-201 11. Field and Pool Prudhoe Bay Field / Polaris Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2201' MD 1900' (Approx.) 23. CASING SIZE 34" X 20" 9-5/8" Caliper, SP, MRES, LWD, MWD, CMR, FMI, DIPOLE SONIC CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 107' 42" 260 sx Arctic Set (Approx.) 28' 30011 12-1/4" 596 sx AS III Lite, 244 sx Class 'G' 26' 5257' 8-3/4" 283 sx Class 'G' WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 L-80 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 SPF MD TVD 25. SIZE 3-1/2",9.3#, L-80 MD TVD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 4136' PACKER SET (MD) 4077' 4750' - 4765' 4815' - 4830' 4845' - 4855' 4954' - 4989' 4592' - 4626' 4399' - 4413' 4461' - 4475' 4489' - 4499' 26. ACID, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4954' - 49891 Frac'd: Placed 188.000# OT 16/20 proppant beh,nd pipe. 47501 -4855' FraC'd: Placed 147.692# ot 16/20 CarDolrte Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit co~:t~~: ' ;', ~ '~r r~ ~ ì .- 1,. r.."... ~'..J. 1!.2..." I ,~... .1.... 2500' 27. Date First Production April 11, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing. gas lift. etc.) Flowing PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL TEST PERIOD OIL-BBL GAs-McF WATER-BBL Sidewall cores taken on 12/30/01. Dean Stark Analysis attached. Form 10-407 Rev. 07-01-80 '1 \ I & Polar ProppanT behind pipe Freeze Protected with 60/40 MeOH CHOKE SIZE GAS-OIL RATIO OIL GRAVITy-API (CORR) r. (..- ;..... .....r !-, ":.' -'/",.":1 t .,. ,', . _. '. J .........1... ~... A~aska i];¡ {~.. ;~~.~ ~ f(. i\~~" .~;/,\·:~;¡:~Ò,.-~¡i~ .Am:hQr~:1)~ RBDMS 8Ft Submit In Duplicate 3 :UC ~) F- MAY Sidewall Core Analysis, Leak-Off Test Summary, Summary of Daily Drilling Reports, Post Rig Work Summary, and Final Surveys. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerTie Hubble ~aN\.Ì(. ~ Title Technical Assistant V-201 201-222 Well Number 29. Geologic Markers Marker Name Measured True Vertical Depth Depth NA 4548' 4207' Nb 4573' 4231' Nc 4618' 4273' OA 4725' 4375' OBa 4797' 4443' OBb 4838' 4482' OBc 4897' 4538' OBd 4950' 4589' OBe 5017' 4652' OBf 5060' 4963' Base of OBf 5114' 4744' 31. List of Attachments: Permit No. I Approval No. INSTRUCTIONS 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. ~,. \ r~ ~ I . \,.' :. . ·M.. þl",1'fo \.. I " n ~, \f ,.- ("1' :., ¡' ',: t. LJ r,:\;'{: 1"..1..1 '1._ . ' ".I~.'ò::" G:I E ~~;;I::~~:~:'>' : \C."" "., Date Olf~?J..I rO~ Prepared By Name/Number: Sandra Stewman, 564-4750 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain, Form 10-407 Rev. 07-01-80 BP Alaska, Inc. . FILE NO. :Hou-020004 Well: V-201 DATE : 22-Jan-02 Orion Schrader Bluff API Prudhoe Bay, Alaska Core Lab ANAL YST : AC - MM p[1~IJLrIJ1'l URrrlCEIJ Dean Stark Analysis of Encapsulated Percussion Sidewall Cores 600 psig NCS GRAIN SMPL DEPTH Kair POR DEN K/Phi Sco Stw Retort Sample Extraction NO. (Feet) (mD) (%) (g/cc) sq rt (%) (%) "'API °API Viscosity, cp Weight, g LITHOLOGY 1 4349.00 458 32.69 2.641 37.4 48.5 16.0 17 10.9 1462 0.258 Sd f gr sslty 2 4379.00 112 29.20 2.668 19.6 3.7 86.2 21 * 1803 0.028 Sd f gr sslty 3 4416.00 160 29.71 2.632 23.2 53.2 17.2 19 11.5 1037 0.282 Sd f gr sshy sslty 4 4431 .00 1050 30.62 2.641 58.6 47.9 16.2 19 10.7 1295 0.254 Sd m-f gr sslty 5 4445.00 861 30.11 2.640 53,5 40.3 52.9 17 11.7 1051 0.242 Sd m-f gr sslty 6 4506.00 1030 28.96 2.668 59.6 4.7 67.2 31 * . 0.010 Sd c-f gr sslty 7 4524.00 169 28.38 2.679 24.4 0.0 75.4 * · * 0.008 Sd c-f gr slty 8 4562.00 126 24.06 2.728 22.9 0.0 90.8 . * * 0.006 Sd vf gr sshy vslty 9 4578.00 420 26.21 2.664 40.0 13.4 47.0 19 * 499 0.094 Sd c-f gr occ peb sslty 10 4581.00 157 28.08 2.678 23.6 16.7 54.1 27 13.6 316 0.182 Sd f-vf gr sslty 11 4587.00 21.2 24.88 2.753 9.2 0.0 82.8 . * . 0.006 Sd vf gr slty 12 4613.00 528 27.22 2.684 44.0 15.7 53.6 21 13.3 430 0.172 Sd f gr slty 13 4625.00 65.4 29.24 2.685 15.0 18.5 60.1 23 · 205 0.068 Sd f-vf gr slty 14 4631.00 255 28.81 2.681 29.8 11.4 84.4 29 * 135 0.068 Sd f-vf gr sslty 15 4727.00 178 30.50 2.661 24.2 30.9 54.4 21 16.3 130 0.182 Sd f gr sslty 16 4735.00 96.9 30.68 2.687 17.8 6.4 41.9 26 16.9 113 0.138 Sd f-vf gr sslty 17 4743.00 173 29.76 2.672 24.1 18.8 50.3 26 16.6 112 0.198 Sd f-vf gr sslty 18 4754.00 235 29.03 2.695 28.5 9.4 60.2 28 .. 103 0.078 Sd f-vf gr sslty 19 4763.00 216 28.41 2.718 27.6 19.3 47.3 22 16.6 109 0.234 Sd f-vf gr sslty 20 4799.00 121 30.89 2.686 19.8 20.2 61.9 25 17.5 99 0.134 Sd vf gr sslty 21 4806.00 632 31.36 2.680 44.9 15.0 59.3 23 17.3 96 0.122 Sd vf gr sslty 22 4811.00 167 28.32 2.706 24.3 45.0 38.0 21 · 114 0.090 Sd f-vf gr sslty 23 4823.00 167 26.61 2.705 25.1 14.5 68.5 27 * 118 0.066 Sd f-vf gr shy lam slty 24 4827.00 681 24.24 2.694 53.0 8.1 52.5 27 16.7 94 0.172 Sd m-f gr sslty 25 4842.00 217 29.77 2.625 27.0 21.9 44.8 21 17.0 122 0.140 Sd f gr sslty BP Alaska, Inc. A FILE NO. :Hou-020004 Well: V-201 DATE : 22-Jan-02 Orion Schrader Bluff API Prudhoe Bay, Alaska Core LaI:Ì ANAL YST : AC - MM P.E:1I1:'LtIJl'l HIIVIu''' Dean Stark Analysis of Encapsulated Percussion Sidewall Cores 600 psig NCS GRAIN SMPL DEPTH Kair POR DEN KIPhi Sco Stw Retort Sample Extraction NO. (Feet) (mD) (%) (g/cc) sq rt (~,~) (%) 0API °API Viscosity, cp Weight, 9 LITHOLOGY 26 4849.00 297 28.58 2.731 32.2 14.5 62.3 22 ~ 125 0.076 Sd vf gr shy vslty 27 4853.00 145 28.79 2.709 22.4 33.0 50.7 20 , 140 0.096 Sd f gr sslty 28 4864.00 308 23.92 2.707 35.9 11.8 74.7 25 , 93 0.054 Sd vf gr slty 29 4887.00 175 28.41 2.710 24.8 20.9 58.7 26 * 101 0.106 Sd vf gr sslty 30 4903.00 56.9 28.94 2.706 14.0 14.0 70.0 26 , 104 0.070 Sd f-vf gr shy vslty 31 4907.00 194 30.90 2.700 25.1 22.3 55.1 23 16.8 96 0.110 Sd f-vf gr sslty 32 4913.00 201 25.80 2.720 27.9 9.7 39.9 28 · * 0,038 Sd vf gr shy vslty 33 4916.00 179 26.41 2.702 26.0 0.0 75.1 , · * 0.026 Sd vf gr shy vslty 34 4953.00 183 28.90 2.714 25.2 53.5 20.1 23 · 125 0.078 Sd vf gr vslty 35 4961.00 251 30.71 2.693 28.6 24.0 58.6 23 16.3 120 0.146 Sd f-vf gr sslty 36 4966.00 172 30.60 2.704 23.7 22.7 61.0 23 · 142 0.102 Sd f-vf gr sshy sslty 37 4973.00 334 30.55 2.702 33.1 25.4 51.7 23 ~ 67 0,082 Sd f-vf gr sshy sslty 38 4985.00 212 28.73 2.677 27.2 13.2 67.2 20 * 109 0.072 Sd f-vf gr sshy sslty 39 4999.00 180 28.14 2.640 25.3 14.1 40.8 25 , 90 0.082 Sd f-vf gr sshy sslty 40 5021.00 335 29.16 2.694 33.9 10.4 52.2 27 , . 0.042 Sd f-vf gr sshy sslty 41 5027.00 567 25.38 2.675 47.3 11.3 83.4 29 * 60 0.050 Sd vf gr slty 42 5040.00 466 26.89 2.623 41.6 17.1 80.9 29 , * 0.028 Sd vf gr shy vslty 43 5063.00 260 27.08 2.727 31.0 10.7 75.1 27 · , 0.040 Sd vf gr shy slty 44 5069.00 100 26.78 2.676 19.3 10.5 84.3 28 * 124 0.048 Sd f-vf gr shy sslty 45 5084.00 251 28.93 2.630 29.5 3.5 61.4 28 * , 0.036 Sd vf gr sshy vslty Note: 'Insufficient Sample for Analysis Legal Name: V-201 Common Name: V-201 Test Date 12/28/2001 Test Type LOT Test Depth (TMD) 3,001.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 2,763.0 (ft) AMW 9.20 (ppg) Surface Pressure Leak Off Pressure (BHP) 825 (psi) 2,145 (psi) Page 1 of 1 EMW 14.95 (ppg) Pr,nlea 1/2/2002 801 34 AM BP EXPLORATION Operations Summary Report Page 1 of4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-201 V-201 DRILL +COMPLETE NABORS NABORS 9ES Start: 12/23/2001 Rig Release: Rig Number: Spud Date: 12/24/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 12/23/2001 12:00 - 16:00 4.00 MOB P PRE Move pit complex away from sub. Move sub complex off well. Tight maneuvering between well houses and light pole on edge of pad. 16:00 - 17:00 1.00 MOB P PRE Lay derrick over. 17'00 - 00:00 7.00 MOB P PRE Move sub complex from W Pad to well V-201. 12/24/2001 00:00 - 06:00 6.00 MOB P PRE Move pit complex, camp and shop to V Pad. Spot complexes over V-201. Hook up lines. 06:00 - 08:00 2.00 RIGU P PRE ACCEPT RIG ON WELL V-201 AT 0600 HRS 12/24/2001. Take on water, Lower blocks, bridle down. 08:00 - 17:00 9.00 RIGU P PRE N/U Diverter & lines, Re- fabricate riser, Mix spud mud, Load Dp & BHA in shed 17:00 - 22:00 5.00 RIGU P PRE P/U 4" DP & HWDP - Stand back in derrick 22:00 - 22:30 0.50 RIGU P PRE Pre- spud Meeting with Rig Team. 22:30 - 23:30 1.00 RIGU P PRE P/U & M/U BHA #1. 23:30 - 00:00 0.50 RIGU P PRE Function Test Diverter System. Witness waived by Jeff Jones, AOGCC. 12/25/2001 00:00 - 00:30 0.50 DRILL P SURF Pre-Spud Meeting w/2nd Crew, TP, Co. Rep. & all Svc Co. Personnel. 00:30 - 03:00 2.50 DRILL P SURF M/U BHA #1. Stand back collars. M/U Bit, Motor, LWD, MWD- Orient same. 03:00 - 18:30 15.50 DRILL P SURF Spud @ 101'. Drill to 300' & Kick-off. Drill 12 1/4" Directional Hole to 1975'. 620 GPM @ 2180psi TQ = 5 - 6K RPM = 60 to 70, P/U = 90K S/O = 80K ROT = 83K AST = 5.2 Hrs. ART = 5.5 Hrs. 18:30 - 19:00 0.50 DRILL P SURF CBU 19:00 - 21 :00 2.00 DRILL P SURF POOH No Problems 21 :00 - 23:30 2.50 DRILL P SURF CIO Bit. RIH. Taking weight from 1100' to 1500' Worked through - OK. RIH to 1882'. 23:30 - 00:00 0.50 DRILL P SURF M/U Top Drive. Wsah last stand to bottom @ 1975'. 12/26/2001 00:00 - 05:00 5.00 DRILL P SURF Drill ahead 12 1/4 hole drctnl, 1975 - 3016 ft. Confirmed TD geologist. WOB 30, RPM 70, SPM 220, Press 3000, GPM 635 Up 107, dn 88, rot 93, tq 6000 AST = 1.6 hrs, ART = 1.6 hrs 05:00 - 06:00 1.00 DRILL P SURF Circ sweep, clean well bore. 06:00 - 08:00 2.00 DRILL P SURF Poh to 900', slight intermittant drag - 40 K between 1400' & 1000' , work free one pass. 08:00 - 08:30 0.50 DRILL P SURF Rih to 1400', hole free, no obstructions. 08:30 - 10:30 2.00 DRILL P SURF Poh for 9 5/8 csg run. Normal drag. 10:30 - 12:30 2.00 DRILL P SURF Handle bha, layout bha #2. 12:30-13:00 0.50 CASE P SURF Make dummy run with 9 5/8 hgr, mark and strap. 13:00 - 15:00 2.00 CASE P SURF Place csg equip on floor, rig up to run same. 15:00 - 20:00 5.00 CASE P SURF PJSM, Make up 9 5/8 shoe track, test float equip, follow with 9 5/840#, L80, BTC csg, filling every jt. No dn drag. 20:00 - 20:30 0.50 CASE P SURF Make up Idg jt. 9 5/8 fluted hgr, land hgr, MU circ hd. 20:30 - 23:00 2.50 CASE P SURF Recip pipe, circ I cond for cmt. 23:00 - 00:00 1.00 CASE P SURF Pump 10 bbl CW1 00, test lines to 3500 psi. 12/27/2001 00:00 - 02:00 2.00 CASE P SURF Cmt 9 5/8 in 12 1/4 open hole as follows: Drop btm plug, pump 75 bbl Mudpush XL spacer, 10.2 ppg Pr,mae 112/2002 801 41 AM BP EXPLORATION Operations Summary Report Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-201 V-201 DRILL +COMPLETE NABORS NABORS 9ES Start: 12/23/2001 Rig Release: Rig Number: Spud Date: 12/24/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 12/27/2001 00:00 - 02·00 2.00 CASE P SURF Mix and pump 472 bb110.7 ppg ASIII Lite, "G" tail slurry Mix and pump 51 bb115.8 ppg "G" tail slurry Drop top plug, displace with rig pumps 212 bbl mud. 9 bpm, no losses at any time. Recip pipe 30 ft strokes during entire job. Bump plug at 0109 hrs with 1040 psi. 3039 strokes correct displacement. Hold press 10 min, bleed, floats holding. 02:00 - 03:30 1.50 CASE P SURF Back out Idg jt, clear floor all csg run equip. 03:30 - 06:00 2.50 CASE P SURF Nipple dn diverter system, all components, layout same. 06:00 - 11 :30 5.50 BOPSUR P PROD1 Nipple up csg hd, test pkf, NU bope. 11:30 - 15:30 4.00 BOPSUR P PROD 1 Prepare and test bope as follows: Rams, annular, kill I choke lines, choke mnfld, standpipe to pumps, floor safety valves, 250 I 3500 psi 15 min. Koomey as per BP Ak specs All tests successful, no retest. Witness waived by Chuck Sheeve AOGCC 15:30 - 16:00 0.50 DRILL P PROD1 Clean rig floor, prepare next phase. 16:00 - 19:00 3.00 DRILL P PROD1 Assemble bha #3, orient. RIH & flow check. 19:00 - 20:30 1.50 DRILL P PROD1 Rih 4" dp in sgls. Work slowly past port collar. 20:30-21:30 1.00 DRILL P PROD1 Resume rih stds dp to 2737 ft, brk circ. 21 :30 - 22:30 1.00 DRILL P PROD1 Test csg to 3500 psi I 30 min. Test successful. 22:30 - 00:00 1.50 DRILL P PROD1 Cont rih 4" dp, wash to 2800 ft. Tag hard cmt at 2833 ft 12/28/2001 00:00 - 02:45 2.75 DRILL P PROD1 Drill cement fr 2833' to 2916', Float collar, cement & shoe.to 3001'. Wash rat hole to 3016'. 02:45 - 03:00 0.25 DRILL P PROD1 Drill 20 ft. New Hole to 3036' Start Mud displacement 03:00 - 04:00 1.00 DRILL P PROD 1 Displace wellbore wI new 9.2 ppg LSND Mud. 04:00 - 04:30 0.50 DRILL P PROD1 Perform Leak Off Test. 9.2 ppg Mud - Surface leak off pressure = 825 psi. Leak Off EM W = 14.94 ppg. 04:30 - 10:30 6.00 DRILL P PROD1 Drill 8 3/4" Directional Hole from 3036' to 3790 ft. Survey 30 ft intervals 10:30 - 20:30 10.00 DRILL P PROD1 Drill 8 3/4 drctnl hole 3790 - 5270 ft. Survey 90 ft intervals. TD at 5270 as per Co. geologist. OBT - 5053 ft, OBT base - 5112 ft (See remarks) WOB 15, RPM 60, Press 2860, SPM 195, GPM 575, Tq 7200 Up 157, Dn 104, Rot 124 ART = 7.8 Hrs AST = 3.3 Hrs 20:30 - 21 :30 1.00 DRILL P PROD1 Circ hi - vis sweep around, shaker clean. 21 :30 - 00:00 2.50 DRILL P PROD 1 Flow check, poh wiper trip to 9 5/8 shoe. Slight drag at 4600 - 4500 ft. 15 - 30 overpull. Recip, work free. Tight at 3350 ft, orient I pull through. Recip, work free Pull to shoe, intermittent swabbing. 12/29/2001 00:00 - 00:30 0.50 DRILL P PROD1 Service Top Drive & draworks. 00:30 - 02:00 1.50 DRILL P PROD1 RIH worked through tight spots between 3312' & 3350'. Cleaned up OK. No problems in rest of hole. 02:00 - 03:30 1.50 DRILL P PROD1 Precautionary wash last stand to bottom. Circ. Sweep. Spot lube pill. 03:30 - 07:00 3.50 DRILL P PROD1 POH to BHA - Hole Slick - No Drag. Pnmea 1I2f2002 80141 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-201 V-201 DRILL +COMPLETE NABORS NABORS 9ES Date From - To Hours Activity Code NPT Phase 12/29/2001 07:00 - 08:30 08:30 - 10:00 1.50 DRILL P 1.50 EVAL P PROD1 PROD1 10:00 - 18:30 8.50 EVAL P PROD1 18:30 - 19:00 0.50 EVAL P 19:00 - 19:30 0.50 EVAL P 19:30 - 23:30 4.00 EVAL P 23:30 - 00:00 0.50 EVAL P 12/30/2001 00:00 - 03:00 3.00 EVAL P 03:00 - 03:30 0.50 EVAL P 03:30 - 05:30 2.00 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 08:00 2.00 CASE P 08:00 - 09:00 1.00 CASE P 09:00 - 13:00 4.00 CASE P 13:00 - 13:30 0.50 CASE P 13:30 - 16:00 2.50 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 18:30 2.00 CASE P 18:30 - 20:30 2.00 CASE P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP PROD1 PROD1 PROD1 PROD1 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 12/31/2001 00:00 - 00:50 00:50 - 01 :00 01 :00 - 03:30 03:30 - 05:00 1.50 CASE P 1.00 CASE P 1.00 CASE P 0.83 CASE P 0.17 CASE P 2.50 CASE P 1.50 CASE P PROD1 PROD1 PROD1 COMP COMP COMP COMP 05:00 - 10:30 10:30-12:30 5.50 CASE P 2.00 EVAL P COMP COMP Page 3 of 4 Start: 12/23/2001 Rig Release: Rig Number: Spud Date: 12/24/2001 End: Description of Operations UD BHA#3. PJSM wI SWS, Crew, TP & Co Rep. Rig up SWS E-Line. Load rad. sources for 1 st. run. # 1 Logging Run: PEX + CMR. TD at 5272, 9 5/8 csg shoe 3001 ft. Log interval td to csg shoe. POH PJSM, unload source, layout #1 run assy. Assemble tools run #2, FMII Dipole Sonic. Rih run #2, log interval - td to csg shoe. POH Layout #2 run assy. Contstant well monitor. Fluid static. PJSM, make up and run side wall core. 5084 - 4349 ft. Poh, all · shots fired ( 45 ), no debris in hole. Recover cores. '_ Rig dn Schlum, release unit. Pull wear ring, set test plug, change to 7" rams, test door seals, pull test plug, set wear ring. Lay dn jars, 5" hwdp. Rig up for 7" csg run. PJSM, make up shoe track, test floats. Follow shoe track with 7" 26#, L 80, IBT Mod prod csg to 9 5/8 shoe. Break circ, pump csg volume, 7 bpm @ 630 psi. Resume rih 7" csg to btm 5256 ft. No down drag. Up 210, dn 116 Layout Franks tool. make up cmt hd I lines. Stage to 7 bpm, recip I circ, cond mud. No losses. Commence cmt 7" csg per program as follows: Pump 10 bbls CW 100 Test lines to 4000 psi. Begin recip csg. Pump 40 bbls CW100 Pump 10 bbls Mudpush XL, 10.2 ppg, drop btm plug. Batch mix and pump 59 bbls 15.8 ppg slurry @ 6 bpm. Drop top plug, Switch to rig pumps, displace with 198 bbls heated I filtered seawater. Bump plug at 1945 hrs with 1500psi. Hold 10 min. Bleed press, check floats. Float holding. Stop recip pipe at 1930 hrs. No losses I gains. Remove cmt hd, Idg jt. csg equip, clear floor. Install 7" pkf and test 5000 psi 115 min. Test successful. Change rams to 3.5 X 6 variables, test same to 3500 psi. Test Door seals to 3500 psi. Install wear bushing. R.I.L.D.S. RIH wI 4" HWDP & DP from derrick to 5000' Cut drilling line, Svc Top Drive - Sim - OP: LOT & Injectivity test on 7" X 9 5/8" Annulus. LOT = 825 psi sfc pres - 14.9 EMW. Injected 135 bbls 9.2 ppg mud. 2 bpm @ 950 psi. 3 bpm @ 825 psi, 4 bpm @ 850 psi. Shut down pumps. static pres - 650psi. Freeze Protect wI 67 bbls dead crude: FCP = 950 psi POH Laying down DP. PJSM RIU SWS. M/U USIT tool. PrlnTee 1/212002 801 4 T AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/31/2001 111/2002 V-201 V-201 DRILL +COMPLETE NABORS NABORS 9ES From - To Hours Activity Code NPT Phase 12:30 - 17:00 4.50 EVAL N DFAL COMP 17:00 - 20:00 3.00 EVAL P COMP 20:00 - 21 :00 1.00 RUNCOI\tP COMP 21 :00 - 22:00 1.00 RUNCOI\tP COMP 22:00 - 00:00 2.00 RUNCOI\tP COMP 00:00 - 06:00 6.00 RUNCOI\tP COMP 06:00 - 07:30 1.50 RUNCOI\tP COMP 07:30 - 11 :30 4.00 RUNCOI\tP COMP 11:30 - 12:00 0.50 RUNCOI\tP COMP 12:00 - 14:30 2.50 RUNCOI\tP COMP 14:30-17:30 3.00 RUNCOI\tP COMP 17:30 - 21 :00 3.50 RUNCOI\tP COMP 21 :00 - 21 :30 0.50 RUNCOI\tP COMP Page 4 of 4 Start: 12/23/2001 Rig Release: Rig Number: Spud Date: 12/24/2001 End: Description of Operations RIH, tool failed, POH Rih, Re-run USIT, poh same. Results = cmt bond 5071 to 3600 ft. (Interval 5071 - 3000) Poh, layout tools, release unit. Test 7" csg to 4000 psi I 30 min. Test successful. No re-test. Perform dummy run with tbg hgr, RU for tbg run. Assemble 3 1/2 completion bha, rih same to 400 ft. 3 1/2, 9.2#, L80, BTC Mod, Baker Premier 3 1/2 X 7 pkr. Cont rih 3 1/2 tbg, make up sssv, connect control lines, test same 5000 psi. Cont rih tbg I control lines. Make up tbg hgr, test control line, land hgr. Drop rod ball assy, Test tbg to 4000 psi. Bleed tbg to 1500 psi. Test anulus to 4000 psi I 30 min. Bleed tbg, shear RP at 2800 psi. All tests successful. No re-tests. Remove Idg jt, install TWC, test below TWC to 1000 psi. ND bope. NU prod tree, test to 5000 psi. Pull TWC with lubricator. Reverse 63 bbls diesel, freeze protect well to 2500 ft. Allow diesel to "U" tube. Install BPV, test below BPV to 1000 psi. Release rig. NABORS RIG 9-ES RELEASED 2130 HRS THIS DATE 1/1/2002 Printed 1/2/2002 801 41 AM Well: Field: API: Permit: V-201 Prudhoe Bay Field / Polaris Pool 50-029-23054-00 201-222 Rig Accept: Rig Spud: Rig Release: Drilling Rig: 12/24/01 1 2/25/01 01/01/02 Nabors 9ES - ..--. - . - - - -.--. . --.-. ---- ----. -.- .-- - -.. - ---.. ---- ..---.. -----.. - ..-- -- - ---- ._-.. -- .-. - --- ..--.. .-. - ---.- -. --.._------ - POST RIG WORK 03/26/02 COMPLETED JEWELRY LOG AND IPERF. SHOT 35' INTERVAL (4954'-4989') W/2.5" POWERFLOW @ 4 SPF-- ALL GUNS SHOT 90 DEG OFF BOTTOM. 03/29/02 SET FRAC SLEAVE @ 2184' WLMD 03/30/02 PULLED FRAC SLEEVE -- DRIFT TBG WI 3' 1-7/8" STEM, 2.78 CENT. & SAMPLE BAILER TO 4818' SLM (PERFS = 4954 TO 4989 MD). RIG UP OS. FRAC SCHRADER BLUFF OBD SAND. PUMP 50 BBL YF125LG FLUIDS. CALC FLUID EFF @ 74% TC=27 MIN. REDUCE PAD TO 30 BBLS (YF125LG). PUMP 60,320# 16/20 C- LITE FROM 1 TO 7 PPA RAMP. PUMPED 128K 16/20 POLAR PROP RCS WI ACTIVATOR FROM 8 TO 13 PPA FLAT STAGES @ 15 BPM. AVERAGE PRESSURE = 1800 PSI. FLUSH WI 62 BBLS SLICK WATER (5 BBL UNDER FLUSH). LEFT 3000# IN WELLBORE. PLACED 188K BEHIND PIPE ALL TREESAVER RUBBERS RETRIEVED. 03/31/02 DRIFT WI 3' 1-7/8" STEM, 2.78 CENT & SAMPLE BAILER TO 4818' WLMD -- PULL DGLV FROM GLM # 1 @ 3997' MD -- SET PETRADAT SPMG IN GLM # 1 -- MITIA TO 3500#. MIRU DS CTU #3. RIH W/2.25" BALL DROP NOZZLE. DRY TAG SAND TOP AT 4818' CTDM. REVERSE CLEAN OUT TO 4890' CTDM. 04/01/02 REVERSE OUT SAND TO 4890' CTDM. LEAK RATE 0.7 BPM/3000 PSI, 0.5 BPM/2500 PSI. PERF 4750-65, 4815-30,4845-55 W/2.5" HMX, 4 SPF, 180 DEG PHASE SWS GUNS. RIH W/2.25" NOZZLE & TAG HARD BTTM AT 4835' CTDM. REVERSE OUT TO 4885'. FRZ PROTECT WELL TO 2500' WITH 60/40 MEOH. 04/02/02 FRAC SCHRADER BLUFF OBB, OBA & OA SAND. PUMP 100 BBL BREAK DOWN WI WF-20. BROKE DOWN @ 4831 PSI @ 35 BPM. PUMPED 80 BBL YF125LG DATA FRAC. CALC TC=27 MIN, FLUID EFF = 72%. PUMPED MAIN TREATMENT: 30 BBL YF125LG PAD AND RAMP FROM 1-6 PPA STEP FROM 6 TO 13 PPA. SWAPPED FROM 16/20 C-LlTE TO 16/20 POLAR PROD DURING 9 PPA STAGE. AVERAGE RATE = 20 BPM, AVE PSI = 1900 PSI. WENT TO FLUSH EARLY DUE TO INCREASING PRESSURE. FLUSHED WI 14 BBLS SLICK WATER AND 40 BBLS DIESEL. PLACED 147,692# BEHIND PIPE ( 39,000# 16/20 C-LlTE AND 110710# POLAR PROP). LEFT -2018# IN PIPE. RECOVERED ALL TREE SAVER CUPS. PULL FRAC SLEEVE FROM 2177' WLMD. DUMP LIQUID LATEX ON FILL @ 4874' WLMD -- SET FRAC SLEEVE @ 2177' WLMD. 04/03/02 MIRU DS CTU #3. RIH W/2.25" BALL DROP NOZZLE. DRY TAG SAND TOP AT 4739' FCO TO 5120' FP WELL TO 2500'. 04/04/02 DRIFTrrAG TO @ 5071' SLM W/2.5" CENT. PULL SPMG FROM STA #1 @ 3997' MD. INSTALL OGLV (W/20/64" ORIFICE). (2"W x 1"L PIECE OF SLIP OFF OF CATCHER SUB LEFT IN HOLE.) RDMO bp V-201 Survey Report - Geodetic Schlumberger Report Date: 23-Apr-2002 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 345.100° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V-Pad I V-201 TVD Reference Datum: KB Well: V -201 TVD Reference Elevation: 82.100 ft relative to MSL Borehole: V-201 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWUAPt#: 500292305400 Magnetic Declination: +26.162') Survey Name I Date: V-2011 April 23, 2002 Total Field Strength: 57470.678 nT Tort I AHD I DDII ERD ratio: 97.008" 11746.76 ft / 5.2611 0.357 Magnetic Dip: 80.751" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: January 08, 2002 Location LatlLong: N 70 19 40.833, W 149 15 56.982 Magnetic Declination Model: BGGM 2001 Location Grid NlE YIX: N 5970085.110 ftUS, E 590525.630 ftUS North Reference: True North Grid Convergence Angle: +0.69132628° Total Corr Mag North -> True North: +26.162° Grid Scale Factor: 0.99990931 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec NI-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) e) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970085.11 590525.63 N 70 1940.833 W 149 1556.982 99.04 0.08 213.01 99.04 -0.05 -0.06 -0.04 0.08 5970085.05 590525.59 N 70 1940.833 W 149 1556.983 205.89 0.10 213.01 205.89 -0.16 -0.20 -0.13 0.02 5970084.91 590525.50 N 70 1940.831 W 149 1556.985 295.32 0.61 329.38 295.32 0.25 0.15 -0.41 0.74 5970085.25 590525.21 N 70 1940.835 W 149 1556.994 387.38 1.51 325.23 387.36 1.86 1.56 -1.36 0.98 5970086.66 590524.26 N 701940.849 W 149 1557.021 478.66 2,12 317.79 478.60 4.49 3.80 -3.18 0.72 5970088.87 590522.41 N 70 1940.871 W 149 1557.074 570.52 3.78 314.76 570.33 8.61 7.19 -6.47 1.81 5970092.22 590519.08 N701940.904 W1491557.170 663.89 5.55 308.74 663.39 14.91 12.19 -12.18 1.96 5970097.15 590513.31 N 70 1940.953 W 149 15 57.337 .~- 753.64 7.65 305.99 752.54 23.04 18.41 -20.39 2.37 5970103.27 590505.02 N 70 1941.014 W 149 15 57,57i 848.71 9.65 307.57 846.52 34.27 26.99 -31 .83 2.12 5970111.71 590493.48 N 70 1941.099 W 149 1557.911 942.08 10.85 308.42 938.40 47.52 37.22 -44.92 1.30 5970121.79 590480.27 N 70 19 41.199 W 149 15 58.293 1034.83 12.67 313.14 1029.20 63.16 49.61 -59.18 2.22 5970133.99 590465.86 N 701941.321 W 1491558.709 1131.04 15.10 314.68 1122.59 82.92 65.63 -75.80 2.55 5970149.82 590449.06 N 70 19 41.479 W 149 15 59.194 1226.23 17.88 314.01 1213.86 106.13 84.51 -95.12 2.93 5970168.46 590429.50 N 70 1941.664 W 149 1559.759 1320.17 20.55 314.13 1302.56 132.62 106.01 -117.33 2.84 5970189.69 590407.04 N701941.876 W 149 160.407 1420.23 22.12 313.14 1395.76 163.66 131.12 -143.69 1.61 5970214.48 590380.38 N 70 1942.123 W 149 16 1 .176 1514.59 24.22 313.72 1482.50 195.26 156.65 -170.64 2.24 5970239.68 590353.13 N 70 1942.374 W 149161.963 1609.38 26.91 313.90 1568.01 230.22 1 84.97 ·200.16 2.84 5970267.63 590323.27 N 70 1942.652 W 149 162.825 V-201 ASP Final Survey. xis Page 1 of 3 4/24/2002-8:26 AM 4/24/2002-8:26 AM Page 2 of 3 V-201 ASP Final Survey.xls Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) ("/100ft) (ftUS) (ftUS) 1704.75 26.37 313.17 1653.25 266.65 214.42 -231.15 0.66 5970296.71 590291.93 N 70 1942.942 W 149163.730 1799.73 27.90 312.24 1737.77 303.22 243.80 -262.99 1.67 5970325.69 590259.74 N 70 1943.231 W 149 164.659 1897.60 29.00 311.58 1823.82 342.24 274.93 -297.69 1.17 5970356.41 590224.67 N 70 19 43.537 W 149 165.672 1994.11 30.62 306.92 1907.57 381.07 305.23 -334.85 2.93 5970386.25 590187.15 N 70 1943.835 W 149 166.757 2092.44 32.67 305.12 1991.28 421.09 335.55 -376.58 2.30 5970416.06 590145.06 N 70 1944.133 W 149 167.976 2189.87 34.02 307.82 2072.67 462.94 367.39 -419.63 2.06 5970447.38 590101.64 N 70 1944.446 W 149 169.232 2284.93 35.58 309.53 2150.73 506.59 401.30 -461.97 1,94 5970480.77 590058.90 N 70 19 44.780 W 149 16 10.468 2380.38 35.72 312.43 2228.30 552.64 437.78 -503.95 1.78 5970516.73 590016.48 N 70 1945.139 W 149 1611.694 2476.00 34.68 316.30 2306.44 599.98 476.28 -543.36 2.57 5970554.76 589976.62 N 70 19 45.517 W 149 16 12.845 -= 2571.43 32.79 319.57 2385.81 647.1 0 515.59 -578.88 2.75 5970593.63 589940.63 N 70 19 45.904 W 149 16 13.882 2667.86 32.42 325.51 2467.06 695.03 556.78 -610.46 3.34 5970634.43 589908.56 N 70 19 46.309 W 149 16 14.804 2763.99 32.18 328.05 2548.32 743.78 599.74 -638.60 1.43 5970677.05 589879.90 N 70 1946.731 W 149 16 15.626 2857.75 31.90 327.67 2627.80 791.28 641 .86 -665.06 0,37 5970718.84 589852.94 N 70 1947.146 W 1491616.398 2944.40 29.45 328.55 2702.32 833.55 679.38 -688.42 2.87 5970756.07 589829.13 N 70 1947.515 W 149 16 17.080 3001.00 30.56 328.33 2751.33 860.67 703.50 -703.23 1.97 5970780.01 589814.03 N 70 1947.752 W 149 16 17.513 3047.97 28.98 328.14 2792.10 882.99 723.33 -715.51 3.37 5970799.68 589801 .51 N 70 1947.947 W 149 1617.871 3143.60 25.49 340.55 2877.19 925.71 762.45 -734.61 6.95 5970838.57 589781.94 N 70 19 48.332 W 149 16 18.429 3238.96 23.14 347.42 2964.10 964.90 800.10 -745.53 3.85 5970876.08 589770.57 N 701948.702 W 1491618.748 3335.45 19.09 353.41 3054.10 999.47 834.30 -751.47 4.75 5970910.20 589764.22 N 70 1949.038 W 149 16 18.922 3431.29 17.47 6.07 3145.14 1028.43 864.18 -751.75 4.46 5970940.08 589763.58 N 70 1949.332 W 1491618.930 3526.90 18.41 20.41 3236.14 1054.16 892.62 -744.96 4.71 5970968.59 589770.02 N 70 1949.612 W 149 1618.732 3622.54 18.02 37.79 3327.06 1075.47 918.48 -730.62 5.68 5970994.63 589784.05 N 70 19 49.866 W 149 16 18.313 3717.84 18.37 47.70 3417.62 1091 .32 940.24 -710.48 3.26 5971016.63 589803.93 N 70 19 50.080 W 149 16 17.725 3813.09 18.55 47.72 3507.96 1105.19 960.54 -688.17 0.19 5971037.19 589825.99 N 70 1950.280 W 149 16 17.074 ___ 3908.36 17.89 52.40 3598.46 1117.81 979.66 -665.36 1.68 5971056.58 589848.56 N 70 19 50.468 W 149 16 16.40f 4003.88 17.74 51.09 3689.40 1129.39 997.75 -642.41 0.45 5971074.95 589871.29 N 70 1950.646 W 149 16 15.738 4099.52 17.77 50.23 3780.49 1141 .46 1016.24 -619.85 0.28 5971093.71 589893.62 N 70 19 50.828 W 149 16 15.079 4194.54 17.87 49.39 3870.95 1153.88 1035.01 -597.64 0.29 5971112.74 589915.60 N 701951.012 W 1491614.431 4290.32 18.11 48.33 3962.05 1166.96 1054.47 -575.37 0.42 5971132.46 589937.64 N 70 1951.204 W 14916 13.781 4386.08 18.21 56.37 4053.05 1178.47 1072.65 -551. 79 2.62 5971150.93 589960.99 N 70 19 51,382 W 149 16 13.092 4481.73 18.13 55.85 4143.93 1188.18 1089.29 -527.03 0.19 5971167.86 589985.55 N 701951.546 W 1491612.369 4578.03 18.24 54.58 4235.42 1198.40 1106.43 -502.35 0.43 5971185.30 590010.02 N 70 1951.715 W 1491611.649 4673.91 18.12 53.71 4326.52 1209.10 1123.95 -478.10 0.31 5971203.11 590034.05 N 70 1951.887 W 1491610.941 4768.87 18.14 53.05 4416.76 1220.03 1141.58 -454.38 0.22 5971221.02 590057.55 N 70 19 52.060 W 149 16 10.248 4864.59 18.40 52.02 4507.66 1231.55 1159.83 -430.57 0.43 5971239.56 590081.14 N 70 1952.240 W 149169.553 4/24/2002-8:26 AM Page 3 of 3 V-201 ASP Final Survey.xls Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ·W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) ('/100ft) (ftUS) (ftUS) 4958.57 18.60 51.74 4596.78 1243.30 1178.24 -407.11 0.23 5971258.24 590104.37 N 70 1952.421 W 149 168.868 5054.14 18.66 51.61 4687.34 1255.44 1197.1 7 -383.16 0.08 5971277.46 590128.09 N 70 1952.607 W 149168.169 5150.76 18.49 51.28 4778.93 1267.79 1216.36 -359.09 0.21 5971296.93 590151.93 N 70 1952.796 W 149 167.466 5198.34 18.30 50.30 4824.08 1273.97 1225.85 -347.45 0.76 5971306.56 590163.44 N 70 19 52.889 W 149 16 7.126 5270.00 18.30 50.30 4892.11 1283.41 1240.22 -330.14 0.00 5971321.14 590180.58 N 70 1953.031 W 149 166.621 ':li""nt. Fi<::ld. . . . EP Expl,:¡rati'Æl './-Pa,j (' .!...l Ô3 ka. ) i'J~11... . . . . . . . - . . . . . .. \.' - ~' (I 1 .. 5 (I - (¡.2 }, -l .::. (I 5':1 - t,) I) .. [iaríún~:':iC:'r .:"F'I nurrJ:...::-i.'. En'.;! i n¿.<:: i." . ':(dJl j'Y;: . STl>.TE.: . . l'J.::d:',,) i.' := 'j E::: l>.laska ----- S"ll.-':E-~' ,:-a,lculati(.n rilE-th(,ds------------- ¡·IE-th(,d f·:'r r:lü-=iti,:,n:=:.. ... [,Jinimurn cur'.'-=:1,ture ¡.j¿.th,y:} f,:,i." DLS...........: I,Jas(n ,~< Ta:...rl,':,1.- - - - - - ü ¿. P t h r ¿. f E- r en,: é - - - - - - - - - - - - - - - - - - - - - - - PennarE:nt datum..........: l'Jean SE-a Le·/¿.l Depth ref~r~nce..........: Driller's Pipe Tall~' '3L abc','.,:,. r,ennanen t . . . . . . . : 56 . r:, (¡ f t 1:2. at,ry..-e p¿.nna.nen t . . . . . . . : Ii.'?, ['f' :;1be,'.c¿, r:"=-rrnan-=nt..,....: 1:::2.1Ci ft - - - - - \l.,:,. 1." tic a 1 5 e c tic. n ( r i ÇT i n - - - - - - - - - - - - - - - - L'3titud"" (+¡.J, 2-) . [¡¿,p:Œtur..::' (+E,t,'J-) . . (1.00 ft (I.O() £t . . F'latt':',nn l.",~f-::'i."-=n':..:: p':"lnt--------------- La tit Ij':-¡ -=- (+ I] .. S - I . . . . . - 9 ~< . ~:' f t [1-= 1='21,1: t u r ë (+ E, t,') - ) . . . . . . . . : <~ 9~:¡ . .=::, t t ;'.zlmuth fl."An rl:,tai."~' cat,lë t.:, ta,rget: ::,;.J.J..?1 [ (c ) .=: 1:1I~ll ":J-lôl,:h 111 I DE.L.L IDt._l '=:' _1 (¡ ) ;'J LÙ. [¡ P ILL SCH LUJ·18EP":';EF', s u c\:~~¡ [f::I:.o:,r t Inc. deç¡ r E é<::, 28-D""c-~001 21:.JS:25 S pu d (J.,S, t. ¿.. . . . . . . . . . . . . . . . Last surve~ d~t~. .. . . . .. . Total accepted surv~~s...: HD of firEt survey. .. HD 0 f 1 as t sur ',:' e j.'. . . . Fag~ 1 (, f oJ ~.J - De-=- - (11 :2 é: - D-=-c - (i 1 57 iJ.Ci(j ft =, 1 9:~ . 3.J f t ----- Ge0maçJn~tic data ---------------------- {.Ja'Jnëtic n'II:,d~l.. . . . . . . . . .: E(;(;I· ':-=-l'E i')r1 ~()I)(J Ma'Jnetic clat-=-............ ¿:cl-[ìe,':<:(I(ll ¡',Jagnetic field sc:c,:;,nÇTth. 11.J9.0~' H~'[]'T MagnE-cic dec (+E,'W-) 26.17 deqrees 1-1 a ç/n E- tic dip..... . . . . . . . . : é: (¡ . 7.J de 'JT e ¿. s - - - - - I ·fvJD sur 'J e y Fe fer Eo nee C r i t e 1." i a - - - - - - - - - Reference G. . . . . . . . . Reference H..... .... Eefererll:'':::- Dip... .... 'I' (' 1 -= 1.- a n c.=::-o f G...... . . . Tolerance of H...,. Tolerance of Dlp... 1(¡(l2 62: rnGal 11.J9.09 HCIj'T 8U. 7.J de,] l"eeE ( + - ) ~, 5(1 rnGal ( + ,'- ) 6.0e¡ H("IJT ( + - ) 1:1.4=, r:] ~ 9 r e ¿. .; - - - - - C (, r l." ~ c t i I:, n == - - - - - - - - - - - - - - - - - - - - - - - - - - - r·Ja,9n¿.t ic de,: (+E' IlJ-) . . . . . : \3r id ,:,)In'-¿.l.-902nCe (+ E hi- I . : 'To tal a,:;:: ':' (¡ r r (+ E. 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'j 1 .;.' t:J 3 ¡ 27 ':Hi :;::~.1 (t (I _0 ¿.i 3 =.. ~.:, /' 3.J 11_ _,:J :J ::~ ~; :' ¡? ~, .J (, :-::; ~ =.' ,'~} ::;:? .J~ ~,"'- 1:: I) (1(1 ~1_ (11 '-, 1:: (11 ~ -.: 9 ~;- _ -., C .:...~, _17 79 ~l-l 76 ~ II:':: 7 <l ~ 0:, ~9 -',(J 7 57 -', (I :~ .J ¿ 313 14 31.J ,58 31.J 01 ~1.J 13 .513 1.J: 31.) 72 ~13 90 .:,L, 17 31::" ~4 3 11 S ::: =.; ( tS 1;:4 =- :;.(1 :> 1 =: ~: II I -' '!'(lS~ ':~ ~1::' .J-, .:,1 t, _, II !. 1 S' ':'-; _' " S :' 1. :3 ~' ,-, (I:J (I (10 99 O-l 11:1 i~, ,-,:: :3 '.::~ .J.:, '~:,~ 06 91 ') B SI 1 8 t~, 'j _", :: 7 :?9 7:> ~15 ()7 '9 _ "37 9¿ 7:J 96 :::1 'j5 19 9~; ';< .J 11) 0 (I 6 94 _6 94 79 9:. 37 ') 4 ~J é: ~,t -; 87 'j'::, S 1 9 _ 3 S17 .J.:, 9': ()(, 'j:: .J:, 9: ':,:: 9: ,,L: 9 c' 4 ~', 'j~, L () (I (J 9 9 (I -l ='1 (I :J ':: 9 = 9 :' 3 ~ .:, ,-, 7 ~ 6 -J7é: C,O 570 ~:_ f,6:'~ :;~1 7 :,~ :,.J :? .J i) :) 2 93""' .:} (J 1029 20 112¿ :\9 1213 86 1302 56 139:,76 1.JfL¿ 50 156E: U1 165~, 15 1737 77 lE:=:3 :~:2 1~07 57 1991 ¿:::: ::. 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ILL S"::-HLUI·]EER(:; EF: 3u 1.-'/¿.:/ F.epo r t ~~ e "~] # -------- -------- [.]¿",:;-¡ sur ¿.d ,j¿.pth ( f t) 29-Dec-2001 00:47:44 ------ ------- ------ -------- -------- ---------------- --------------- PaÇfe ------ ------- ------ -------- -------- ---------------- --------------- Incl anÇJl-= ( dEo-f;r ) ¡....;:. irnuth anqle (deCJ) I,=.'C¡U 1.- S Eo- 1 eIi'J t h ( f t) T'\lD c1~pth ( E t) Vertical sectlCln ( E t ) Displ +[',1/ S- ( f t) Displ -¡- E ,: ~v - ( E t ) T'c, t .:1,1 (lisp1 ( E t ) .;t Azirn 31 -------- ------ ------- ------ -------- -------- ---------------- --------------- (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -, .-, j.j 3<-1 35 36 37 3 ê: =~ 9 40 41 .J~ ':1:?- .J.J .:1 :-' .J I) .J7 .J é: 49 5 (I 51 =,~ ~ì 3 :¡ .J r:;c, _' J :) t) 57 5:? :2857.75 ::94.J..JO .) (10 1 . (I (1 =)\)47 . ~")7 :::143.60 3~38.9r) 3335.4:) 3':131.29 3:)~6.~O 36=:2 54 3717.::::.J 3:313. ()9 390:3. '::,1) 4 (I I) 3 . ~: 8 4099 :.2 4194 54 o.1:l'JO.32 43:::ó.I):? 44:::1 7~; 4578.03 4673.91 4 7 t) 8 . ::: 7 4::::(~.J.:,9 49':,8.:,7 :>Í)54 14 :;1':)0.76 :>1 'j;3 . ~q 5.2 7 I) . I) 0 31.90 2~ . <-15 30.56 2 S 9!::~ :=;:) . <-19 2 =.¡ 14 19.09 17.47 18.41 1~; . 02 1E.37 18.55 17 89 17.74 17.77 17 . :?, 7 1 ':. 11 18.:21 1:::.13 18.2':1 1 ,;.> 12 18 14 1~: . <-1l) 1R 60 1:3 t.(. 1~;..J9 18 30 1:3.30 =, 2. 7 . 6 7 ~':;~3.55 ~~2;?. 33 328.1.J =q I) . 5: 347.42 353.41 6.07 20.41 37.79 47.70 47.72 52.-:1(1 51.09 50.23 .:19 39 4 :::: . 33 56.37 55. 8~, 5.J.5:::: :,3 71 53.0:, 5~.01 51.74 51.61 51.2::: 51) . 30 50.3CI 93 76 86.65 56.60 46.97 95.63 95.36 96.49 95.84 95.61 95.64 95.30 95.25 95.27 95.52 95.64 95.02 'j5.78 95.76 95.65 96.2,(1 95.88 94.9Ó 95.72 93.98 95.57 96.6~ 47.58 71.66 2627.:30 2702 32 2751.33 2792 10 2877.19 2964.10 3054 10 3145.14 3236.14 33~7.06 3417.62 3507.96 3598.4f. 36:39.4(1 3 7 8 I) . ':1 9 3 87 I) . 9 5, 3962.05 4053.05, 41.J3.93 4¿35.42 4326.52 .J.:111:'.7¿, ':1507.66 -1596.78 4687 34 477,3.93 4824.0e ':1892 11 798.61 S.J1.07 868 31 890.73 93~, 58 97?.77 1007 30 1036 13 1061.65 1082.64 1098.09 1111 55 1123.75 113':1.91 11<-16.57 1158.58 1171.24 11B2 33 1191 59 1201 ...,/ 1211.64 1222 14 1233.23 1244.56 12:,6.26 1268.17 1274 14 1283.26 641.86 679.38 703.50 723 33 762.-15 800.10 834 30 864.18 892.62 918.48 940.24 960.54 979.66 997.75 1016.24 1035.01 1054.47 1(172.65 1089.29 1106.43 1123.95 11,,1l.5S 1159.83 1178.24 1197.17 1216.36 1225.85 1240.22 -665.06 -688.42 -703.23 -715.51 -734.61 -7-15.53 -751..J7 -751.75 -7':14.96 -730.6~ -710.48 -688.17 -665.36 -6<:12.41 -619.85 -597.64 -575.37 -551.79 -527.03 -502.35 - 4 7 8 11) -454 38 -':130.57 -407 11 -383 16 -359.09 -347.45 -33(1.14 924.27 967.20 994 71 1017.43 1C158.76 1093.60 1122.83 1145.40 1162.64 1173.63 1178.49 1181.61 118.,1.25 1136.68 119¡).36 1195.16 1201.23 1206.26 1210.08 1¿l5.13 1221.41 1228.68 1237 17 1246.59 1256.99 126:3.25 1274 14 1283.41 313.98 314.62 =n5.01 315.31 316.07 3 1 7 . (I 2 317 9q 318.98 320.15 321 5,0 322.92 324.38 325.82 327.2:2 328.62 330.00 331 38 332 7B 334 18 335.58 336.96 338 30 339.1:'3 3.J0.9<:1 3':12.25 3.,13 55 344 18 345.09 3 ':' E J DLS td'=:9 100 f) 0.37 2.87 1. 97 3 37 ó.95 3.85 4.75 <-1.46 4.71 5.68 3.2ó 0.19 1.68 Û . .J 5 0.2>:: 0.29 0.42 2.62 0.19 D..J3 0.31 0.22 0.43 0.23 0.08 0.21 0.76 0.00 S r \r./ tc,ol t :/p-= IFE IFE IFF IFF IFE IFF IFP. IFF IFP IFF IFF: IFF IFF'. I F¡:;~ IFE IFF IFR IFF IFF IFR IFF IFE IFF. IFF IFR IFF IFF Projected - ------ ------ Tc":·} qual t :/1.:' e ------ ------ Ws WrlL LOG TRANSMITTAL --------- ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7rr'Street Suite # 700 Anchorage. Alaska 99501 RE : Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska]. Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 98508 WELL DATE LOG TvPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 , )L,I-):y), V-20 1 4/1/02 Mech. CH 1 Caliper Survey Signed: , " I Av~~ (jj~L,,_ Date: RECEIVED Print Name: , r"....... r· " r". lO? ~ :,.. I..' '.i i.l'_ Aiaska Oil & Gas Cons, CommiSsion Anchorage. PRoAuivE DiAGNOSlic SERvin,;, INc, } 10 K SIRHr Suin 200, ¡\NdIORAGE, AK 99~01 Phonc:(907) ~'¡'5-8951 Fa:x:(907) 1'¡'S-895~ E-mail: pdsanchoragell}mcmorylog.com Websilc: , ,0\ 1 I' ~ - I " , I ~~fÆ~~ r;;::--., F fÆ~fÆ~~~~ / I / I / / TONY KNOWLES, GOVERNOR ~ ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit V-201 BP Exploration (Alaska) Inc. Permit No: 201-222 Sur Loc: 4838' NSL, 1775' WEL, Sec. 11, TlIN, RIlE, UM Btmhole Loc. 801' NSL. 2125' WEL, Sec. 02, TIIN, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced well. The penn it to drill does not exempt you from obtaining additional permits required by la\v from other governmental agencies. and does not authorize conducting drilling operations until an other required pemlitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit V -201. Blowout prevention equipment (BOPE) n1ust 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 \vitness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petr01eum field inspector on the North Slope pager at 659-3607. Sincerely, 6l/h~, J:Je: /'-0 L· ){~1G.-L/ Cammy 6echsli Tayloi-·\ Chair BY ORDER OF THE COM1\1ISSION DA TED this 30th day of November, 2001 jjc/Enc1osures cc: Department of Fish & Game, Habitat Section \v/o encl. Department of Environmental Conservation \Vlo encI. STATE OF ALASKA ALASKA Ol~ ND GAS CONSERVATION COMMISij N PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work iii Drill 0 Redrill 1 b. Type of well ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4838' NSL, 1775' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 693' NSL, 2231' WEL, SEC. 02, T11 N, R11 E, UM At total depth 801' NSL, 2125' WEL, SEC. 02, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028241, 3154' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size CasinQ WeiQht Grade CouplinQ 3411 x 2011 91.5# H-40 Weld 12-1/411 9-5/811 40# L-80 BTC 8-3/411 T' 26# L-80 BTC Hole 4211 LenQth 801 3005' 52141 :31., 'I If ; 1/-5£.'" 'c I ,diu· /./' /-5 l kJ /// '-? c. o Exploratory 0 Stratigraphic Test iii Development Oil o Service 0 Development Gas [3'Single Zon~ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Fiéld and Pool Plan KBE = 83.5' Prudhoe Bay Field / Polaris 6. Property Designation Pool (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number V-201 9. Approximate spud date 12/01101 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 5214' MD / 4834' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 38 0 Maximum surface 1720 psig, At total depth (TVD) 4383' I 2200 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 80' 80' Surface Surface 3005' 2744' Surface Surface 5214' 4834' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (include staQe data) 260 sx Arctic Set (Approx.) 442 sx AS Lite, 244 sx Class 'G' 164 sx Class 'GI 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Perforation depth: measured true vertical Size Cemented MD TVD RECE\VED NOV 1 5 Z001 ,..01 &Ga&ConS. CommissiOn AndØ8Q8 20. Attachments iii Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 1m Drilling Program iii Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requi rements Contact Engineer Name/Number: Robe Odenthal. 564-4387 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th; fore ing is true an~~ct to the best of my knowledge Signed Lowell Crane (J(.~1 /~ Title Senior Drilling Engineer Commission Use Only Date /(-1') -..:::.f Permit Number API Number . / :.L./- .:: ~ 2- 50- () zq· 2.30S-y- ()() Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes c¡ No Required Working Pressure for BOPE 0 2K 0 3K Other: ~~v I Date See cover letter /! L-~) tJ / for other requirements Mud L g R qui red 0 Yes ~ No Directional Survey Required 51 Yes 0 No D4K D5K D10K D15K ~.5KPSif~ Approved By Form 10-401 Rev. 12-01-85 Original Signed By Cammy Oechsli Commissioner by order of the commission Date 1/ /?¡/q ! Submit In Triplicate ORIGINAL \Well Name: IV-201 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Surface Location: UG3 Target Reservoir Target Bottom Hole Location: x = 590,526' Y = 5,970,085.4' 4838' FSL, 1775'FEL,Sec. 11, T11N, R11E X = 589,800' Y = 5,970,950' 431'FSL,2490'FEL,Sec.2,T11N,R11E X = 590,055' Y = 5,971,215' 693' FSL, 2231' FEL,Sec.2,T11N, R11E X = 590,159.32' Y = 5971323.41' 801'FSL,2125' FEL, Sec. 2, T11N, R11E I AFE Number: 15M3504 I Estimated Start Date: 112/1/2001 I RiQ: I Nabors 9ES I OperatinQ days to complete: 112.5 I MD: 15214' I BF/MS: 155.0' I I RKB: 183.5' I TVD: 14833.5' I I Well DesiQn (conventional, slimhole, etc.): I Ultra slim hole (Iongstring) I Objective: I Schrader Formation Mud Program: Surface Inter\/al (0-3005' 1\ID): Densitv (ppg) Initial Below Permafros( TO 8.5 - 8.6 9.0- 9.5 9.6 max. Viscositv (seconds) Spud l\'lud Fluid Yield Point tauo (1bl 1 OOft2) Obiiõõft2) ill 12 1/4" hole APIFL (mls/30min ) 15 - 20 <8 <8 300 200 200 50 - 70 > 9 45 - 60 > 7 45 - 60 > 7 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 Production Interval (3005-5214' 1\'ID): 6%, KCI Baradril-n Fluid 83/4" hole Density Plastic Vis Yield Point I\IBT API FL HTHP FL Jill CI (ppg) (\b/IOOft~) (rnls/30rnin) ICP) 9.1 8-14 22-27 < 2.5 < 4-6 <10 8.5 - 9.5 27-32k V-201 Permit to Drill Page 1 Directional: Ver. (Anadrill) V-201-(P4) KOP: 300' Maximum Hole Angle: Close Approach Wells: 38.260 at 2297-2736' MD All wells pass major risk criteria. LOQging Program: Surface Production Hole Drilling: MWD (GR IRES) Open Hole: Gas Detection Cased Hole: None Drilling: MWD(GR IRES) Open Hole: PEX, CMR, FMI and Di-pole Sonic, Gas Detection, Cuttings Fluid samples Cased Hole: USIT cement evaluation (contingency) Formation Markers: Formation Tops MDbkb TVD Pore Notes Press Base Permafrost 2068 1984 846 No Hydrocarbons SV3 2273 2154 921 Maybe-Hydrates SV1 2902 2654 1139 Maybe-Hydrates UG4 3217 2939 1270 No UG4A 3249 2969 1400 Yes UG3 3580 3284 1424 Yes Ma 4297 3964 1760 Wet or Heavy Oil Mc 4434 4094 1820 Wet or Heavy Oil Nb 4539 4194 1870 Wet or Heavy Oil OA 4740 4383 1940 Yes OBa 4792 4434 1950 Yes OBb 4834 4474 1970 Yes OBc 4898 4534 1990 Yes OBd 4950 4584 2010 Yes OBe 5019 4649 2030 Yes OBf 5056 4684 2040 Yes TD 2100 V-201 Permit to Drill Page 2 CasinglTubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size TbQ O.D. MDfTVD MDfTVD bkb 42" 34x20" 91.5 H-40 WLD 80' GL 80/80 12 14" 9 5/8" 40 L-80 BTC 3005' GL 3005'/2744' 83J¡." 1'1 26 L-80 BTC 5214' GL 5214'/4834' TubinQ 3-1/2" 9.2 L-80 BTC-Mod 5000' GL 5000'/4614' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from su rface shoe Test Type LOT EMW 12.1 ppg target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on 2068' MD of annulus in the permafrost @ 250% excess and 937'MD of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOG: To surface Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At -2385' MD (2210' TVD). Total Cement Volume: Lead 349 bbl I 1963 ft;j I 442 sks of Dowell ARTIGSET Lite at 10.7 ppg and 4.44 disk. Tail 50.8 bbl I 285.5 fe I 244 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 disk. Casinq Size 17" Production string I Basis: Lead: Based on TOG 1000' above top of M sand & 30% excess + 80' shoe. Lead TOG: 3297' MD, 3014' TVDbkb Total Cement Volume: Lead 69.8 bbls I 392 fe I 164 sks of Dowell Premium 'G' at 12.0 ppg and 2.39 disk. Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blindlshear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGGG. Production Interval- · Maximum anticipated BHP: 2200 psi @ 4383' TVDss - Obf Sands V-201 Permit to Drill Page 3 · Maximum surface pressure: 1720 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3500 psi (for future frac stimulation treatments) 8.6 ppg filtered seawater with 2% KCU 6.8 ppg Diesel Disposal: · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at 08-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. V-201 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor, 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12.25" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3005' MD 12744' TVD. Ssurface hole TD will be +1-100' TVD below the top of the SV1 sand. 4. POH LD BHA. 5. Run and cement the 9.625", 40# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 6. ND diverter spool and NU casing 1 tubing head. 7. NU BOPE and test to 3500 psi. 8. MU 8-3/4" drilling assembly with MWD/GR/RES and RIH to float collar. Test the 9.625" casing to 3500 psi for 30 minutes. 9. Drill out shoe joints and displace well to Baradrill drilling fluid. 10. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 11. Drill ahead to -150' of rat hole into the Coleville formation. 12. Condition hole for logging and POOH. Make wiper trip as dictated by hole conditions. 13. Perform open hole logging program. 14. Condition hole for liner and POOH. 15. Run and cement the 7" production casing as required from TD to 1000' above the M sand. Displace the casing with seawater during cementing operations and freeze protect the 7" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7" shoe. Record on chart and submit to town.) 16. Test the casing to 3500 psi for 30 min. 17. Run 3-1/2",12.6# L-80 BTC Mod completion string. 18. Set packer and test the tubing to 5000 psi and annulus to 3500 psi for 30 minutes. 19. Install TWC and test from below to 2900 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 20. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to top gas lift mandrel. 21. Allow diesel to U-tube from annulus to tubing and equalize at -3500' TVD 22. Install BPV. Rig down and move off. Estimated Spud Date: 12-1-2001 V-201 Permit to Drill Page 5 V-201 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies .,. V-Pad is not designated as an H2S site. In V-100 on this pad there was no report H2S as being present. As a pre-caution, follow at all time the Standard Operating Procedures for H2S. .,. The closest surface location is V-100. V-100 will be -220' wellhead to wellhead from the proposed well location. The well does not require a surface shut-in. Reference RPs .:. Operational Specifics . ~_.- . - . -.....----.-..--....----......----.---.--.-------.--. - Job 2: DrillinQ Surface Hole Hazards and Contingencies ,. In this interval, no faults should be penetrated. .,. A surface gyro will be required while drilling the surface hole. All wells pass major risk criteria. .,. There has been consistent observation of gas hydrates while drilling wells off this pad. Expect to encounter hydrates from the base of permafrost to the shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation r Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs .:. Operational Specifics . . ..................-_ '.....-v..,.... ...~.........,'_"'~" ."" -. ..~ -õ'_' ... ?. ..... "'11'_-_............ ....._........._....... ......-...-.,.~ ~.......- ....,..... .. . . ............y....Y'I ............ ............... .... "... ................ ~.... ..,.........._,.._ .....,..._.._¡.P.".. ~........ .c ...,... ................,.........~~..- '.~'''',_""""", ..,. ........ . _. .... .................__ .....~~..'I-.. _ ........._... .. ......-_.... .. .nW......... Job 3: Install surface Casinq Hazards and Contingencies .,. It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 9-5/8" port collar will be positioned at ±1 OOO'MD to allow a secondary circulation as required. Reference RPs .:. V-201 Permit to Drill Page 6 Operational Specifics . Job 7: Drillina Production Hole Hazards and Contingencies ,. KICK TOLERANCE: In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.9 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25.5 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.9 ppg. , A fault is expected to be penetrated by V-201 at the UNGU/Mb1 interval at -4400' TVDss. The throw is -80-120' down to the Southwest. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. Reference RPs .:. Operational Specifics . ...-...-.-------.-...........-.-......--.....--.. -..-----"-.-...- - ...-........-------.....-.--..-.........-...--.......,...-......,........--............-.. Job 8: Loq Production Hole Hazards and Contingencies ;... Ensure the hole is in very good condition to avoid a stuck tool string ,.. If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs .:. Operational Specifics . ...-__......_... .._.....___ ..- ... .._............"...~~-..... ... ............ .._..__..._.___.........._,........................ ...._...~.........._____...--.____... ,,,,,_._ _...... .__._... ...........-...___...-.....___..__ ....._. ___ ._"'._.. ...,.............-_.1.............. ................._....._ _........._.........'......"...c~.,. _~_vOo... Job 9: Case & Cement Production Hole Hazards and Contingencies ,. The 7" casing will be cemented to 1000' above the M sand, the upper most hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. ,. If losses are encountered while running the production casing, be prepared to treat with barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. ,. After freeze protecting the 7" casing annulus to 2744' with 116 bbls of dead crude, the hydrostatic pressure will be assuming a diesel column to surface casing point at 2744' TVD, with 12.0 ppg cement above the top of M sand at 3016' TVD and 10.6 ppg mud to 2744' TVD, the hydrostatic pressure will be equivalent to 8.9 ppg or 2254 psi. (This is nearly equivalent the reservoir pressure of 2200 psi at top of Obf formation) It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) .,. The well will be under-balanced after displacing the cement with sea water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. V-201 Permit to Drill Page 7 Reference RPs .:. Operational Specifics · Job 12: Run Completion Hazards and Contingencies ,. No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics · Job 13: ND/NU/Release Ria Hazards and Contingencies ,. No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics · _........ ._.._....._.....~~ _. _~...._.,___,__...............-_ _"......__~_...-______....__.__.___.._...____.....-. - -..-"' ..... _ ....._............. -..Þ_ _··__.'.__"'"~"''''''''_~·___'__''''''''''..''_~____~..__.''_n,~__..ao.. V-201 Permit to Drill Page 8 V-201 Well Summary of Drillin~ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in offset wells. These are expected to be encountered near the base of the Permafrost at 2068' MD and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.9 ppg at the surface casing shoe, 9.1 ppg mud in the hole, kick tolerance is 25.5 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.9 ppg. · A fault is expected to be penetrated by L-106 in the base of the UGNU/Mb1 transition at -4400' TVDss. The throw is -75' down to the west. There is not a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. · Borealis development drilling may have "kick tolerances" in the 25 bbl range or less. At least 100' prior to entering the Nb formation, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells drilled on L-pad did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page I of 1 TREE: 4-1f16"· 5M FMC Carbon WELLHEAD: 11" - 5M FMC Ullr3 SH GenS 9-5/8" TAM Port Collar 9-5/8...., 40 #/ft, L-80, M-BTC 13005' 7",26 #/ft, L80, BTC-Mod - I 5214' I ~ ~ , V-201 Proposed Completion [ j I . Ground Elevation = 55' Nabors 9ES Floor = 83.5' ] 3-1/2" X Nipple with 2.913" 10. ~ 4 - 31/2" Cameo Gas Lift Mandrel. ------- -- -- - ----- --- --- -- ---------- -------- -li- TVD~S:~IFT M~~:EL~- V~~;Typ~-1 1------ ----i----------- 1 i __lJ TBD TBD TBD L L 1 .-.-- -_._--- ------ ------ 3-1/2" 12.6# L-80 Tubing o ----- 3-1/2" Baker CM Sliding Sleeve - 7" x 4-1/2" Baker 'Premier Packer. 3-1/2" HES 'X' Nipple with 2.813"10. 3-1/2" HES X Nipple with 2.813" 10 \ 3-112· W"eL"e Entry Gu;de ~ Date Rev By Comments RSO Proposed Completion WELL: V-201 API NO: 50-029-XXXXX BP Exploration Afaska - 11/15/2001 - . 41:. ~III!IMltI!l!! V-201 Schlumberger Proposed Well Profile - Geodetic Report Report Date: October 31, 2001 Client: Alaska Drilling & Wells Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure I Slot: V-Pad / V-201 Well: V-201 Borehole: V-201 UWI/API.: 50029 Survey Name I Date: V-201 (P4) I October 31,2001 Tort I AHD I DDII ERD ratlo:80.427° /1706.82 ft 15.1711 0.353 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Location Lat/Long: N 70.32801002, W 149.26582521 Location Grid N/E YIX: N 5970085.400 ftUS, E 590526.000 ftUS Grid Convergence Angle: +0.69132914° Grid Scale Factor: 0.99990931 Survey I DLS Computation Method:Minimum Curvature I Lubinski Vertical Section Azlmuth:344.190° On Iy Vertical Section Origin: N 0.000 ft, E 0.000 ft III study TVD Reference Datum: KB F Iì1II bill I Ity TYO Reference Elevation: 83.5 ft relative to MSL eas Sea Bed I Ground Level Elevatlon55.000 ft relative to MSL Magnetic Declination: 26.184° Total Field Strength: 57469.674 nT Magnetic Dip: 80.751 ° Declination Date: December 15, 2001 Magnetic Declination Model:BGGM 2001 North Reference: True North Total Corr Mag North -> True North:.-26.184 ° Local Coordinates Referenced To:Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azlm TVD VSec NJ·S EI·W DLS Northing I Eastlng Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) KBE 0.00 0.00 313.54 0.00 0.00 0.00 0.00 0.00 5970085.40 590526.00 N 70.32801002 W 149.26582521 KOP Bid 1/100 300.00 0.00 313.54 300.00 0.00 0.00 0.00 0.00 5970085.40 590526.00 N 70.32801002 W 149.26582521 400.00 1.00 313.54 399.99 0.75 0.60 -0.63 1.00 5970085.99 590525.36 N 70.32801166 W 149.26583032 500.00 2.00 313.54 499.96 3.00 2.40 -2.53 1.00 5970087.77 590523.44 N 70.32801657 W 149.26584573 Bid 2/100 600.00 3.00 313.54 599.86 6.76 5.41 -5.69 1.00 5970090.74 590520.25 N 70.32802480 W 149.26587135 700.00 5.00 313.54 699.61 12.76 10.21 -10.75 2.00 5970095.48 590515.13 N 70.32803791 W 149.26591239 800.00 7.00 313.54 799.06 21.75 17.42 -18.32 2.00 5970102.60 590507.47 N 70.32805761 W 149.26597377 900.00 9.00 313.54 898.08 33.72 27.00 -28.41 2.00 5970112.05 590497.27 N 70.32808378 W 149.26605559 1000.00 11.00 313.54 996.56 48.66 38.97 -41.00 2.00 5970123.87 590484.54 N 70.32811648 W 149.26615769 1100.00 13.00 313.54 1094.37 66.55 53.29 -56.07 2.00 5970138.00 590469.30 N 70.32815560 W 149.26627989 1200.00 15.00 313.54 1191.39 87.36 69.95 -73.60 2.00 5970154.45 590451.57 N 70.32820111 W 149.26642205 1300.00 17.00 313.54 1287.51 111.07 88.94 -93.58 2.00 5970173.20 590431.36 N 70.32825299 W 149.26658407 1400.00 19.00 313.54 1382.62 137.66 110.23 -115.98 2.00 5970194.21 590408.71 N 70.32831115 W 149.26676572 1500.00 21.00 313.54 1476.58 167.08 133.79 -140.77 2.00 5970217.47 590383.64 N 70.32837552 W 149.26696675 1600.00 23.00 313.54 1569.29 199.31 159.60 -167.92 2.00 5970242.95 590356.18 N 70.32844603 W 149.26718692 1700.00 25.00 313.54 1660.64 234.30 187.61 -197.40 2.00 5970270.60 590326.37 N 70.32852254 W 149.26742599 1800.00 27.00 313.54 1750.52 272.01 217.81 -229.17 2.00 5970300.41 590294.24 N 70.32860505 W 149.26768363 1900.00 29.00 313.54 1838.81 312.40 250.15 -263.20 2.00 5970332.33 590259.83 N 70.32869339 W 149.26795960 V-201 (P4) report. xIs Page 1 of 3 10/31/2001-5:26 PM Grid Coordinates Geographic Coordinate. (' Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing I Ea.Ung Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (01100tt) (ftUS) (ftUS) 2000.00 31.00 313.54 1925.41 355.41 284.60 -299.44 2.00 5970366.34 590223.18 N 70.32878750 W 149.26825349' End Bid 2038.77 31.78 313.54 1958.50 372.78 298.51 -314.08 2.00 5970380.07 590208.37 N 70.32882550 W 149.26837222 Base Permafrost 2068.17 31.78 313.54 1983.50 386.11 309.18 -325.30 0.00 5970390.60 590197.02 N 70.32885465 W 149.26846321 Bid 2/100 2097.58 31.78 313.54 2008.50 399.43 319.84 -336.53 0.00 5970401.13 590185.67 N 70.32888377 W 149.26855428 2100.00 31.82 313.54 2010.56 400.53 320.72 -337.45 2.00 5970402.00 590184.74 N 70.32888618 W 149.26856175 Bid 3/100 2147.58 32.78 313.54 2050.77 422.40 338.24 -355.88 2.00 5970419.29 590166.10 N 70.32893404 W 149.26871121 Bid 4/100 2197.58 34.28 313.54 2092.45 446.16 357.26 -375.90 3.00 5970438.07 590145.85 N 70.32898599 W 149.26887357 2200.00 34.37 313.54 2094.45 447.33 358.20 -376.88 4.00 5970438.99 590144.86 N 70.32898856 W 149.26888152 SV3 2272.84 37.29 313.54 2153.50 484.01 387.57 -407.79 4.00 5970467.99 590113.60 N 70.32906879 W 149.26913219 End Bid 2297.10 38.26 313.54 2172.68 496.80 397.81 -418.56 4.00 5970478.09 590102.71 N 70.32909677 W 149.26921954 Cry 5/100 2736.23 38.26 313.54 2517.51 730.72 585.12 -615.64 0.00 5970663.00 589903.40 N 70.32960845 W 149.27081789 2800.00 35.47 316.14 2568.52 764.04 612.07 -642.78 5.00 5970689.61 589875.94 N 70.32968206 W 149.27103801 2900.00 31.24 321.00 2652.04 813.52 653.17 -679.23 5.00 5970730.27 589839.00 N 70.32979434 W 149.27133364 SV1 2901.70 31.17 321.09 2653.50 814.33 653.86 -679.78 5.00 5970730.95 589838.44 N 70.32979622 W 149.27133810 3000.00 27.24 327.16 2739.30 859.27 692.58 -707.98 5.00 5970769.32 589809.78 N 70.32990199 W 149.27156682 9-5/8" Csg Pt 3004.72 27.06 327.49 2743.50 861.33 694.39 -709.15 5.00 5970771.12 589808.59 N 70.32990694 W 149.27157631 3100.00 23.60 335.15 2829.63 900.95 730.00 -728.82 5.00 5970806.49 589788.49 N 70.33000422 W 149.27173586 3200.00 20.49 345.63 2922.35 938.24 765.14 -741.58 5.00 5970841.4 7 589775.31 N 70.33010021 W 149.27183937 UG4 3217.22 20.03 347.73 2938.50 944.20 770.94 -742.96 5.00 5970847.25 589773.86 N 70.33011606 W 149.27185057 UG4A 3249.07 19.25 351.86 2968.50 954.85 781.47 -744.86 5.00 5970857.75 589771.84 N 70.33014482 W 149.27186599 3300.00 18.21 359.10 3016.74 970.86 797.74 -746.18 5.00 5970874.01 589770.32 N 70.33018927 W 149.27187670 3400.00 17.08 15.23 3112.09 998.55 827.55 -742.56 5.00 5970903.85 589773.58 N 70.33027071 W 149.27184737 3500.00 17.33 32.17 3207.68 1021. 11 854.34 -730.77 5.00 5970930.78 589785.04 N 70.33034390 W 149.27175177 UG3 3579.64 18.49 44.59 3283.49 1035.30 873.38 -715.58 5.00 5970950.00 589800.00 N 70.33039592 W 149.27162860 End Cry I UG3 Tgt 3579.65 18.49 44.59 3283.50 1035.30 873.38 -715.58 5.00 5970950.00 589800.00 N 70.33039592 W 149.27162860 Ma 4296.66 18.49 44.59 3963.50 1147.60 1035.30 -555.97 0.00 5971113.82 589957.63 N 70.33083831 W 149.27033425 Mc 4433.73 18.49 44.59 4093.50 1169.07 1066.25 -525.45 0.00 5971145.13 589987.77 N 70.33092287 W 149.27008674 .. Nb 4539.18 18.49 44.59 4193.50 1185.59 1090.06 -501.98 0.00 5971169.22 590010.95 N 70.33098792 W 149.26989641 OA 4739.50 18.49 44.59 4383.49 1216.97 1135.30 -457.38 0.00 5971214.99 590055.00 N 70.33111152 W 149.26953471 Target 4739.51 18.49 44.59 4383.50 1216.97 1135.31 -457.38 0.00 5971215.00 590055.00 N 70.33111155 W 149.26953471 OBa 4792.24 18.49 44.59 4433.50 1225.23 1147.21 -445.64 0.00 5971227.04 590066.59 N 70.33114406 W 149.26943950 OBb 4834.41 18.49 44.59 4473.50 1231.83 1156.74 -436.25 0.00 5971236.69 590075.87 N 70.33117010 W 149.26936335 OBc 4897.68 18.49 44.59 4533.50 1241.74 1171.02 -422.17 0.00 5971251.13 590089.77 N 70.33120911 W 149.26924917 OBd 4950.40 18.49 44.59 4583.50 1250.00 1182.93 -410.43 0.00 5971263.18 590101.37 N 70.33124165 W 149.26915395 OBe 5018.94 18.49 44.59 4648.50 1260.74 1198.41 -395.18 0.00 5971278.84 590116.43 N 70.33128394 W 149.26903028 V-201 (P4) report.xls Page 2 of 3 10/31/2001-5:26 PM Grid Coordinates Geographic Coordinates I Station ID MD Incl Azlm TVD VSec NJ·S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°11 o Oft) (ftUS) (ftUS) OBr 5055.84 18.49 44.59 4683.50 1266.52 1206.74 -386.96 0.00 5971287.27 590124.55 N 70.33130670 W 149.26896361 TD I 7" Csg Pt 5214.00 18.49 44.59 4833.50 1291.29 1242.46 -351.75 0.00 5971323.41 590159.32 N 70.33140429 W 149.26867806 Le~al Description: Surface: 4838 FSL 1775 FEL S 11 T11 N R 11 E UM End Cry I UG3 Tgt: 431 FSL 2490 FEL S2 T11 N R11 E UM Target: 693 FSL 2231 FEL S2 T11 N R11 E UM BHL: 801 FSL 2125 FEL S2 T11 N R11 E UM Northinq ey) rftUSl 5970085.40 5970950.00 5971215.00 5971323.41 Eastin~ eX) rftUSl 590526.00 589800.00 590055.00 590159.32 V-201 (P4) report.xls Page 3 of 3 10/31/2001-5:26 PM ]£ 11." -1000 - 0- 1000 - - ..... Q) - Q).....J .....Cf) g~ o Q) T""" > II .8 c:: CO T"""¢:: _0 ..c::~ ë.~ Q) - oca Cã~ uo.+..-: t: Q) Q)e:: > > Q)~ ::JW ¡:: 2000 - 3000 - 4000 - 5000 - 6000 - " , I ~ I .' .¡ I ,I II I . ~I'" ...' ." ' ,.:.. ,I :.' ¡"I I ,I~I j í,~ - :' 1,~' ~ i:; ':( :.,I~J " I: " '·r,' : >J ! : I' . ~,' I -1000 -1 ~RTICAL SECTION VIEW Client.: ~laska Drilling & Wells \.'-201 \ p.,¡ Prudhoe Bay Unlt. - WOA V-Pad 3 H . 19 deg October 31, 20ùl Schlumbepger I 3000 Vertical Section Departure at 344.19 deg from (0.0, 0.0). (1 in = 1000 feet) ¡'Ie 11 : Field: Struct.ure: Sect.ion .;t.: Date: I ., .. '{- - KOP,Bld1f100JL"Jr.'D 3wT',D 0('11)' 31:,S,J'ðZ ')üf.!iPðrrure )' ---'--- ~~~(I~'~~Jõ~~.r~~ 76~~p:;·I~rB End Bid 2U:\(.. MD 1':1::':' T'.'D 31 ;r8~ 31 3 ~.J. d..::' 37'3 dð~ø"urf.t Bid 2/100 ~ú':1& T.~D :-0(":' riD I )1 ,~: jn !'J: d~ ~~5":lo)¡:'øl"u,re BldJ/1002IJ¡;I.!D ;,,~!T¡D :\l7ð- j 1 ~ ~,J.' dZ J:t~ cJBPø~UI'B Bid 41100;: lSiB r.'D ~r:,ç.2 T\'D 'jJ ~8' ')13 'SJ~ Li.:!: .U6·':IBP.JrTUfe End Bid ;:~:9'! f.1D ~ 1-::' f\,D )8 ~t.. )1 j ~J,' LI.!. JÇl7 ü~j.:.rlure , ~. : ,-1 1"\ \ '-<" ' y ~ .'., \/,_~OI~~~:~,:;,~8,;~;~~.. '\ \ ' ,- 9-S'S"' Cog PI ! \\~ -- ":";51.11) ¿~JJT.D f) \ ¿I ':',;' j¿~ J~' dZ ~t I "~¡:.ar'uI8 End Cry / UGJ Tgl )'5,';0 r.'D J~¡;'.J P. Ù I¡;'J~· JJ,:~·.:az Illj:) ':1ð~I';'l1u;~ ,. "', ' Hold Angle 18.49° Targal ..1";'4(1 r.ID .,n6J T" D '~.J~' ¡.1J ~9: I;'! ,~ l' a~ar1ure j\h TD / T" Cog PI ~,¿ IJ I,'D Jr;)J T'. D 18.JÇt' JJ =,.;.: èll I ~,~ I 1];"¡:'drTur~ i o I 1000 I 2000 ]£ I.. 1200 - 1000 - ^ ^ ^ I I- 800- 0::: o Z 600- I I- ::> o C/) V V V 400- 200- 0- ~ PLAN VIEW Client: ~'Jell : field: Structure: Scale: Alaska Drilling & Wells 'J - ? (I 1 ( P -I ) Prudhoe Bay Unic - WOA V-Pad 1 in = 200 ft. 31- ûc c <: 0 0 1 Da t. e : -800 I -400 I -200 Bid J'100 ... ./1JF,¡rJD J,j~,1T\'D "" >:7~ '1J;~.: , ~ >;ð~1 >'¡0:,1I\I "-_------ ~~::;~~O ",j,,~ rvD -600 I ~~ /)- ~. § :P è~.p~ /' f-------- End Cry I UCJ Tgt )~tI(, MD )~ðJ T'/D '&rJ.~i· JrJ ~St I;'Z ~7) 1\1 ";' 1E, \IV 9-5/B'" Cog Pt jùu~ p.'D ,¿",J,J T'. ù ~:'.'JÓ ¿¡¿,:' .1.;.' .:1';: l";yJ 1\1 7ùÇJI/IJ Cry 5/100 27jt.MD ~-:'I¡jï\'D' j¡;~6· ~1~~·J·d';: 5&5 N ~ 1.;' W End Bid ';'':.;.;' ~.'D ~';'j r...û ~ð':'t.: :'1)~J:ill ~\'~Elr~ J1c;.W ~/, (7 ~h;. "0 .)7 ~8.: VO I -800 I -600 «< WEST I -400 TO /1" Cog PI '¡JI~MD ~iI:"¡T\'D 1& 4ÇJI 4J ~~. U '2~2 tl ;'~2 W Targlt J7Ju '.'D J ~13.1 TvD 1E1Jc;;,' JJ ~'1. iJl 11~-:' N Joj7 V\t True North Hag Deç ( E 2 6 . 1 8 :' ~ ',--.-,,' Bid 4/100 -': I ~ð r.'D 20~-4~ I'VD >~ :'. 313 S~· ~, j57 t.,¡ j"'i W j17& j1? 5.1:.:..: j::(d\~ jj;r \Iv - ~ End Bid ,¿ü? ~ MD ';'~ ~ r,.'o 31.78 JO~J a: ~.;.~ 1"1 )1.1W , Bid 21100 : iljO UD 60(1 T'. D - .-- - ..j ~~~:"6~):J~a~ I KOP Bid 1'100 )(11) f.'D )(1(1 ï\ CI (I lXI' jlj~,J,·';'';: (I CI rJE I -200 EAST »> Schlumberger o I - 1200 - 1000 -800 -600 -400 -200 -0 I o Schlumberger Anticollision Report __0.- _____ - - - - __ ___ ___ ___n___ ___ ___ .__ _ ___ _ _. _ ___ _ _ _____ n_ ___ _ _____ --~- -- I Company: ' Field: I Reference Site: I Reference Well: I Reference Well path: BP Amoco Prudhoe Bay PB V Pad Co-ordinate(NE) Reference: Well: V-201, True North V-201 Vertical (TVD) Reference: V-201 plan 83.5 Plan V-201 Db: Sybase ------ ---.-----------.- -. -. -- -- ----.-- ..------.---. - --- ---- --- -.. . ---.- -- - ----- - ---- - . - -----_. --- -_._--------- ------- NO GLOBAL SCAN: lIsing user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM I I Interpolation !\Icthod: MD Intenal: 100.00 ft Error !\Iodel: ISCWSA Ellipse Depth Range: 28.50 to 5214.00 ft Scan !\Iethod: Trav Cylinder North I\la:\imum Radius: 1200.00 ft Error Surface: Ellipse + Casing - -._--_. -- ------".- --.---- ----. ------ -------- ---- - -- ----- ----.-----..-----.-------.--------- Date: 10/31/2001 Time: 17:22:19 Page: ---------- ..--.------ --.- ---- _.. -------------------. -----.------------------.------------ Sun'c) Program for DefinitÏ1,e Well path Date: 8/23/2001 Validated: No Planned from To Sun'e)' ft ft --.------ --- 28.50 5214.00 Version: T oolcode 6 Tool Name Planned: Plan #4 V1 MWD - ------ ----,--- ____ ___.._ _I MWD - Standard I ----_ - ..__ ___ _J -.--- ----- ----- ------~- ---------------- ..---- - - -- -- - -- _. -------------------.- Casing Points !-~rn·----TVD-----·· -Öia;;;;;----H~;_si;_--- - -N~;~------ ----------- ft ft in in -"-- -----------_.-- -- ,---..---------------- 3004.76 2743.50 9.625 12.250 5214.00 4833.43 7.000 8.500 ---------- ------- - ---_._------ - -- -..----------- ------- =--=-~:_-~-~=-~ - ---=-~~ _J ---.-- ---------- -------- -- 95/8" 7" Summar)' -------- - ---- --- -- --- - --------- -------- -- ------. -- -. - -_. -- --. -- --"- ---- ------- --- ----- ----- ---------.--- ----------. : <---------------- Offset Wellpath ---------------> Reference Offset err-Ctr No-Go ..\.110\\0 able Site Well Well path 1\10 1\10 Distance Area Deviation Warning ft ft ft ft ft --- .-.. - - - - -- - . - ._-- . . - ". - - -..-- - .---.-- ---- - ..------.- --- .. - - .-.. ---------. -.--.------..----.- -- --- .----.------ --. - .- -...-- . PB V Pad V -100 V-100 V7 300.00 300.00 273.20 5.02 268.18 Pass: Major Risk - --- ---- - - -- -- -.---- -----. ------- -- -- ---. .---.------ ----.--- ----------- Site: PB V Pad Well: V-100 Rule "\s~igned: Major Risk Wellpath: V-100 V7 Inter-Site Error: 0.00 rt --.---- --- - .....-. --.--- - -.. ----- ----------..----- ------ - ---.--- - -- . -- - -. - -. --.------ - --- .-- .----.. ._. - -. - -- ------- - - ----- - _. --. . --. -.-- , - Rcference Offset Semi-l\lajor Axis Or-Ctr No-Go Allowable I\ID T\"D 1\10 TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft --- 28.50 28.50 28.40 28.40 0.00 0.00 117.04 117.04 9.625 272.69 0.91 271.78 Pass 100.00 100.00 100.00 100.00 0.04 0.05 117.05 117.05 9.625 272.70 1.90 270.80 Pass 200.00 200.00 200.00 200.00 0.15 0.13 117.11 117.11 9.625 272.69 3.46 269.23 Pass 300.00 300.00 300.00 300.00 0.26 0.20 117.26 117.26 9.625 273.20 5.02 268.18 Pass 395.58 395.58 400.00 399.99 0.37 0.24 117.51 163.97 9.625 274.83 6.42 268.41 Pass 491.09 491.05 500.00 499.98 0.48 0.30 117.89 164.35 9.625 277.95 7.87 270.07 Pass 586.45 586.33 600.00 599.97 0.60 0.31 118.34 164.80 9625 282.80 9.19 273.61 Pass 678.00 677.69 700.00 699.96 0.71 0.28 118.88 165.34 9.625 289.58 10.32 279.27 Pass 768.46 767.74 800.00 799.96 0.85 0.24 119.50 165.96 9.625 299.36 11 .45 287.97 Pass 858.26 856.81 900.00 899.95 1.01 0.23 120.16 166.62 9.625 312.26 12.71 299.68 Pass 947.21 944.65 1000.00 999.95 1.20 0.26 120.88 167.34 9.625 328.21 14.24 314.32 Pass 1035.22 1031.09 1100.00 1099.95 1.43 0.28 121.64 168. 1 0 9.625 346.88 15.75 331.75 Pass 1122.13 1115.92 1200.00 1199.95 1.69 0.31 122.35 168.81 9.625 368.47 17.42 352.05 Pass 1207.77 1198.89 1300.00 1299.95 1.98 0.37 123.07 169.53 9.625 393.06 19.39 375.27 Pass 1292.01 1279.87 1400.00 1399.94 2.31 0.42 123.83 170.29 9.625 420.50 21.38 401.37 Pass 1374.78 1358.74 1500.00 1499.94 2.68 0.45 124.62 171.08 9.625 450.56 23.36 430.18 Pass 1455.87 1435.26 1599.92 1599.85 3.07 0.49 125.37 171.83 9.625 483.43 25.49 461.77 Pass 1535.46 1509.61 1700.00 1699.92 3.50 0.52 126.10 172.56 9.625 518.87 27.62 495.99 Pass 1613.33 1581.55 1800.00 1799.91 3.94 0.55 126.76 173.22 9.625 556.68 29.83 532.59 Pass 1689.48 1651.10 1900.00 1899.90 4.41 0.58 127.36 173.82 9.625 596.86 32.01 571.57 Pass 1763.84 1718.19 2000.00 1999.89 4.91 0.63 127.91 174.37 8.625 639.38 34.43 612.88 Pass 1836.47 1782.91 2100.00 2099.86 5.42 0.68 128.44 174.90 9.625 683.90 36.95 656.18 Pass 1900.00 1838.81 2200.00 2199.84 5.89 0.70 128.90 175.36 9.625 730.35 39.13 701.61 Pass 1976.56 1905.27 2300.00 2299.82 6.49 0.76 129.32 175.78 9.625 778.78 41.86 748.72 Pass 2045.23 1963.99 2400.00 2399.80 7.05 0.81 129.71 176.17 9.625 829.34 44.54 798.10 Pass 2123.10 2030.13 2500.00 2499.77 7.71 0.83 130.05 176.51 9.625 880.78 47.46 848.22 Pass 2183.08 2080.43 2600.00 2599.75 8.24 0.87 130.36 176.82 9.625 933.87 49.78 900.30 Pass 2234.17 2122.42 2700.00 2699.72 8.72 0.89 130.63 177.09 9.625 989.54 51.79 955.17 Pass 2297.10 2172 67 2800.00 2799.70 9.33 0.92 130.91 177.37 7.000 1048.47 54.01 1013.19 Pass 2348.21 221280 2900.00 2899.66 9.85 0.94 131.17 177.63 7.000 1110.17 56.22 1073.98 Pass ---- -- --- --.- --------- -. - - .-- -.---- --- '- .--------.- -.-- '---'-"'- -...--.-.-- ._-. .. --- - --. .'-' Target: \'-201 TapO:-\. Polygon I Sll~ PH \' Pad Drlllmg T3rg~! ConI 99°0 'I C~ntTe Locallon: r-.1ap Northmg· 5971215 00 tì r-.1ap Easllng : 590055.00 f1 LatUude. hi'" ¡9'S::! 002N -t-N/-S ft -75.12 150.73 217.95 -2.90 -t-E -w Ii 9.09 -58.19 172.67 240.00 \\' 'I. \'-2(11 ~ ,lm Planned Program \'~r!Ical D~p!h 4300.00 f1 below r-.kan S~a Le\d Local +N,-S: 1135.32 ft Local +E:-\\-': -t57.34 ft Longitude· 149~16'10.315\V Northing ft 5971140.00 5971365.00 5971435.00 5971215,00 Easting tì 590065.00 589995 00 59022501 590195.00 2 3 ..J --.---.--- --------- - ---------- I EJO ISCJ I 4- r= --- J I'"'] 0~ 120 I I '"' --- -- I ,J .---- .-- ,- ...--- ...-- --'- --- I IJIJ (1 I :=J CJ I ~I ( ) LJ C=J ,--' 0 ¡1 ~ I I .------- I I .-----.. C=I l ì I '--' '---' ,---. I '1 [) III Lr--) --3- I,~Y) c-''',-I [, I I I I I ¡] ,1 r, Schlumberger Anticollision Report ------ ---------------~ -- -- ---- ------ ------.------ ...- - ---------- '--'-!, Page: 2 Company: BP Amoco Field: Prudhoe Bay Reference Site: PB V Pad i Reference Well: V-201 ;_Refe~n~~_~~~~~h~~~_n V-201 Site: PB V Pad Well: V-100 Wellpath: V-100 V7 10/31/2001 Time: 17:22:19 Date: Co-ordinate(NE) Reference: Well: V-201, True North Vertical (TV D) Reference: V-201 plan 83.5 I ,____ _'u,____________ _,..._______ _,__u, _...,_.._...___n__ ___m__ ____ ___~b:__ ~~~_~~_j Major Risk 0.00 ft Allowable Deviation Warning ft Rule Assigned: Intt'r-Site Error: ---- -¡ , I I I I Reference i\1D T\'D ft ft Offset 1\10 T\1) ft ft Semi-Major Ads Rt'f Offset TFO+AZI TFO-HS Casing ft ft deg deg in Ctr-Ctr No-Go Distance Area ft ft I ¡--...--...---- I 2424.09 .. --------- _ _h__.__________. ___________._. ______ __________ _ --- ----- ---- -- --"--- - ---" - ----" -- _. -- ---- - ---.---. 2272.38 3000.00 2999.46 10.62 095 131.09 177.55 7.000 117523 59.35 1137.73 Pass ------------------- ----_----! ------"- 198742 OATE 09/28/01 CHECK NO. 00198742 )ATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENOOR ALASKAO I LA DISCOUNT NET 00 ?2701 CK092701 F JYMT COMMENTS: -iANDL I NG I NST: 100.00 100.00 H_ Pernit to Drill ~ee S/H - Terri Hubble X4628 y\)Dl TTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 198742 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00198742 lAY ONE HUNDRED ~ 00/100************************************* US DOLLAR DATE 09/28/01 AMOUNT $100_00 ro The JRDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 NOT VALID AFTER 120 DAYS n n /1..';.:, <I ;' I \ <. ~ ~'i . ~(".~/~ III . Ii B ?... 2/11 I: 0'" . 2 0 ~ 8 ~ 5 I: 0 0 8 ~ ~ . ~ III ... - - - -- ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIER/PARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER // ~ / WELL NAME /~6¿ { V ~ 2C;! I CHECK 1 STANDARD LETTER DEVELOPMENT CHECK \VHAT APPLIES ADD-ONS (OPT]ONS) MULT] LATERAL (If api number last two (2) digits are between 60-69) \1 DEVELOPMENT REDRlLL PILOT HOLE (PH) EXPLORA TION ANNULAR D]SPOSAL l.J.ÓNO INJECTION 'VELL ANNULAR DISPOSAL <.---> YES INJECTION \\'ELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well -' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. ]n accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and AP] number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <.---> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the appro\'ed application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. j/Æ( _ WELL PERMIT CHECKLIST COMPANY AI...."" WELL NAME ,/- 21.'/ PROGRAM: exp _ dev ~ redrll_ serv _ well bore seg _ann. disposal para req_ FIELD & POOL (:, Lj{)~ /ðf)lNIT CLASS ~/=-\/ j r: I L GEOL AREA A1z,,: UNIT# t:,')//t~ Ç-C' ON/OFF SHORE C)/7 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellböre plat induded.. . . . . . . . . . . . . . 9. Operator onty affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . AP~R_~ DATE 12. Permit can be issued without administrative approval.. . . . . _ -6_~ If. Z<-~, . C;f 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C. T. B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations . . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation . . . . . . . . . ~ . . . . 26. BOPE press rating appropriate; test to ~:}ÙV psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H:25 gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . (ý- ~ N 31. Data presented on potential overpressure zones . . . . . . . --y;; N 32. Seismic anal~~is of shallow gas zones. . . . . . . . . . . .. ~ /'( N APP-R DATE 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . _.;J Y N .ft /1, ZL O',uf 34. Contact name/phone for weekly progress reports [exploratprý only] Y N ANNULAR DISPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOL2~Y: ENGINEERING: UIC/Annular COMMISSION: ~þ~~ ~~ WM~ 8~s /!/Pc.' 'Æ rEM 1~1)n l~Ò JMH YfL1/t' /I /3(..'/D I ENGINEERING IffSrt eJ\TE (~Ù GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ZJ ~~ y~ ~ ~ b.\"'~"'~ ~\~ \ '"'-~ WS'<.Nt 0 N ~~ t~"" C',"~~~ \ð((~-\\<,~ N N N '\ NV\~~\> «- ~-\-Q 'ì.)~ ~c:; \ N Y~ (Y)N Gl.,N (.::L-,Ij:l Y,-(~) Y'N ,1 N Y)N N N N N N N Y N Y N ¿/::' I ~L.I_ 4'tl.-,-/ S h~ 11,:,- t¿.A- d<.+, IL¿~¡;'~I c o z o -I :E :::c -I m '> <;(Ja~.ç \ c CJ. c;. h. \ ~\- ~ \,," '"'~ Z -I :I: en » ::0 m » t::-)c.ra..~ '/Z--r)'J'1q. / j:>~c:."~:"'t::- ~ '-""Ld,"''-'t t: /-1, 'f~/r':/~$ ~¡: ~,.h:l, ~-,J .b·i~ ¡J"-I ¡}lf~ hc.~~ t.. I /96'/" -rJ,' ,"":) It. slc....¡~- ct.:.--V/... or Z7V'I' 71.';>, oj ~ - ~ /~e. G~~>.J\o..,\)~~ \o.,,~_ / 'P\<1"~ ~~<')L\-.)~ \...öT ~~ ~~' Comments/lnstructions: