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Home My WebLink About204-041STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LOG By Samantha CIrW1 of 7.03 pm, Jun 09,2021 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned R Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 0 1b. Well Class: Development [I Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp North Slope, LLC 6. Date Comp., Susp., or Aband.: 5/23/21 14. Permit to Drill Number/Sundry 204-041 321-016 3. Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 4/5/2004 15. API Number: 50-029-23201-00-00 4a. Location of Well (Governmental Section): Surface: 4645' FSL, 1803' FEL, Sec. 11, T11 N, R11 E. UM Top of Productive Interval: 2047' FNL, 388' FWL, Sec. 13, T11 N, R11 E, UM Total Depth: 2263' FNL, 450 FWL, Sec. 13, T11 N, R11 E, UM 8. Date TD Reached: 4/13/2004 16. Well Name and Number: PBU V-119 g Ref Elevations KB 81.7 GL 53.7 BF Surface 17. Field/Pool(s): PRUDHOE BAY, BOREALIS OIL 10. Plug Back Depth(MD/TVD): Surface 18. Property Designation: ADL 0028245 0028240 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590500 y- 5969892 Zone - ASP -4 TPI: x- 592778 y- 5963226 Zone - ASP -4 Total Depth: x- 592843 y- 5963012 Zone - ASP -4 11. Total Depth (MD/TVD): 10483'/ 6867' ' 19. DNR Approval Number: 00-001 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MD/TVD: 1900' (approx.) 5. Directional or Inclination Survey: Yes ❑ (attached)No Q Submit electronic and printed information per 20 AAC 25.050 113. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 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 MIND / GR, MWD / GR / PWA, PEX-Triple Combo, BHC Sonic, USIT 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 20" 91.5# H-40 Surface 109' Surface 109' 42" 260 sx Arctic Set( Approx,) 9-5/8'. 40# L-80 Surface 3350' Surface 2725' 12-1/4" 536 sx Arctic Set Lite, 288 is Class' G' 7" 26# L-80 Surface 10475' Surface 6862' 8-3/4" 358 sx LiteCrete, 133 sx Class' G' 24. Open to production or injection? Yes ❑ No H If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number, Date Pend): Abandonment Date 5/23/2021 HEW 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# L-80 10056' 9995'/ 6568' 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 information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Surface 24 -gal 15.6-ppg HES Arctic C Cement 27, PRODUCTION TEST Date First Production: Abandoned Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period �► Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press Casinq Press: Calculated 24 Hour Rate �1 oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Sr Pet Enq Sr Pet Geo Sr Res Ena Form 10-407 Revised 3/2020 RBDMS HEW 6/10/2021 1 SFD 6/2412021 Submit within 30 days of Completion, Suspension, or Abandonment G 28. CORE DATA Conventional Core(s) Yes ❑ No 0 Sidewall Cores Yes ❑ No Q 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 10200' 6694' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 3730' 2952' Schrader Bluff N 6182' 4364' Schrader Bluff O 6471' 4531' Base Schrader Bluff/ Colville 7091' 4893' HRZ 9702' 6395' Kalubik 10073' 6615' Kuparuk C 10200' 6694' Kuparuk B 10258' 6730' Kuparuk A 10352' 6787' Formation at total depth: Kuparuk A 10352' 1 6787' 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. Stan Stan Golis (880;"y9"eaeyslencwe Oliver Sternicki Authorized Name: Contact Name: DN: —Stan core (660), ou=Users Authorized Title: Sr. Area Operations Manager oe,e 2az106,0916:0952-0e'tontact Email: Oliver.Sternicki@hilcorp.com 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 RA 1• Daily Report of Well Operations PBU V-119 ACTIVITY DATE SUMMARY ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 487. Begin 4/23/2021 excavation to —2' below pad elevation w/ jackhammers. LDFN. ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48.7'. Continue excavation with jackhammers to 4.5' below pad elevation. Uncover cutoff casing 4/24/2021 strings and float plate. Barricade excavation, LDFN. ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 487. Continue excavation around float plate. Attempt to remove float plate with excavator with no 4/28/2021 success. Plan forward is to use torch to remove float plate tomorrow. LDFN. ***P&A In Progress*** Use torch to remove float plate gussets. LDFN - crew change 4/29/2021 out. ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 487. Remove float plate. Continue excavation with 320 excavator at the front of well and 303 excavator at the back of well, reach a depth of 7' and see partial tundra line. Cover excation with 4/30/2021 rig mat. LDFN. ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48'. Continue 5/1/2021 excavation to 13' below pad elevation, 6' below tundra elevation. LDFN ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48'. Clean up sides of excavation for shoring box. Set shoring box. Move over to V-201 P&A per OPS 5/2/2021 request due to SI MOPS issue with service coil at V-117. *** P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48'. Cut cemented strings 3' 1" below Tunra elevation. T/I/O had good hard cement. Conductor x 9-5/8" casing had contaminated cement. Notified AOGCC Brian Bixby comunication the condion of the cement. He asked if we could remove cement in the contucor x casing until good and cement is found. Removed — 19 inches of contaminated cement until finding hard bottom. Performed cement top job on 20" conductor & insulated conductor with 24 gal of 15.6 ppg HES Arctic C cement. Moved to V-201 to start that 5/10/2021 cut while letting cement cure. Job In Progress. ***P&A In Progress*** Cement Top job Witnessed by Adam Earl. Welded Marker 5/19/2021 plate. Pictures sent to AOGCC Adam Earl. Will return to back fill. 5/23/2021 ***P&A Complete*** Pulled shoring box. Backfilled and delineated excavation. ` : ,,� 4 y: ' � ., r � � n. T �-� .f '� B ��.. `'� ,_ � :.4; ry « "� .` r' SO- iLAM I j V S• k * So IL p ' ' 4kr INK e i ! � � rxi c�r•r+` r - � &4" 1a. Well Status: GINJ Oil 1b. Well Class: Exploratory Service Hilcorp North Slope, LLC 14. Permit to Drill Number/Sundry 204-041 4/5/2004 4/13/2004 GL PRUDHOE BAY, BOREALIS OIL 4a. Surface: Top of Productive Interval: Total Depth: Surface: x- y- Zone -590500 5969892 ASP-4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 5/23/21 15. 50-029-23201-00-00 16. PBU V-119 Well Name and Number: Surface 53.7 17. TPI:y- Zone -592778 ASP-4x-5963226 Total Depth: x-y-Zone -592843 ASP-45963012 10483' / 6867' 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: MIND / GR, MWD / GR / PWA, PEX-Triple Combo, BHC Sonic, USIT 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 10475' Surface Surface 6862' 8-3/4" 260 sx Arctic Set( Approx,) 358 sx LiteCrete, 133 sx Class' G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# L-80 10056' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production:Abandoned 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: Surface 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 3350'12-1/4"536 sx Arctic Set Lite, 288 is Class ' G'Surface 2725' 9995' / 6568' 24-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 0028245 321-016 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): 81.7 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 4645' FSL, 1803' FEL, Sec. 11, T11 N, R11 E. UM 2047' FNL, 388' FWL, Sec. 13, T11N, R11E, UM 2263' FNL, 45 FWL, Sec. 13, T11N, R11E, UM By Samantha Carlisle at 7:03 pm, Jun 09, 2021 RBDMS HEW 6/10/2021 Abandonment Date 5/23/2021 HEW GSFD 6/24/2021 MGR08JUL2021 x DSR-6/10/21DLB 06/22/2021 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. 3730' 6182' 6471' 7091' 9702' 10073' 10200' 10258' 10352' 2952' 4364' 4531' 4893' 6395' 6615' 6694' 6730' 6787' Ugnu Schrader Bluff N Schrader Bluff O Base Schrader Bluff / Colville HRZ Kalubik Kuparuk C Kuparuk B Kuparuk A Kuparuk A 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 10352'6787' Top of Productive Interval 10200'6694' 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. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList 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 16:09:52 -08'00' Stan Golis (880) FULL ABANDONMENT - ALL STRINGS CEMENTED TO SURFACE & CUT 3' BELOW TUNDRA (05/23/21) ACTIVITY DATE SUMMARY 4/23/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48.7'. Begin excavation to ~2' below pad elevation w/ jackhammers. LDFN. 4/24/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48.7'. Continue excavation with jackhammers to 4.5' below pad elevation. Uncover cutoff casing strings and float plate. Barricade excavation, LDFN. 4/28/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48.7'. Continue excavation around float plate. Attempt to remove float plate with excavator with no success. Plan forward is to use torch to remove float plate tomorrow. LDFN. 4/29/2021 ***P&A In Progress*** Use torch to remove float plate gussets. LDFN - crew change out. 4/30/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48.7'. Remove float plate. Continue excavation with 320 excavator at the front of well and 303 excavator at the back of well, reach a depth of 7' and see partial tundra line. Cover excation with rig mat. LDFN. 5/1/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48'. Continue excavation to 13' below pad elevation, 6' below tundra elevation. LDFN 5/2/2021 ***P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48'. Clean up sides of excavation for shoring box. Set shoring box. Move over to V-201 P&A per OPS request due to SIMOPS issue with service coil at V-117. 5/10/2021 *** P&A In Progress*** Pad Elevation = 54'. Tundra Elevation = 48'. Cut cemented strings 3' 1" below Tunra elevation. T/I/O had good hard cement. Conductor x 9-5/8" casing had contaminated cement. Notified AOGCC Brian Bixby comunication the condion of the cement. He asked if we could remove cement in the contucor x casing until good ard cement is found. Removed ~ 19 inches of contaminated cement until finding hard bottom. Performed cement top job on 20" conductor & insulated conductor with 24 gal of 15.6 ppg HES Arctic C cement. Moved to V-201 to start that cut while letting cement cure. Job In Progress. 5/19/2021 ***P&A In Progress*** Cement Top job Witnessed by Adam Earl. Welded Marker plate. Pictures sent to AOGCC Adam Earl. Will return to back fill. 5/23/2021 ***P&A Complete*** Pulled shoring box. Backfilled and delineated excavation. Daily Report of Well Operations PBU V-119 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �'� 7�3��2vZ DATE: May 30, 2021 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector PBU V-119 Hilcorp Alaska North Slope LLC - PTD 2040410; Sundry 321-016 ' 5-18-2021: 1 traveled out to PBU V-119 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 4.5 feet below tundra grade. The marker plate information was correct. Attachments: Photos (2) 2021-0518—Surface—Abandon —PBU—V- I 19 ae.docx Page I of 2 C) r lqt CD Iq CDN O aCo �w �Q L W Q acn . c cU 00 CD =O �Q � � N V cA O O O L T— o- ' 02 O Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:204-041 6.API Number:50-029-23201-00-00 PRUDHOE BAY, BOREALIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028240 & 028245 Property Designation (Lease Number):10. N/A 8. PBU V-119 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 10483 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): 6867 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9995, 6568 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program Surface - 3350 Surface - 2725 14. Estimated Date for Commencing Operations: BOP Sketch Surface - 109 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker Premier Packer None 4-1/2" 12.6#Surface - 10056 Production Surface Surface Surface None Surface - 109 470 9-5/8" Contact Phone:(907)564-4891 Date: ~77 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 ~3318 5750 Intermediate ~10443 7" Surface - 10475 Surface - 6862 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 12, 2021 321-016 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2021.01.12 09:35:54 - 09'00' Stan Golis Photo document and described. DSR-1/12/21 10-407 SFD 1/13/2021MGR12JAN2020 Yesn Required? Comm 1/28/21 dts 1/28/2021 JLC 1/28/2021 RBDMS HEW 1/29/2021 Plug and Abandon Well: V-119 PTD: 204041 API: 50-029-23201-00 V-119 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 Borealis well V-119 (PTD# 204041) was originally drilled and completed in 2004. V-119 was shut-in after an unsuccessful surface casing repair and was suspended under sundry #318-009 on 6/1/2018. All strings were cemented to surface and the wellhead was cut and temporarily capped approximately 3 feet 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-119 API No. 50-029-23201-00 PTD No. 204041 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 shutdcvvn ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate Nev, Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name. BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 204-041 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 1 6. API Number. 50-029-23201-00-00 7. Property Designation (Lease Number): ADL 02824011028245 8. Well Name and Number: PBU V-119 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. BOREALIS OIL RECEIVE 11, Present Well Condition Summary: Total Depth: measured 10483 feet Plugs measured Surface feet JUN 2 6 2019 true vertical 6867 feet Junk measured None feet Effective Depth: measured Surface feet Packer measured 9995 feet true vertical Surface feet Packer true vertical 6568 fee[ AOGCC Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor -77 20" Surface - 109 Surface - 109 1490 470 Surface -3318 9-5/8" Surface -3350 Surface -2725 5750 3090 Intermediate Production -10443 T Surface -10475 Surface -6862 7240 5410 Liner Perforation Depth: Measured depth: None fee1 True vertical depth: feet Tubing (size, grace, measured and true vertical depth) 4-112" 12.6# L80 Surface - 10056 Surface - 6605 Packers and SSSV (type, measured and 4-12" Baker Premier Packer 9995 6568 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water-BDI Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments: (w uke4 per 20 MC 25,07025.071, s 25,20) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ JGSTOR ❑ 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: I peciali t Contact Email: Travis.Mompomeryabp.com Authorized Signature: Date: l Z,�/ Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 1401 ZS;r°"''97 RBDMSL4� JUN 2 8 2019 Submit Original Only 101 of A V-11 i niL) = NSA. i emp = sl. AUUU; 51-1 Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 ISV,WV=C. IA, OA = OTG. 11:30 Suspended Well Site Inspection FormI^Ilial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: V-119 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 2040410 API Number: 50-029-23201-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 6/1/2018 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: Clean vaa or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: None icv�l Access road condition: Good Photographs taken (# and description): Pad 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: Clean Cellar description, condition, fluids: N/A Rat Hole: N/A Wellhouse or protective barriers: N/A Well identification sign: N/A Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description): Yes Work Required: None Operator Rep (name and signature): Josh Prowant�r1T AOGCC Inspector: Adam Earl Other ObServers: Inspection Date: 6/2/2019 AOGCC Notice Date: 6/1/2019 Time of arrival: 11:15 AM Time of Departure: 11:20 AM Site access method: Access Road pm-MMIJAM WO 7�w r WELLMMEV•11 p Ii. �J19�YI1;,1�1� w �♦ a4 ' t d LZ -112 I2-32 _ Z-$25 PB2 -_ f_.Z-32A 110 _ AO?A I 12 Z-112PB2 Z-09: Z-05 '.Z-38PB1 "Z-OPAPBI ' -Z-238 Z-O!A Z-09 C Z -04A Z-04 Z-102 ;131 i -- -- - '.c214PB4 V= 'j- 105 - 7V--213 iA204PB2 V=2224 — V=211 2 1 U1 2PSi �01,KUPST-01 104 3-V-204L1PB1 V-101 9 `J-02 V-111 -, '� `J-2050 V-207L4PS1 9• V-24 V-2 0+[2 ,!20.1 V-204UP131 V-1�204PB'Y%1212 - B 111 P@7- Z-81 Cb=107 V-117PB3 UL110XTC 27 YF224P61 V-i1,.L2�,0�218 j�,12219 C. V-,08 V-214PB1 - �, I Z 30^7 V-'219 V p , 09FB2 V ¢B, V 1m 11 5LZ Z-22 V,15P'81 2m Z -22A V 114A I 1 if 12 — Z-31 ." V- 114A.PB2 G V11E _ Z -32B 11 4AP 1 215 1 Z -32C LZ -112 I2-32 _ Z-$25 PB2 -_ f_.Z-32A 110 _ AO?A I 12 Z-112PB2 Z-09: Z-05 '.Z-38PB1 "Z-OPAPBI ' -Z-238 Z-O!A Z-09 C Z -04A Z-04 Z-102 ;131 i 1�1�1�1' Suspended Well Inspection Report InspectNo: susAGE190618091250 Date Inspected: 6/2/2019 Inspector: Adam Earl Well Name: PRUDHOE BAY UN BORE V-119 Permit Number: 2040410 Suspension Approval: Sundry tt 317-527 Suspension Date: 6/1/2018 Location Verified? If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent ' Date AOGCC Notified: 6/1/2019 Operator: BP Exploration (Alaska)Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? Photos Taken? Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑ OA: VR Plug(s) Installed? ❑ Wellhead Condition NA Condition of Cellar NA Surrounding Surface Condition well is buried, no sheen or trash, area looks clean Comments No Issues, location verified by pad map Supervisor Comments Photos (2) attached Tuesday, August 13, 2019 O O U-) O N O O 000— CL C W W_aow �cy)Q �w r0 `o CL Q U N N CL Xt c I C) —y U U (D 0 C O C U O QU N 3 O t N maacfl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED S{ '?1W 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ® - 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well Class. Development ❑ ExploJf [3" �' Service p Stratigraphhis Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6, Date Comp., Susp., or Abend.: 6/1/2018 14. Permit to Drill Number/Sundry 204-041 • 317-306 & 318-009 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7, Date Spudded: 4/5/2004 15, API Number. 50-029-23201-00-00 4a. Location of Well (Governmental Section): Surface: 4645' FSL, 1803' FEL, Sec. 11, T11 N, R11 E. UM Top of Productive IntervaC 2047' FNL, 388' FWIL, Sec. 13, T11N, R11E, UM Total Depth: 2263' FNL, 45V FAIL, Sec. 13, TI IN, R11E, UM 8. Date TO Reached. 4/13/2004 16. Well Name and Number: PBU V-119 ' 9 Ref Elevations KB 81.70 - GL 53.70 BF Surface 17. Field/Pool(s): PRUDHOE BAY, BOREALIS OIL ' 10. Plug Back Depth(MD/TVD): Surface 18, Property Designation: ADL 028240 & 028245 ' 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590500 • y- 5989892 Zone - ASP 4 TPI: x- 592778 y- 5963226 Zone - ASP 4 Total Depth: x- 592843 y- 5963012 Zone - ASP 4 11. Total Depth (MD/TVD): 10483'/ 6867' 19. DNR Approval Number: 00-001 12. SSSV Depth (MD/TVD): None PO Thickness of Permafrost MDr-VD: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21, ReAnt/Lateral Top Window MD/ND: 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 my, 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 MIND / GR, MWD / GR / PWA, PEX-Triple Combo, BHC Sonic, USIT 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 Surface 109' Surface 109' 42" 260 sx Arctic Set(Approx,) 9-5/8" 40# LEO Surface 3350' Surface 2725' 12-1/4" 536 sx Arctic Set Lite, 288 is Class 'G' 7" 26# Lao Surface 10475' Surface 6862' 8-3/4" 358 sx LiteCrete, 133 sx Class'G' 24. Open to production or injection? Yes ❑ No m If Yes, list each interval open (Ii of Top and Bottom; Perforation Size and Number; Date Perfd): s ,- Dvu 'eeMP7 _ DATE ( 1171—r VERT)`IED 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# L-80 10056' 9996'16568' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No RI Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTHINTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27, PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, gas lift, etc.) WA Date of Test: Hours Tested Protluction for Test Period y Oil -Bbl Gas -MCF: Water -Bbl: Choke Sire Gas -Oil Ratio: Flaw Tubing Press Casino Press: Calculated 24 Hour Rale y Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (coff): Form 10-407 Reviseo 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS4,-,rL-nJUN 2 9 2018 28. CORE DATA Conventional Corals) 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 10200' 6694' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 3730' 2952' Schrader Bluff N 6182' 4364' Schrader Bluff O 6471' 4531' Base Schrader Bluff / Colville 7091' 4893' HRZ 9702' 6395' Kalubik 10073' 6615' Kuparuk C 10200' 6694' Kuparuk B 10258' 6730' KuparukA 10352' 6787' Formation at total depth: KuparukA 10352' 6787' 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, Aras J Authorized Title. SI ecialist Contact Email: Ares.Worthington@bp.cem Authorized Signature: Date: Contact Phone: +1 907 564 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 1 a. 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 hem 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each addifional 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 coretl 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-119 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used Conductor 33 Gal AS 1 8702' 27 Bbls Class'G' Surface 115 Bbls Cement, 312 Bbls Class 'G' Surface —20 Gal AS I Daily Report of Well Operations V-119 ACTIVITYDATF SI IMMARY TWO = SSV/3/9. Temp = SI. Bleed OAP to 0 psi (Eval fluid in conductor). Spray in liner installed in cellar. There is 21" of water in cellar. Fluid in conductor has come over the top and -1/2 gal has spilled into the cellar. Bubbling in conductor at the 10 o'clock position. No LELs 1' above bubbling or anywhere else in WH. Bled OAP to BT from 9 psi to 0 psi in 3 min (Gas). Monitored for 15 min. OAP increased 4 psi, bubbling in conductor subsided and the FL in the conductor receeded 1". Bled OAP to 0 psi and held an open OA bleed for 30 min. Monitored for 15 min, OAP increased 1 psi, SRT on location. Fluid in conductor is now 1 1/2" from the top. Final WHPs = SSV/3/1. 8/15/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:10 TWO = SSV/3/6. Temp = SI. Bleed OAP to 0 psi (Eval fluid in conductor). Spray in liner installed in cellar. Fluid in conductor had come over the top and into the cellar (-7 gal). There is 21" of water in cellar. Bubbling in conductor at the 6 and 10 o'clock positions. No LELs 1' above fluid and throughout WH. SRT on location upon arrival. Vac truck arrives on location and evacuates conductor and dark fluid from cellar. Fluid in conductor is now 11" from the top. Bled OAP to BT from 6 psi to 0 psi in 1 min (Gas). Monitored for 30 min. OAP increased 2 psi. Final WHPs = SSV/3/2. 8/16/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:20 TWO = SSV/3/5. Temp = Sl. Conductor Top Job Prep (SC mitigation). Spray in liner installed in cellar. Cellar is 40" deep w/ 13" of fluid/what looks to be water. Flutes are 14" above the top of the conductor. Intermittent bubbling in the conductor @ the 3, 6 & 10 o'clock positions. 0% LELs 1' above & through out well house. Fluid in the conductor is 4" from the top. Evaded black crude like fluid from the conductor. There is 18" from the top of the conductor to what feels like a gravel bottom w/ -13" of RG 2401. Cleaned out -3 gal of RG 2401 & Evac'ed the remaining fluid from the conductor. FWHPs = SSV/3/5. 8/17/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 8/19/2017 Job Scope: Prep conductor for cement. Cleanout rocks, wash w/ hot water. Steam Job Scope: Prep conductor for cement. Cleanout cement, wash w/ hot water, steam conductor Start open bleed on OA (no flow). Vac 4" crude from conductor. TOC @ 18". Remove cement to 34" w/ 6' bar, hot water and Cusco. Steam conductor 4 hrs. crude still seeping into conductor - unable to properly clean. Remove OA valve and insert hose into OA to remove fluid. Unable to pull fluid deeper than 2-3' through small diameter hose (unable to insert larger hose in 7 x 9-5/8" annulus). Replace and PT OA valve. Will depress FL in OAw/ N2 8/19/2017 *****Cont on WSR 8/20/19***** Job Scope: Cement Conducutor *****Cont from WSR 08/19/17***** OA pressure built to 8 psi overnight. Cellar watch noted increase in rate of crude in conductor (kept vac'd out overnight) Apply N2 to depress OA fluid level and vac out returns from condcutor. N2 in returns after 4 gal recovered. Known hole in OA @ 15.3' (OA vol to hole -16 gal. Expected -16 gallons of returns before N2 to surface since fluid level in OA was verified at surface. Continue N2 on OA and add hot water to conductor while maintaining vac. Attempt to perc crude from condcutor to prep for cementing. Stop when no more crude entering conductor. Wash conductor and surace casing w/ hot water and F103. Mix and pour 33 gal SLB AS1 cement. Conductor topped off. DHD maintain open bleed on OA. AS1 cement reaches 1200 psi compressive strength 6-8 hrs and ultimate compressive strength (>2000psi) in 6 days 8/20/2017 IT/I/O = SSV/3/0. Temp = SI. Hold open bleed on OA (post cement). Monitored cement & held open bleed on OA. 8/20/2017 Cont on WSR 8/21/17 Daily Report of Well Operations V-119 WSR continued from 8/20/17. TWO = SSV/3/0. Temp = SI. Hold open bleed on OA (post cement). Monitored cement & held open bleed on OA. OA BUR = 2 hrs/0 psi. 24-581 Crystal gauge & T left on recording data. FWHPs = SSV/3/0. 8/21/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:15 TWO = SSV/0/7. Temp = SI. Eval fluid in conductor (WIE Request). Crystal gauge on OA. There is a small depression in the conductor cement at the 3 o'clock position with a small amount of dark fluid in it (1/4", 1/2 dollar size). No LEL's/bubbling at the fluid, around the conductor or throughout the wellhouse. 8/22/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1640 hrs. TWO = SSV/O+/O+. Temp = SI. WHP's & eval SC. (Post top job). No fluid in top of conductor, cement @ top of SC and -90% solid. 8/22/2017 SV, SV, SSV = C. MV = O. IA, OA = OTG. 04:45 TWO = SSV/3/7. Temp = Sl. Eva] fluid in conductor (WIE request). Crystal gauge recording on OA. There is a hole in the top of the cement in conductor at the 3 o'clock position -1.5" in circumfrence. Dark fluid in the hole is at the top of cement with bubbling. No LELs at bubbling, 1' above, or anywhere else in WH. Bled OAP to BT from 7 psi to 0 psi in 1 min (Gas). Monitored for 30 min. FL and bubbling in conductor unchanged. Final WHPs = SSV/3/0+. 8/23/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:15 TI/O = SSV/3/5. Temp = SI. Eval conductor cement (WIE request). OAP increased 5 psi overnight. There is a depression in the conductor cement @ the 3 o'clock position. There is dark luid in the depression is -1.5" in circumference (Sporatic bubbling). Bled the OAP from 5 psi to 0 psi in 3 minutes (all gas, no change in the bubbling). The OAP increased to 1 psi in the 30 minute monitor. FWPs = SSV/3/1. 8/24/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1040 hrs. TWO = SSV/3/7. Temp = SI. Eval conductor cement (WIE request). Fluid in conductor at the 3 o'clock position is -1/2" below the top of cement. No bubbling observed. Bled OAP from 7 psi to 0 psi in 1 min (Gas). Monitored for 30 min. OAP increased 1 psi. No bubbling observed. Final WHPs = SSV/3/1. 8/25/2017 SV, WV, SSV = C. MV = O. ]A, OA = OTG. 16:20 T/1/0 = SSV/3/5. Temp = SI. Eval conductor cement (WIE request). Crystal gauge on the IA (recording, 75% battery). There is a 112 " deep depression @ the 3 o'clock position in the conductor (Cement is stained where fluid was but standing fluid reported on 8/25 is gone). Bled the OAP from 5 psi to 0 psi in 30 seconds (gas). The OAP increased to 0+ psi and the depression in the cement top inflowed to 1/4 " (steady bubbling, no LEL's 1" above the bubbling or throughout the wellhouse). FWPs = SSV/3/0+. 8/26/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1000 hrs. TWO = SSV/3/5. Temp = SI. Eval conductor cement (WIE request). Crystal gauge on the OA (recording, 25% battery), pulled & replaced batteries & downloaded data. No bubbling at this time. Bled OA from 5 psi to 0 psi in - 10 seconds (gas). Cleaned fluid out of depression @ the 3 o'clock position. Re-installed crystal gauge on OA recording @ 15 second intervals. 8/27/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:15 TWO = SSV/3/6. Temp = SI. Eval conductor cement (WIE request). OAP increased 6 psi overnight. Crystal gauge on the OA (recording, full battery). No bubbling at this time. Cleaned -1/4" fluid out of depression @ the 3 o'clock position. Bled OA from 6 psi to 0 psi in <10 seconds (gas). 8/28/2017 SV, WV, SSV = C. MV=O. IA, OA = OTG. 09:15. Daily Report of Well Operations V-119 TWO = SSV/3/6. Temp = SI. Eval conductor cement (WIE request). OAP increased 6 psi overnight. Removed Crystal gauge from the OA. No bubbling at this time. Cleaned -1/4" fluid out of depression @ the 3 o'clock position. Bled OA from 6 psi to 0 psi in <10 seconds (gas). 8/29/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 hrs TWO = SSV/3/6. Temp = SI. Eval Conductor Cement (WIE Req). OAP increased 6 psi overnight. Removed Crystal gauge from the OA. Slight bubbling @ 3 o'clock position. Bled IAP from 3 psi to 0 psi in <10 sec. Bled OA from 6 psi to 0 psi in <10 seconds (gas). Bubbles stopped and still no LEL's. Cleaned -1/4" fluid out of depression @ the 3 o'clock position. Monitor for 30 min. No change in WHPs, fluid @ 3 o'clock filled in slightly. Final WHPs = SSV/0/0. 8/30/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:00 TWO = SSV/0+/9. Temp = SI. Eval conductor cement (WIE request).. There is a baseball size spot of dark fluid @ the 3 o'clock position (no bubbling noticed, cleaned up before departure). Bled the OAP to 0 psi before departure. 9/1/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1320 hrs. T/1/0 = SSV/0+/6. Temp = SI. Eval conductor cement (WIE request). The baseball size spot of dark fluid is back on the cement of the conductor in the 3 o'clock position. No visible bubbling on cement or in cellar. Cleaned up spot and bled OAP to 0 psi (all gas, < 1 min). Monitored for 30 mins, OAP increased to 6 psi & dark spot returned about the size of a golf ball. Wiped dry before departure. Final WHPs = SSV/0+/3. 9/1/2017 SV, WV, SSV = C. MV =0. IA, OA = OTG. 23:59 T/I/0 = SSV/0+/6. Temp = SI. Eval conductor cement (WIE request).. There is a baseball size spot of dark fluid @ the 3 o'clock position (no bubbling noticed, cleaned up before departure). Bled the OAP to 0 psi before departure. 9/2/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 TWO = SSV/0+/5. Temp = SI. Eval conductor cement (WIE request). There is a baseball size puddle of dark fluid @ the 3 o'clock position (no bubbling, cleaned up before departure). Bled the OA to 0 psi. 9/3/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1545 hrs. T/I/O = SSV/0+/8. Temp = Sl. Eval Conductor Cement (Wie Request). In the 3 o'clock position their is a puddle of dark fluid about softball size (no bubbling, cleaned up before departure. 9/4/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00 T/I/O = SSV/0+/13. Temp = SI. Eval Conductor Cement (Wie Request). In the 3 o'clock position their is a puddle of dark fluid about softball size (no bubbling, cleaned up before departure. 9/6/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 TWO = SSV/0+/8. Temp = SI. Eval Conductor Cement (WIE Req). Cleaned -1/2 cup of dark fluid from the conductor cement top @ the 3 o'clock position (no sign bubbling). Bled OAP to BT from 8 psi to 0 psi in -10 sec. FWHPs = SSV/0+/0. 9/7/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 TWO = 460/0+/4. Temp = SI. Eval Conductor Cement (WIE Request). Cleaned -1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position (fluid was slowly seeping back into the impression in cement after cleaning). Bled OAP to BT from 4 to 0 Psi. FWHP = 460/0/0. 9/8/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 09:30. T/I/O = 460/0+/0. Temp = SI. Eva[ Conductor Cement (WIE Request). Cleaned -1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position no bubbling, (fluid was slowly seeping back into the impression in cement after cleaning). PO had cleaned up the puddle earlier in the day. 9/9/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 13:00 Daily Report of Well Operations V-119 TWO = SSV/0/10. Temp = Sl. Eval Conductor Cemented (WIE Req). Cleaned -1/2 cup dark fluid from the conductor cement top @ the 3 o'clock position (no sign of bubbling). Bled OAP to BT from 10 psi to 0 psi in <1 min. Final WHPs = SSV/0/0. 9/10/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:00 TWO = SSV/0/10. Temp = SI. Eval Conductor Cemented (WIE Req). Cleaned -1/2 cup dark fluid from the conductor cement top @ the 3 o'clock position (no sign of bubbling). Bled OAP to BT from 10 psi to 0 psi in <1 min. Final WHPs = SSV/0/0. 9/11/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 TWO = SSV/0/7. Temp = SI. Eval Conductor Cement (WIE Req). Cleaned -1/2 cup dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. Bled OAP from 7 psi to 0 psi in <1 min (gas). Final WHPs = SSV/0/0. 9/11/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00. TWO = SSV/O/10. Temp = SI. Eval Conductor Cemented (WIE Req). Cleaned -1/4 cup dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. Bled OAP to BT from 10 psi to 0 psi in <1 min. Final WHPs = SSV/0/0. 9/13/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 TWO = SSV/0/10. Temp = SI. Eval Conductor Cemented (WIE Req). Cleaned -1/4 cup dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. OAP increased 10 psi overnight. Bled OAP to BT from 10 psi to 0 psi in <1 min. Final WHPs = SSV/0/0. 9/14/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 TWO = SSV/O+/8. Temp = SI. Eval Conductor Cemented (WIE Request). Cleaned -1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. OAP increased 8 psi overnight. Bled OAP to BT from 8 psi to 0 psi in -30 sec (Gas). Final WHPs = SSV/0/0. 9/15/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 13:30 TWO = SSV/0/10. Temp = SI. Eval Conductor Cemented (WIE Request). Cleaned -1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. OAP increased 10 psi overnight. Bled OAP to BT from 10 psi to 0 psi in -30 sec (Gas). Final WHPs = SSV/0/0. 9/16/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 13:00 TWO = SSV/O+/8. Temp = SI. Eval conductor cemented (WIE request). Cleaned -1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. OAP increased 8 psi overnight. Bled OAP to BT from 8 psi to 0 psi in 30 sec. (Gas). Final WHPs = SSV/O+/0. 9/17/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 12:15 TWO = SSV/0/6. Temp = SI. Eval Conductor Cemented (WIE Request). Cleaned -1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. OAP increased 6 psi in 15 hours. Bled OAP to BT from 6 psi to 0 psi in -30 sec (Gas). Final WHPs = SSV/0/0. SSV, WV, SV = C. MV = O. IA, OA= OTG. 16:30 9/18/2017 TWO = SSV/O+/6. Temp = SI. Eval conductor cement (WIE request). Cleaned <1/4 cup of dark fluid from the conductor cement top @ the 3 o'clock position. No bubbling at this time. OAP increased 6 psi in 12 hrs. Bled OAP from 6 psi to 0 psi in -30 sec (gas). Final WHPs = SSV/O+/O. 9/18/2017 SSV, WV, SV = C. MV = O. IA, OA = OTG. 01:00. TWO = SSV/0/9. Temp = SI. Eval conductor cement (WIE request). There is a small amount of dark fluid on top of the cement in the conductor at the 3 o'clock position. No bubbling observed. Bled OAP to 0 psi. Monitored for 30 min. OAP increased 1 psi. Final WHPs = SSV/0/1. 9/19/2017 SV, WV, SSV = C. MV = 0 IA, OA = OTG. 23:50 Daily Report of Well Operations V-119 T/I/O = SSV/0/7. Temp = SI. Eval conductor cement (WIE request). Cleaned <1/4 cup of dark fluid from the cement in the conductor at the 3 o'clock position. No bubbling observed. Bled OAP to 0 psi <1 min (gas). Final WHPs = SSV/0/0. 9/20/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:50 TWO = SSV/0/11. Temp = Sl. Eval conductor cement (WIE request). Cleaned <1/4 cup of dark fluid from the cement in the conductor at the 3 o'clock position. No bubbling observed. Bled OAP to 0 psi <1 min (gas). Final WHPs = SSV/0/0. 9/22/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:10. T/I/O = SSV/1/11. Temp = SI. Eval conductor cement (WIE request). There is a small amount of dark fluid on top of the cement in the conductor at the 3 o'clock position with bubbling observed. Cleaned <114 cup of fluid from the top of conductor at the 3 o'clock position. Bled OAP to 0 psi. No change in bubbling. Monitored for 30 min. OAP increased 1 psi. Final WHPs = SSV/1/1. SV, WV, SSV = C. MV = O. IA, OA= OTG. 20:30 9/23/2017 TWO = SSV/0/11. Temp = SI. WHPs, Bleed if required. (Eval Conductor cement job, WIE request). OA FL = Near surface. 2" x 3" spot of dark fluid on top of cement @ 3 O'clock position (cleaned up) with 1 small bubble every 5 to 6 seconds. Bled OAP from 11 psi to 0 psi in <30 seconds, rig down & monitor for 30 minutes. No change in IAP, OAP increased to 2 psi in 30 minutes. Final WHP's = SSV/0/2. 9/25/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:35. T/I/O = SSV/0/10. Temp = SI. WHPs (Eval conductor cement job). Half dollar size puddle of dark fluid in cement top depression (cleaned before departure, no bubbling). Bled the OAP to 0 psi in 15 seconds (all gas). 9/26/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1300 hrs. T/I/O = SSV/10/10. Temp = SI. WHPs (Eval conductor cement job). Half dollar size puddle of dark fluid in cement top depression with a bubble every — 30 sec. Bled the OAP to 0 psi in 15 seconds (all gas). Cleaned fluid from depression, no bubbling after bleeding OAP to 0 psi. 9/27/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 TWO = SSV/10/6. Temp = SI. Eval Conductor Cement (WIE Req). Half dollar size puddle of dark fluid in cement top depression w/ no bubbling. Bled the OAP to 0 psi in 15 seconds (all gas). Cleaned fluid from depression. 9/28/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 TWO = SSV/0/8. Temp = SI. WHPs (Eval cement top). There is a quarter dollar size puddle of fluid in the cement top depression (no bubbling). Bled the OAP to 0 psi in 15 9/29/2017 seconds. TWO = SSV/6/12. Temp = SI. Eval conductor cement (WIE request). There is a small amount of fluid on top of cement in the conductor at the 3 o'clock position. No bubbling observed. Bled OAP to 0 psi. Intermittent bubbling now observed on top of fluid in conductor. OAP increased 2 psi. Final WHPs = SSV/612. 9/30/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 T/I/O = SSV/5/20. Temp = Sl. Eval conductor cement (WIE request). There is a small amount of fluid on top of cement in the conductor at the 3 o'clock position. No bubbling observed. OAP increased 20 psi since 9/30/17. Bled OAP to 0 psi. Final WHPs = SSV/5/0. 10/5/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 TWO = SSV/5/10. Temp = SI. Eval conductor cement (WIE request). There is about 2 table spoons of fluid in the divit in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP to 0 psi (<1 min, all gas). Final WHPs = 10/6/2017 SSV/5/0. Daily Report of Well Operations V-119 T/I/O = SSV/5/10. Temp = SI. Eval conductor cement (WIE request). There is about 1 table spoon of fluid in the divit in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP to 0 psi (<1 min, all gas). Final WHPs = 10/7/2017 SSV/5/0. T/I/O = SSV/5/7. Temp = SI. Eval conductor cement (WIE request). There is -1 teaspoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP to 0 psi (<1 min, all gas). Final WHPs = SSV/5/0. 10/8/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 20:00 T/I/O = SSV/4/11 Temp = SI. Eval conductor cement (WIE request). There is -1 tablespoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP from 11 psi to 0 psi (<30 sec, all gas). Final 10/10/2017 WHPs = SSV/4/0. T/I/O = SSV/2/10 Temp = SI. Eval conductor cement (WIE request). There is -1 tablespoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP from 10 psi to 0 psi (<30 sec, all gas). Final 10/12/2017 WHPs = SSV/2/0. T/I/O = SSV/3/12. Temp = SI. Eval conductor cement (WIE request). There is -1 tablespoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP from 12 psi to 0 psi (<30 sec, all gas). Final WHPs = SSV/3/0. 10/14/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30. T/I/O = SSV/2/10. Temp = Sl. Eval conductor cement (WIE request). There is -1 tablespoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP from 10 psi to 0 psi (<30 sec, all gas). Final WHPs = SSV/2/0. SV, WV, SSV = C. MV = O. IA, OA= OTG. 12:00. 10/15/2017 T/I/O = SSV/2/20. Temp = SI. WHPs (Eval SC leak). There is -1 tablespoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP from 20 psi to 0 psi (<30 sec, all gas). Final WHPs = SSV/3/20. 10/20/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30. T/I/O = SSV/2/15. Temp = SI. WHPs (Eval SC leak). There is -1 tablespoon of fluid in the divet in the cemented conductor at the 3 o'clock position. No bubbling observed. Wiped up fluid & bled OAP from 15 psi to 0 psi (<30 sec, all gas). Final WHPs = SSV/2/0. 11/2/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O = SSV/0+/20. Temp = SI. IA FL (WIE request). IA FL @ 35'. Small amount of fluid in the divet in the cemented conductor @ the 3 o'clock position. 11/8/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:35 T/I/O = SSV/0/16. Temp = SI. WHPs (Ops call in). Rapid bubbling in the cemented conductor @ the 3 o'clock position (16% LEL's 1" above bubbling). Bled the OAP to 0 psi in 15 seconds (all gas, no change to bubbling rate). Sampled flowstream during bleed: 02 = 16%. LEL's = OR. CO2 = 5.6%. No abnormal gas readings 1' above bubbling or throughout the rest of the wellhouse. 11/22/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 0955 hrs. T/I/O = SSV/03/14. Temp = Sl. WHPs (Eval conductor cement job). IA FL near surfac, OA FL cemented. There is a half dollar size puddle of dark fluid in cement top depression with a very small bubble every - 1 sec. Bled IAP from 03 psi to 0 psi in - 2 sec. Bled the OAP to 0 psi in -15 seconds (all gas). Cleaned fluid from depression, still bubbling after bleeding IAP & OAP to 0 psi. Held open bleed on OAP and monitored gas bubbling with 4 gas 1" above leak point for 30 min with no % LEL or decrease in bubbling. Final WHPs = SSV/0/0. 11/28/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30 Daily Report of Well Operations V-119 T/l/O = SSV/0/10. Temp = SI. WHPs (post bleed). Quarter size fluid on cement depression, wiped up with a rag. No LELs detected at this time. OAP increased 10 psi since bleed on 11/28/17. 11/30/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 T/I/O = SSV/0/10. Temp = SI. WHPs (post bleed). No new fluid on cement depression. 0% LEL's detected. WHPs unchanged from 11/30/17. 12/3/2017 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 12/31/2017 (INJECTIVTY TEST) Job postponed due to rig on pad. 1/2/2018 T/1/0= 434/8/23 Temp= FP (OA Injectivi Test) ***job continued to 1/3/2018 T/I/O = 0+/10/20. Temp = SI. Assist FB w/ cellar watch (SC leak). Conductor has a depression in the top of the cement @ the 3 o'clock position that is -3" across and -1" deep where fluid has historically seeped up through. Assisted FB as they pumped down the OA wiping up -1 teaspoon of fluid from the depression. Final WHPs = 0+/10/10. 1/3/2018 LRS in control of valves upon departure. 02:00 ***WSR continued from 1/2/2018 (OA injectivity test). Pumped 12 bbls crude down OA to establish injetivity rate of 0.75 to 0.8bpm @ 850-900 psi. No significant retruns from conductor (became moist, no vac needed, able to wipe up with rag). OAP fell from 900 psi to 9 psi in 5 min. monitor after shutting down. 1/3/2018 FWHP= 453/8/7 Vavles= wing, ssv, swab= closed IA, OA= open to gauge ***WELL SHUT IN ON ARRIVAL*** (p&a) PULLED 4-1/2" PX PLUG @ 2214' MD DRIFTED TBG. w/ 20'x 3.70" DUMMY WHIPSTOCK TO 3000' SLM ***JOB COMPLETE, WELL LEFT S/I*** ***DRIFTED TO 3000' MD w/ 3.70" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE 1/30/2018 SURVEILLANCE*** T/I/O = SSV/Vac/0. Temp = SI. Measurments (P&A). Measurement from BFE to top of landing ring = 26.5"". BFE to top of conductor = 44". BFE to pad grade -6' in front of wellhouse door = 44.75". 2/1/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1515 hrs. T/l/O = 550/0+/10. Temp = SI. T FL (FB request). T FL @ 280' (5 bbls). 2/2/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:30 T/I/0= 537/2/11. Injectivity test. Pre P&A (Plug and abandonment -reservoir) Pumped 1 bbl 60/40, followed by 38 bbls crude down tbg. Load tbg with 80 bbls of 1 % kcl at max rate. Slow rate to 1 bpm and begin injectivity test as follows: 1 bpm pressures were 1342 psi to 1288 psi 5 bbls pumped. 2 bpm pressures were 1401 psi to 1460 psi. 10 bbls pumped. 3 bpm pressures were 1518 psi to 1558 psi. 15 bbls pumped. 4 bpm pressures were 1643 psi to 1641 psi. 20 bbls pumped. 5 bpm pressures were 1749 to 1798 psi. 40 bbls pumped. Pumped 2 bbls 60/40 to flush surface lines, followed by 40 bbls crude to freeze protect tbg. Bubbling at the 3:00 position through out job. 2/3/2018 FWHP= 1426/557/73 (LRS Unit 46 - Heat Diesel Pre Cement Job) Heat diesel tanker to 90* for cement crew. 2/18/2018 Circulated and heated 195 bbls of diesel to 65*. **Continued WSR on 2-19-18** **WSR continued from 2-18-18** (LRS Unit 46 - Heat Diesel Pre Cement Job) Heat diesel 2/19/2018 tanker to 90* for cement crew. Circulated and heated 105 bbls (300 total) of diesel to 90*. Daily Report of Well Operations V-119 Initial T/I/O = 352/0/0 psi. Temp = S/I (SLB Unit - Reservoir Plug & Abandonment) Pump the following down the Tubing: 5 bbls 60/40 5 bbls Freshwater 27 bbls 15.8 ppq Class G Cement ***Estimated TOC=9200' MD*** 102 bbls Freshwater 39 bbls Diesel WV, SV, SSV = Closed. MV=Open. CV=OTG. Grease Crew on Location to service valves upon Departure. 2/19/2018 Final T/I/O = 974/0/0 psi T/I/O = SSV/0+/20. Temp = SI. WHPs p. -1 Tablespoon of fluid inside the 1/2 dollar sized depression @ the 3 o'clock position w/ active bubbling. 20.9% 02, 0% LEL, 0% CO, 0 PPM H2S V above bubbling and throughout wellhouse. 4% LEL directly on top of bubbling. 2/21/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30 TWO = SSV/0+/20. Temp = SI. Bleed OAP to 0 psi & hold open bleed for shift (Eval SC leak). -1 Tablespoon of fluid inside the 1/2 dollar sized depression @ the 3 o'clock position w/ rapid bubbling. 02 = 20.9%, LELs = 0%, CO = 0%, H2S = 0 PPM V above bubbling and throughout wellhouse. Bled OAP to BT form 20 psi to 0+ psi in -45 sec, ten minutes after holding open bleed bubbling slowed to -1 bubble every 10 sec. Held open bleed on OA for 7.5 hrs, bubbling would increase & decrease throughout the day. Final WHPs = SSV/0+/0. 2/22/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:20 T/I/O = SSV/0+/4. Temp = SI. Bleed IAP & OAP to 0 psi (Eval SC leak). IA FL near surface. OA FL cemented to surface. -1 Tablespoon of fluid inside the 1/2 dollar sized depression @ the 3 o'clock position w/ rapid bubbling. 02 = 20.9%, LELs = 0%, CO = 0%, H2S = 0 PPM 1' above bubbling and throughout wellhouse. Bled IAP & OAP to BT form 0+/4 psi to 0 psi in <1 min. Bubbling in conductor unchanged. Monitored for 30 min. WHPs unchanged. 2/23/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:00 T/I/O = SSV/0/7. Temp = SI. WHPs (post bleed). -1 Tablespoon of fluid inside the 1/2 dollar sized depression @ the 3 o'clock position w/ active bubbling (bubbling has slowed from previous monitor). 20.9% 02, 0% LEL, 0% CO, 0 PPM H2S V above bubbling and throughout wellhouse. IAP unchanged, OAP increased 7 psi from 2/23/18. 3/1/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 TWO = SSV/1/9. Temp = SI. WHP's. (Eval Bubbling in SC). IAP increased 1 psi, OAP increased 2 psi in 4 days. -1 tablespoon of fluid in -2" to 3" depression in cement at the top of the SC, constant slow bubbling at this time. 20.9% 02, 0% LEL, 0% CO, 0% H2S 1" above the bubbling and inside the wellhouse. 3/5/2018 SSV = C. MV = O. IA, OA = OTG. 22:35 S/I ON ARRIVAL ***(P&A) WCP 4522 3/7/2018 ON 3-8-18 WSW" LAbandonlment-Reservoir) /5 Temp= S/I Assist Slickline: AOGCC State witnessed MIT-T(Plug and rvoir) MIT -T **PASSED** at 1564 psi target 1500 psi max applied Pumped 2.8 bbls 60/40 to reach test pressure. 1 st 15 min TBG lost 58 psi. 2nd 15 min TBG lost 29 psi for total loss of 87 psi in 30 min. Bled TBGP, bled back - 2.8 bbls. SL performed passing negative test on TBG. RDMO. Hung info tag on WV/MV. SL in 3/8/2018 control of well upon LRS departure. IA/OA=OTG FWHP's=0/2/7 Daily Report of Well Operations V-119 ***CONT FROM 3-7-18 WSR***(P&A) DRIFTED WITH 3.50" CENT& 3" SBLR TO 8679' SLM. DRIFTED WITH 2.60" CENT& 2.5" SBLR TO 8702' SLM. HARD BOTTOM, UNABLE TO GET DEEPER. RAN 2.74" CENT & 2.50" SAMPLE BAILER, TAGGED TOC @ 8702' SLM, 8707'MD (aogcc witnessed) LRS PERFORMED PASSING MIT -T TBG TO 1650psi.(see Irs log) PERFORMED PASSING NEGATIVE PRESSURE TEST ON TBG. RAN PDS 40 ARM CALIPER FROM 3,200'- oo Data) SET 4-1/2" CATCHER @ 8,682' SLM. ATTEMP TO PULL DMY-GLV FROM STA #2 AT 8502' MD DOG BROKE OFF OF PULLING TOOL. (LIH: 5/8" x 1/4" x 3") 3/8/2018 ***CONT ON 3-9-18 WSR*** ***CONT FROM 3-8-18 WSR*** (P&A) PULLED DMY-GLV FROM STA#2 AT 8502' MD PULLED EMPTY WHIDDON C -SUB FROM 8682' SLM. ***WELL LEFT S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS*** 3/9/2018 *****ONE JD DOG LEFT IN HOLE. (3" x 1/4" x 5/8")***** T/I/O = SSV/310/10. Temp = SI. WHPs (eval bubbling in cellar). -1 T spoon of black fluid in the depression on the cement @ the 3 o'clock position. No bubbling or LELs @ this time. 3/10/2018 T/1/0= 115/285/10 (PLUG AND ABANDOM ENT -RESERVOIR) Pumped 5 bbis 60/40 followed by 114 bbis 160* soap, 286 bbis 9.8 brine and 20 bbis 60/40 down TBG taking returns up IA to open top tank. U -Tube TAA freeze protect for 30 minutes from choke skid. AFE sign hung on MV ***FLUID PACKED WELL*** Caution tags hung on MV and IA. Valve 3/12/2018 positions SV/WV/SSV closed MV open CV's OTG FWHP 58/63/10 SLB Cementing - OA Downsqueez_e (Pre P&A) Establish Injectivity w/ 60/40 MW. Pump 60 bbis FW surfactant, 12 bbis 13.5 ppg Mud Push, 10 bbis neat cement 49 bbis w/ 12 ppb aggregate, and 66 bbis neat behind (total of 115 bbis cement) Volume to OA shoe 95 bbis. Avg cement rate 3 bpm @ 300 psi. Small leak to surface up OA x Conductor annulus while pumping. Did not get a bump. Final pressure on cement 1 bpm @ 40 psi. Perform hesitation sqz over 2 hrs 20 mins by hesitating 20 mins then pumping additional -3 bbis until out of cement. Shut in @ OA casing valve on cement. Wash up and freeze protect surface lines and cement pump. 3/14/2018 ****Job Complete"" T/I/O = SSVNac/9. Temp = SI. Strap TOC (P & A). Bled the OAP from 9 psi to 0 psi in 8 seconds (all gas). Maintained an open bleed for 1 hour (no flow) and strapped the top of cement @ 191'(4.9 bbis). FWPs = SSV/Vac/0. 3/17/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1300 hrs. SLB Fullbore PUmping Crew. Job Scope: Plug and Abandonment cement down 4-1/2" TBG taking returns from the IA. Pumped 5 bbis 60/40, 5 bbis FW spacer, 312 bbis 15.8 p Class G came . nt. Cement retruns observed -303 bbls awa�i. Shut down, shut SV and IA valve, align valves to OA. Pumped 0.8 bbls cement into OA when conductor top cement leak activated. Shut down and bled OAP, leak stopped immediately. Flushed and freeze protected surface lines. Class G cement in TBG from 8707'MD/5713' TVD to surface Class G Cement in IA from 8502'MD/5820'TVD to surface 3/22/2018 Daily Report of Well Operations V-119 TWO = SSV/270/17. Temp = SI. WHPs (eval cement squeeze). 2" hardline rigged up to well. IAP increased 270 psi, OAP increased 17 psi from 3/17/18. 3/23/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:00 TWO = SSV/O+/20. Temp = SI. WHPs (eval cement squeeze). 2" hardline rigged down from WH. Small divot in conductor @ the 3 o'clock position has - 1 tablespoon of new fluid with no active bubbling presently. Wipe dry with a clean rag. Cellar has has no new fluid inside. IAP decreased 270 psi, OAP unchanged in 20 hrs. 3/23/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 3/2512018 Cost Placeholder build of AOGCC required suspended well Marker Plate T/I/O = SSVNAC/20. Temp = SI. WHPs (eval for P&A). OA cemented to surface. Bled OA to 0 psi in 30 seconds (all gas). It is 12" from ice in cellar to bottom of circ port and 38" 5/17/2018 from edje of 20" conductor to edje of 8' CMP. T/I/O = ONAC/0. Temp = SI. WHPs (eval for P&A). OA cemented to surface. Bled OA to 0 psi in 30 seconds (all gas). It is 12" from ice in cellar to bottom of circ port and 38" from edje of 20" conductor to edje of 8' CMP. SSV is in the open position will not cycle closed. Strapped TBG cement @ 4' just above SSV. Cycled MV (23.5 turns). Installed hooch around cellar & installed heater. 5/19/2018 SV, WV = C. SSV, MV = O. IA, OA = OTG. 12:00 T/1/0=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 -10 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' deep to cellar floor. Excavation Tag hung on barricades. Work area 5/25/2018 barricaded off and Open Excavation signs out. TWO = 0/0/0. Temp = SI. Cut & Remove Wellhead (P&A). Held Well Control Drill. 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 graqe. Staged wellhead on pad and cleaned up work area. Placed 5/26/2018 around excavation and cellar. Top of Cut Wellhead (P&A). Sucked water from cellar. Mixed -20 gallons AS1 and poured into TBG and OA voids for top off. Weighed cement to see if correct 5/27/2018 rbarricades nt . Left heater in cellar. Let setup overni ht. Off location at 17:00 d marker cap. AOGCC witnessed (Bob Noble). Final pics put in Well Pics Folder on 6/1/2018 Remove Wellhead (P&A)***. Used - 35 yds of gravel to backfill excavation, backfill complete. 17:30. 6/10/2018 TREE= ' 4-1116"CNV WT3d.FEAD= FMC ACT114TOR = T4A OKB. R VLV FEF ELEV SIX BF. ELEN = 53.64' KOP= 600' Max Angle = 57' 600T Datum AD= 10180 Datum TV 6600SS 9-58" CSG. SUSPENDED u ---v = 6.835" H 3349' V-119SAFETY NOTES: H2S READINGS WHEN GE 125 ppm N MI. WELL REQUIRESAA SSSSSV WHEN ON ML GAS LFT MAPOPaS ST ND I TVD I DLV I TYPE VLV LATCH FORT DATE 6 3127 2598 55 KBG-2 DMP BK 0 12/29/04 5 4343 3306 55 KBG-2 DMP BK 0 04/21104 4 5901 4206 56 KBG-2 DM1' BK 0 12/29/04 3 7438 5094 54 KBG-2 DMV BK 0 12/29/04 2 8502 5713 54 53 KBG2 KBG-2 B43TY DMP - BK - 0 03/09/18 1027108 9865 6489 4-1/2" TBG, 12.61/, L-80-0152 bpf, D = 3.95a- PEWOPATDN S~RY REF LOG: DIAD ON 04/14/04 ANGLE AT TOP PEIRF: 52-01021(y 940T - 9429'1 BKR 45 KB PATCH, D = 2.45 S17E SPF NTH2VAL Opn/Sqz 9931' 3-38' Minimum ID = 2.45" @ 9402' 0208-10256 4 1/2' FES X NP, D:3.813" BAKER 45 KB PATCH SUSFE DED WELL 0227118 LM AD F¢SB2VOR CMF PLUG (2119/18) 03/13/18 JMGIJMD SL TAGGED TOC(03M&18) 9993' 7"X4-12" BKR R8A RCR 10021' 41/2" PES X NP, D = 3.613' 10041' 4-1/2" FES XN NP, D = 3.725' 4-112" VVLEG. D = 3.95W 4-1/2" TBG, 12.61/, L-80-0152 bpf, D = 3.95a- PEWOPATDN S~RY REF LOG: DIAD ON 04/14/04 ANGLE AT TOP PEIRF: 52-01021(y Nota: Refer to Production DB for historical pert data S17E SPF NTH2VAL Opn/Sqz I DATE 3-38' 6 0208-10256 S 02119/18 7" CSG, 269, DATE F* -V BY COMMENTS Y ODWAENT5 04/21/04 KAK ORGINAL COMPLETION D GLV aO (03109118) 08111/16 JMGJMD SET PX FLAG (08109/16) rAEN CMT OA (03114118) 06130/17 JPL/JMD ACO® REF & BF ELEV D CMT IA & TBG (03122118) 0281/18 GJB/JAD FILLEDRAPI.IIG(OV30/18) SUSFE DED WELL 0227118 LM AD F¢SB2VOR CMF PLUG (2119/18) 03/13/18 JMGIJMD SL TAGGED TOC(03M&18) 17" MARKEF T I BOREALIS LUT WELL V-119 F6iMT No: "2040410 AS No: 50-02323201-00 SEC 11, T11K R11E 4645' NSL & 1803' WB BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commis ion TO: Jim Regg art `8(i€ DATE: 5/31/18 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector PBU V-119 BP Exploration Alaska Inc. PTD 204-041, Sundry 318-009 5/31/18: I traveled to BP's PBU V-119 to inspect the cut of the well, site and marker plate. On arrival, I met with BP rep Orvill Bass. All strings of pipe were full of good hard cement. The marker plate was a 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. I found the plate to have the wrong API number and had them correct it. PBU V-119 will be considered suspended, not plugged and abandoned, as noted -- in the approved sundry. Attachments: Photos (3) SCANNED JUN 2 1 2018 2018-0531_Surface_Abandon_temp_PBU_V-119_bn.docx Page 1 of 3 • . Surface Abandonment — PBU V-119 (PTD 2040410) Photos by AOGCC Inspector B. Noble 5/312018 • ,,Ni....\ ,,,,.., RRR t . PBU V-119 cement to surface all strings; cutoff 3 ft below pad level (.1-''' r' ,.-4 ✓.`• ' J �' ti x r , . � �,' � . w 1• +: � l h' 4 €�sr . ` ` < y AaK ,.y .}f��,S X01 + y Temporary marker plate with incorrect API# 2018-0531_Surface_Abandon_temp_PBU_V-119_bn.docx Page 2 of 3 . . F j'h N Y . ' .,, Ceitve OA' , . 4',4 i ''''-44 ,:s•' " ,,,, e 3 t „}*; Temporary marker plate with correct API# 2018-0531_Surface_Abandon_temp_PBU_V-119_bn.docx Page 3 of 3 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ` 31131(6 DATE: 3/08/2018 P. I. Supervisor FROM: Bob Noble SUBJECT: Plug Verification Petroleum Inspector PBU V-119 ' BPXA PTD 2040410, Sundry 318-009 3/08/2018: I traveled to PBU V-pad well V-119 to witness a tag and test on the bottom plug as part of the well suspension. On arrival, I met with BPXA representative Chuck Nardini and we discussed what they had planned. He told me that they had pumped 27 bbl of Class G cement at 15.8ppg and displaced it with 100 bbls of fresh water. That was done on February 19, 2018. • They had a slick line unit rigged up with a 2 1/2 inch bailer and 200 lb weight bar. They ran in the well and tagged top of cement at 8774 feet RKB. Then they came out of the hole and I inspected the sample in the bailer. It was the consistency of modeling clay with small, hard lumps. It smelled and was the color of cement. -- Hot oil rigged up to the tubing to pressure test. The results were: Initial T/I/0=17 / 2 / 8 psi Pre T/I/0=1651 / 33 / 8 psi 15 min T/I/0=1593 / 33 / 8 psi 30 min T/I/0=1564 / 29 / 8 psi - This was a passing test. ✓ SCANNED Attachments: none 2018-0308_Plug_Verification PBU_V-119_bn.docx Page 1 of 1 SOF T4, • Iy/. s HE STATE T • Alaska Oil and Gas ��'a� ofALA Conservation Commission itn x=== == 333 West Seventh Avenue ofGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 GOVERNOR ALAS? Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Joshua Tempel SCANNED A ?l ; Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU V-119 Permit to Drill Number: 204-041 Sundry Number: 318-009 Dear Mr. Tempel: 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, Cathy . Foerster Commissioner DATED this 1 d of January, 2018. RBDIVIS j !,,; 1 8 2018 STATE OF ALASKA *LASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVV 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend E• Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-041 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service E 6. API Number: 50-029-23201-00-00 • 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 E PBU V-119 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028240&028245 PRUDHOE BAY,BOREALIS OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10483 • 6867 2214 2066 2214 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 30-109 30-109 1490 470 Surface 3320 9-5/8" 29-3350 29-2725 5750 3090 Intermediate Production 10447 7" 28-10475 28-6862 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10208-10256 6699-6728 4-1/2"12.6# L-80 26-10056 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and TVD(ft): 9995/6568 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary E Wellbore Schematic E 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service E 14.Estimated Date for Commencing Operations: January 15,2018 • 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended E r 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel,Joshua be deviated from without prior written approval. Contact Email: Joshua.Tempel@bp.com Authorized Name: Tempel,Joshua Contact Phone: era'T. -sct I_ s9 3 40 Authorized Title: Drilling Enrgineer / �j ,ice Authorized Signature: a-•`- y� I Date: / / ( 'S� COMMISSION USE ONLY Ci Conditions of approval:Notify Commission so that a representative may witness 2 q hi, 4 6 fi.c_ s Sundry Number: `/��) n 0 Plug Integrity BOP Test 0 Mechanical Integrity Test ❑ Location Clearance Ilr Other: p1) D G/UG/.-`li'7 z'v1 74- a.5• h O fe-G/ . awl bt--i n lS o,b� - 7<<Y.,$ \ d Post Initial Injection MIT Req'd? Yes 0 No p�—l'%Y S`n�`l S�a PP v _I u3/F-,---4÷9 Spacing Exception Required? Yes 0 No 2 Subsequent Form Required: 10' 4 U Y- 3`7 ---3-g - APPROVED BYTHE Approved by: 4. COMMISSIONER COMMISSION Date: _ .. 8 l � /iz/r8 REG IrD f oma 8' R 3DMiS ✓J; 1 c618 ORIGI . :...... JAN AOG C C Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ....5; • • V-119 Reservoir Abandonment Well Interventions Engineer: Josh Tempel (907)891-5930 Pad Engineer: Eric Zoesch (907) 564-4695 Expected Start Date: 1/15/2018 History V-119 is a Kuparuk injector drilled in 2004. The well was shut-in in 2010 due to a tubing leak, a patch was successfully installed in 2011. The well remained shut-in due to a surface casing leak. An unsuccessful surface casing x conductor top job was performed in August 2017. On 10/17/17 sundry #317-447 was approved for the reservoir abandonment and it was requested by AOGCC that a sundry for the surface plug also be submitted. On 11/21/17 sundry # 317-527 was approved for the surface plug. Both sundries were revised after being approved. The Reservoir Abandonment sundry was revised to be done in 2 separate plugs instead of 1 plug and the Surface Plug sundry was revised to allow for an OA injectivity test to check/verify the competency of the OA. The results of the OA injectivity test indicate the OA can be effectively downsqueezed which allowing a more effective P&A procedure for both the Reservoir Abandonment and the Surface Abandonment. The new procedure is described in this sundry application. The below work combines the objectives of the prior two sundries and, per a phone discussion with AOGCC Senior Engineer Victoria Loepp, it is agreed that upon approval of this sundry application, the prior two sundries (#317-447 and #317- 527) will be superseded. Current Status The well currently has no remaining value, no sidetrack opportunities, is currently classified as "Not Operable" by BP, and is shut-in due to a surface casing leak. An OA injectivity test has been performed, results indicate an OA cement downsqueeze is achievable. Objective The objective of this job is to perform a full abandonment of this well. The well will be converted to Suspended status until full-field abandonment. Procedural steps Fullbore 1. Pump OA squeeze: 115bbls of Class G cement with 50bbls of cement containing 12ppb aggregate. Cement Design -OA down squeeze BHST-40° F. SBHP - -2200 psi BHCT- 50° F Cement: Class G cement batch mixed Density: 15.8 ppg Thickening time: Minimum 8 hours (6 hr pump time + 2 hr contingency) API Fluid Loss: 80-400 cc (40-200 cc/30 min) Free Water: 0 Compressive Strength: Minimum of 2000 psi • • Slickline 2. Pull plug from SSSV X nipple. Fullbore 3. Pump reservoir abandonment, 27bbls of 15.8ppg class G cement. Target top is 9200' MD in the tubing which places cement 1008' above the top perforation. Cement Type/weight: Class G 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Minimum thickening time 6 hours Slurry Temperature: between 80° and 110°F BHST 145° F BHCT 130° F SBHP 3200psi Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Fullbore AIf, � CG t k15/ltd 1. MIT-T to 1500psi2r. -to ` r 5-5 /-4 p 2-41- 11/1 ' Slickline 2. Drift and tag TOC. Pull dummy valve from GLM #2 at 8502' MD. Fullbore 3. Pump plug #2, 308bbls of cement, down tubing taking returns from the IA. The well will be cemented in both the tubing and IA from open GLM #2 at 8502' MD to surface. Cement Type/weight: Class G 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Minimum thickening time 7 hours Slurry Temperature: between 80° and 110°F BHST 110° F BHCT 130° F SBHP 3200 Fluid Loss: 40-200cc Compressive Strength: 2000 psi 2 • • ,Special Projects (minimum 96 hours after cement in place) 1. Photo document all steps of this process. 2. Cut off wellhead -1' below pad level. 3. Top off annuli/tubing with cement as needed. Notify AOGCC for witness (24hrs notice) 4. Install marker plate on outermost casing string. Notify AOGCC for witness (24hrs notice) • Marker Plate to meet requirements i. Minimum '/4" Thick • Bead weld to the marker plate the following information: BP Exploration Alaska Permit #: 2040410 Well V-119 API#: 50-029-23201-00 5. Photograph and backfill. Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. 3 • ITZEE 4-1/16'CIN WELLHEAD- ACTUATOR= NA V-119 Current SAFETY NOTES:H2S READINGS AVERAGE 125 ppm WHH4 ON MI WELL REQUIRES A SSSV WHEN ON OKB EIEV= 81 7' MI REF El_EV 81.T BF TLEV '364 KOP 600' 1111--- 2214' —0-1r2"HES X Ntf', - 1813' Max Angle sr_as 5uor 2214' 44 1/7-PX LIG(08/109F16) 1 Tiiiu-m = — f31 -0610.1mTVD= 6600SS GAS LFT N'APCRIELS CSG 400,L 80 0 8 8S -F 3349' 1—A ST TVD DEV• TYPE VLV LATCH PORT DATE 6 3127 2598 ) 55 KBG-2 CMY BK 0 12/29/04 5 ; 43433306 1 55 KBG-2 CM? BKBK 00 04212, 1/04 I Ii 4 1 56 4206 KBG-2 3 7438 5094 54 KBG-2 EMY BK 0 12129/04 2 I 8502 5713 54 K9G-2 CMI' BK 0 12174/04 Minimum ID =2.45" 9402' 1 • . 53 KE30-2 CMI' BK 0 10/27108 BAKER 45 KB PATCH z9402'-9429' Blesit 45 KB PATCK -=2 45'(815111) I I 11931' F-4-1(2' 139$13' — r X 4-1(2-BKR PI PKR I I 10021* 1-4-1i2'Porms x NP,ID=3 813' , I I 10041' 1- 1170 XN PAP, 3 725^ 1 10064' 1—4-112'VVLEG,ID 4-1 2-MG, 1)WI,L-80, 0152 bipf r-3 95t1" 10611 •:*• ORA T1ON SUMARY REF LOG: OUAD ON 04/14iO4 ANGLE AT TOP FERF• 57 10210' • 1014$ JT __— Note Refer to Prodtrtion 1Y3 Ok:a Of historl pert data SVF SPF IstIFFNA Opn,'Se2 flA TF 3-3/r 6 102i/8 10256 B 0625/04 103667"W3RXER MID 10425' f.4101 W • • w . 26w.Lao,,0383 r 02713. 10473' 4 • • tiir CM • 1.1411.1-EAO—.7.— ACAS TOP• V-119 Proposed SAFETY 1410TES 1474 RFACIRM AVERAGE 175 win *VF%ON MI VIFI I Rf QutRFS A SS V 641-0Exo014 OKB ELEV hi r PC' IMF FLO/• 11.7' BF MEV- 1.164 KOP• • . 2 214 - I". ",sal! ] 1444 4,ngla sr 0 tcor Oman 1.4)• 1011X7 . 001•11 TVD• 66001S GAS LFT 114U ..5 M) TVD DN. TYPE VW U1Ttli POO - CAM Cement Column from 8502' ".c surface G 3)2? 25911 55 KBG 2 OW BK a 1212104 - 5 4343 3J1 5 KBG 2 CI& OK 0 04/21.04 4 5901 47C6 56 1010-2 E1.4, BK 0 17451.04 3 !4 SON 54 KIMS 2 OW BK 0 IT/2404 2 61 92)3 54 KBG 2 DPP' BK 0 1212904 Minimum ID 2.45" 94-02213E6 6489 53 KFIG. EPA( BK 0 11077.00' LI__3AKER 45 K8 PATCH 6,174'md / 4277' tvd Top Schrader 7,077' md / 4803' tvd Base Schrader „. Cement Heignt-9200' - Imar t4nr I%Telt IBM' 4-1W WS MP,O.3 sir Ng' r x 4-IVY abUI FIGEI4 MR 1 • 10021" 4-ixr x sw.1)•31117 i0434) -fa ur %PIMP,ID.,3.725'I 1,7 . C C1. I I 0053' ; 0054' J-14-ler &).1) 3 ler] FV.KQR TIQN 51.4,44CW QUAD ON 04i 144:4 MOLE AT TEPFLI4i ST Kola lbw RAM" Pacluclion IINADical ppri ce. , • 10143. 7-Ix Facm.rt WE 0111341/AL OgievSqz 1-3fit • * 10205•102S6 0 10,200'md 6612' tvd Top KuRajuk *Top pert 10,208' md • • + 4 FWD 16425' 4°4404 414.4.4.11.0 , 2"010,NO,1..410,0313 IV, rb- 104 73' 5 • 411110 law, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday,January 09, 2018 9:59 AM To: Loepp,Victoria T (DOA) Cc: Tempel,Joshua Subject: Withdraw sundry#'s 317-447 &317-527 for V-119 (PTD#204-041) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please withdraw sundry#'s 317-447 and 317-527 for V-119(PTD#204-041). We will be submitting a new sundry today to replace these previously approved ones. If you have any questions, please don't hesitate to let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 AN fi BP Exploration Alaskal900 E. Benson Blvd.IRoom: 788D1Anchorage, AK 1, 9 2 ScaH�ED �MA2r113 1 • • PTD boy- - og Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, December 07,2017 10:21 AM To: 'Tempel,Joshua' Subject: Change Request:V-119(PTD 204-041, Sundry 317-447) Reservoir Abandonment Sundry Joshua, The outlined changes are approved for this abandonment sundry. 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 o(�alaska.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.Loeoa©alaska.gov From:Tempel,Joshua [mailto:Joshua.Tempel@bp.comj Sent:Wednesday, November 29,2017 4:31 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> SCANNED Subject:Change Request:V-119 Reservoir Abandonment Sundry Hi Victoria, In reference to the 1s`sundry for V-119,the reservoir abandonment sundry. 1. While we are figuring out how to best abandon the surface portion of V-119,with your permission, I would like to go ahead and start the abandonment by pumping a Kuparuk reservoir abandonment plug.The effect of this change will break up the lower plug into 2 parts.The second part of the plug would be pumped after the well finishes going through our internal review process. 2. I'm also requesting to change the pressure test on the 2nd plug from a CMIT-TxIA 2500psi to an MIT-T 2500psi. After reviewing the potential for subsidence damage on this well I am very concerned about damaging the production casing and causing problems for the remainder of the abandonment. These changes have no negative effect on the competency of the abandonment. I've attached a redlined Sundry with the proposed changes and I've cut and pasted the diagrams below. 1 • • , Please let me know if you have any questions or concerns on these changes.Thank you working with us to get this well properly P&A'd. Nil 4 1 ?e fYlr _.. 7 AL"�11ia!6 . Imo. [TY GSM p11 as WaafQPp.TiwfTa a 007 tf1Y• Otr ' MM Mtti AKyYeK.1<V0* ler 6A1* Ot.l' M MN- IAIM': .77.- pd ( i71r ..,,•r=.vav-a-7111 w Ate. it 00007 Iwr.N D• IOW' 9.9 P•17* MUM .... a C a'N a't .... US+.! ..Mat*,•. C)�N'i AOr' 4 laic.. 1r. ...,*. * ',7.7*,. s 430 m;a!,vox VW at 0 fOYN 4 Cent Hetht'T�SOQ' 4 Moe UM, T1-.room 1 ow Off 0 f7PMA I..4711 WWI VI 4a07 OM' PK 0 0790+. ' *XO 17,7 14 VI07 el M 0 17rIIM.a Aluie wm 10*j.45-a 4407' , won,bf1 a 414r+7 We i41 i 0 ',O.'"°' BAXER 45 Ko PATCH 6,174'md/4277'tvd Top Schrader 7,077' and/4803'tvd Base Schrader '- :, a4 rate-sa-r--i�-i I 0031' s I1Y1l11 A1l,11.Tiff, -_ ' V►14 -.«tA'*,i(IOeiYCllaiell I 1::‘,.4trrii11/0!111ri 10641 1 1.-.9':ry N...1...!!!!"1 ♦4:1",...94-1;to,,No ,,a'.Irl I. i rail y 1009/ , 1001A ,;'IN fi 71711-] 41*LOG gout OM0VNuI Aia><t AP'tram. iT0KIM '1''' d ' Wei."c"°` G T+7YA 10,200'md/6612'tvd Top Kuparuk r 'Top pe:rf 10,208'mt! 9 �14•4- I Vri<CM --, iii-Piir— -fie ACRMMA. ,,,,,, t'-119 Proposed 79POTS 11 d1 aM abt Ora gar. 147'`. M no. 1.1 e,r' I *ry<. 477I.` { ..._.. VW Mew. 10'1067^! . ... t1A.YI. PPM i7as N[7. IPOPPIt tA*'0 r, 1MNLs Cement Mt t'i500it w' :r an Twee n1. v f►1•;, pR`, a Iva'AN'!Y'OIG 7 Of, -<''' 7 a7 M VOCr. UV* OA 1 l_...Y i 1 '•711API"/#6f* 14 Mr+t Sm1M 0[ f'- -- 7 aem'.vii 11 V1rs7 W' na 4 I r,M mmtea o.2 -e'( " L a 9a4`K4 43 Vit-. CM `: 0 s .l.r. BAKES 45KRPATCH .•'?i ` ;,t 6174'md/4277'tvd Top Schradef Mii 7,077'and/4803'tvd Base Schradei Cern ent$eoght'92o0' i NN,I, +r soil!:+!.!,-irs,44ho�►+a.o•r•roir ai, . 4_____ Msl[ 11.11 .f11 O.1Nr( Mtm LO.0044100*W11 7 60471' n111/0.1111., y Oil tC4 01.04211•00r141.0*•lel t A7 RO'aTM it 0 sum P ,/ s 11,Ii PYP.11 NOA1'in al lw•P.p.! *4.1. IP,—f .w _. r"".. 11Ji 1 dYi T.iiW._ K/ilerai... ._..P ,..._ a,4j 7 e" taxi T'�B° o ,f',x, " Fti 4 A 10,200'rod/6612'tvd Top Kuparuk 1 i" * i' : s i *top peril l0,208`and 2 • Regards, Josh Tempel GWO l BP Alaska I Well Integrity Engineer I Mobile: +1 (907)891 5930 I Office 742A 3 • • by 0 V-119 Reservoir Abandonment Well Interventions Engineer: Josh Tempel (907)891-5930 Pad Engineer: Eric Zoesch (907) 564-4695 Expected Start Date: 10/1/2017 History V-119 is a Kuparuk injector drilled in 2004. The well was shut in in 2010 due to a tubing leak, a patch was successfully installed in 2011. The well remained shut in due to a surface casing leak. An unsuccessful surface casing x conductor top job was performed in August 2017. Current Status The well currently has no remaining value, and no sidetrack opportunities, it is currently classified as "Not Operable" by BP and is shut-in due to a surface casing leak. Objective The objective of this job is to perform a reservoir abandonment on this well. Procedural steps Slickline 1. PuII TTP Miine- Fullbore - - -- - -- - ,,' ..r . ._ ,dump reservoir abandonment, 1 fObis of 15.tsppg class G cement. Target top is 9200' MD in the tubing which places cement 1008' above the top perforation. Slickline 4. Drift and tag TOC. Pull dummy valve in GLM #2 at 8502' MD. Fullbore 5. GMIT-T NOM 1500 • Cement Type/weight: Class G 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Activity Time(hours) Shearing time,quality control, PJSM 1 Cement displacement 2 Cement contamination 2 Safety Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3500 2:00 140 3500 3:00 150 3500 4:00 160 3500 7:00 160 3500 15:00 160 3300 Fullbore Pump plug #2, 102 bbls 15.8ppg Class G, by circulating through GLM#2. Planned TOC is —5500' MD. Cement Type/weight: Class G 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Activity ime(ht. Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 1 Safety 2 Minimum required thickening time: 2 • • TimTempt: sur(. (°F) (psi) u:u:. 70 0 0:30 100 2400 1:00 110 2400 2:00 110 2400 3:00 110 2400 4:00 110 2400 5:00 110 2400 6:00 110 2400 Slickiine 3. Drift and tag TOC. Fullbore 4. MIT-T 2500psi 3 • TREE= 4-116"CIW WELU-ED= v-119 Current SAFETY MOTE:1125 READINGS AVERAGE 125 ppm ACTUATOR= NA WHEW ORM,. WELL REQUIRES A SSSV WHEN ON OKB ELEV= 81 r Mt REF BLEW 811' ELEV 53.64 KOP 600 wilt_ I 2214' 1-1' /2-His NIP,K3=3.813' I Max Angie= 5r 600P —4 2214H4117*PX OG(08,Ogn8) Ltaturn MD= 10180' Datum TVD= 6600SS GAS LET MATCRH_S Lt518" 40a.L-80, 8.835 I 3349' 1--A ST' M) 1VD DEVI TYPE VLV LATER PORT DATE 6; 3127 2598 55 KBG-2 OW BK 0 12r29,04 43435 330655 KBG-2 DiwBK 0042 4 5901 4206 56 KBG-2 DRY BK 0 12/29/04 3 7438 5094 54 KBG-2 OW BK 0 1229/04 2 8502 5713 54 KBG-2 DAY BK 0 12/29/04 Minimum H) =2A5" ri 9402' I • I 9865 6489 53 KBG-2 OW BK 0 10127/08 BAKER 45 KB PATCH 9402` 9429' Ham 45 KB PATCH,ID=2.45'(8/5/11) I 993V H4 112*PEFS X NP,ID-3 8i3 j—r X 4-1/2.BKR PRIEM PKR I I 10021* H4-112*HE X NIP. =3 813" I I I. 10041 - -1/2 NPS XN RP. -3 725 1 44 1 I 10064' H42-1ALEG,II=3.958' I /1-1/7 111u,17 8#, -80, 0152 bpi, -t 10053' PERFORATION SUFAVARY IF LOG: GLAD ON 04/14/04 ANGLE AT TOP PERF: 52"o-, 10210' ' MARKPR sr] 1`43te.Refer to Prod4ction DB for historical pert data 10143 SVF SPF INIFFIVA OprilSq7 MATF 3-318" 6 10206 10756 0 ncy5in4 10388' I—7'?MAKER /4311.) H 10425' I 4444.04.44 CSG,2130/,L-80.,0383 bpf 276"-1 10473' /4.4.414.4.41+.Olt!4.1 1:411 4 S • 043. 4 V IE LAN 15%@LHEAD 14C V-119 Proposed Iwo r15; 1171,441,424Wgi AV11144114 1 rs ACTUA TOR- 40N Mt WEi kk OLAALFR 4SSSV WeLk N(302. 100 H LV 61 r 'REF @LEV• 61 1 01%, 63 64. ,KOP I I 1214 4 t rir 91 11141—1 16.11&4 Angie r^ srODIT 106600.4)- 10100 im,iVO- 460752, GAS Lin FAANCEELS TVD 0II/ TYPE;VtV tATC31 MAT 0011E Cement Height—5500 6 312? 2200 56 K80.2 OW OK 8 12321404. S 4343 3335 56 103G-2 1144 0 002004 4 55421 4206 56 KM 2 OW OK 0 1212044 3 24311 MIA4 54 IK (M BK 121731134' 2 6302 5713 54 KEG 7 OW BK u 11f29414 Minimum ID=2.45- uv, 9402' vt,,, Mit 11104 t us.;f BAKER 45 KB PATCH 6 1741md / 4277' tvd Top Schrader 7,077' md /4803'tyd Base Schrader Cement Height—9200' elr-**2-ra sum-mar HEM 45 88 MICR c.x 2 45'(8f3111) I ; 01131' 21113'1 0033' I r x ia• s406H464 10021, i4 L7 ifs x pip 3 air , 10041' i 14 1,•N IS. 4 1 0054' I t fa 141; DP,/tto 991" 10053' FUE-ORMION SUIPAVAIT1 REF LOG 01.11,D°NM/14.04 ANOLE AT TOP POP sr 0 10210' FAB*atfor M Rothmeier.lB 1nr haiiteroal pontl sistr p 1 10147 wit6ER,77 Sl7F SPF NTEAVAI OprdS42 MIT 3.361" 5 10208 102% 0 05/25234 10,200'md / 6612'tvd Top Kuparuk 10368 NV, r *Top perf 10,208'md ••••• •ye ‘, rci 2817J-110,0383 to.53 02/8* FLIo4rx AAk°10. 5 • • i = 4-ins'aw WH JFAD- FAC JETT NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= PN �7 1 7 1440.r�osy C1icB a.Ev 81 7' 4E ON NIL WELL REQUIRES A SSS V WHEN ON REIF ELS/ 91.r —�-- BF.aEV- 53.64' !NOP= 607 f 2214' 4.112`1465 x nv,in-3 a 13- Max Angle• Sr Q 600?' lOetunMCl __... 10140• IkeunIVO A._... 660055 43A6 LFt MAWIRELS (9 53 CSG 40*L-8a,ID-8.835• -- 3949• 1 111-17 hD TVD DEV TYPE vLv`LATCH PORT OATS 6 3127 2596 55 0203.1 OAM BK 0 12t2904 5 4343 3306 55 KUG-2 OWBK 0 040104 Cement Height—5500',\� 4 5901 4205 55 K33Cr2 CAW BK 0 12/29034 3 7430 5094 54 090-2 OM' BK 0 12!29004 ': 3 2 5502 5713 54 :KOC 2, OIVh' - BK 0 12/25004 Minimum ID=2.46"fa 9402' . F. ' 1 9965 6469 53 k ;2 4 W HK 0 10077109 BAKER 45 KB PATCH q,y 6,174 and /4277' tvd Top Schrader p 7,077' and /4803' tvd Base Schrader 940T-942T --IBWR45 G4 fi1O-4ID-?45'0/5111) - • MOT I-4r x 4-ire SKRR MGM R+Ot J 10021' HI Ur HES X RR 0.3.eir I 10041'j--[4-1/2"NES KR NIP,0.3 773* (4-11$'113G 12.84,480,.0152 bpl.93=3.966'J-{ 100W...I --, ' 1-141.1)7 ACM RFF LOG 4]I9tOOW04114104 ANGLEAT TOPPOEF: 52'A 102117 tote:Refer b Redueiion OB to h hared pelf data 10143' r WIRER Jr SIZE SPF i NTERVAL ' 3.3>� e � 10200 10256 �Q°0 04 10,200'md / 6612' tvd Top Kuparuk *Top pert 10,208'and 4444.. 4__444 • iu om 10424' (r G.nick.ee.03ea epr,0 r e 2rr } { 10473 } �4 c 4 us. 6 • • •Loepp. Victoria T (DOA) From: Tempel,Joshua <Joshua.Tempel@bp.com> Sent: Thursday, December 07, 2017 12:19 PM To: Loepp,Victoria T(DOA) Subject: RE:Change Request:V-119(PTD 204-041, Sundry 317-447) Reservoir Abandonment Sundry Follow Up Flag: Follow up Flag Status: Completed Thanks! Josh Tempel GWO I BP Alaska I Well Integrity Engineer I Mobile: +1 (907)891 5930 I Office 742A I From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Thursday, December 7,2017 10:21 AM To:Tempel,Joshua<Joshua.Tempel@bp.com> Subject:Change Request:V-119(PTD 204-041,Sundry 317-447) Reservoir Abandonment Sundry Joshua, The outlined changes are approved for this abandonment sundry. 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( 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.Loeop@alaska.gov From:Tempel,Joshua [mailto:Joshua.Tempel@bp.com] Sent:Wednesday, November 29,2017 4:31 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> • Subject:Change Request:V-119 Reservoir Abandonment Sundry 1 • • .Hi Victoria, In reference to the 15t sundry for V-119,the reservoir abandonment sundry. 1. While we are figuring out how to best abandon the surface portion of V-119,with your permission, I would like to go ahead and start the abandonment by pumping a Kuparuk reservoir abandonment plug.The effect of this change will break up the lower plug into 2 parts.The second part of the plug would be pumped after the well finishes going through our internal review process. 2. I'm also requesting to change the pressure test on the 2nd plug from a CMIT-TxIA 2500psi to an MIT-T 2500psi. After reviewing the potential for subsidence damage on this well I am very concerned about damaging the production casing and causing problems for the remainder of the abandonment. These changes have no negative effect on the competency of the abandonment. I've attached a redlined Sundry with the proposed changes and I've cut and pasted the diagrams below. Please let me know if you have any questions or concerns on these changes.Thank you working with us to get this well properly P&A'd. 2 •4111. 4 4 W CbV 0 4111.114,40• illie. IIIIIIIIIIIIIIII -114141 ORM.NMI 1111111•111014140WOME 4111 pp* 411444.4111, t• 1.1401.11 11•11••••1111111”1:11011144114 . Ara 44144, *I r r - ew. it W 414".•.- 11011 .14/4, fe30 i 11...............r71-aTAAVIiiiIIIIP EP.saw i w...Amp• /''a WE, Ala.YID• IOW illbs TWO• WOWS& ' . CAS 01 4 44.411111.1 W, 1 r di. '. ?We:A-444 2'61/1* L.1.6r,. 'A- *211.-2 11W MK * 1,A Cement Height-5500..„ Ea • son WA, w wc.2•ON Illw 0 LA710:4 11 1 MU 14414 1 w usb4 111114 Mk 0 4244.444 loos 4'11,u .s..1 41 ar, 010 . ., 1 monorrawn io.246"0 10442' I , ... •, 1 4 141111. 6011 BAKER 45 KB PATCH 1 6,174'md/4277'tvd Top Schrader ....„.',,...;,tt , 7 077' end/4803'tvd Base Schrader ,.7.,.44,....: --'147,---firaris r-iiirmict-Wizies,...,• ;*„,,,,...-- -- •[-11160-144.4.ar me A 0IP a•I win oer SI* A"); Ulf.girl AMMO----1 lAii—•.----nolialt tip a•3 sir I Leone .:-:•-lir-iiiiiiiiiii-ti;iiiil toor too look Loa allt WA D.liar i-E-406-11-. I— 141•41411410114 NAPO, 1 Ali LOG OILAIKIAIIIIVI4**4 AJC11 Al I ' ll ST.,,,,,,,, '..let,.....,;'ft, I .,,,,,,. AI**A****go.Ww.w•WM Ler AbbrALAI pm,*** 11.•„St'Air*** 'L - 1 44". 1 ' 44.443k Ic.,..416' 0 ' L4..,(6,4,4 :.*,-." '4': 10,200'md/6612'tvd Top Kuparuk • , Ip pert 10,208'rnti 1'. ow- 4 virtu WWu4iai:-- OW v_ii9 proposed D iiR111 411111111114424 avnwat ws yr. NA p0101 INALLANKIWII At***vow*or ram n or., I.+" WO'LW• w, _, ... ,---...... 40 to . t)la .4.0.. a* I it., --1 1141' }-4.41.•IS 6 A Nfe _ tba**/*A• ar*PO LAAA•41,1,. V*** AMA.*WO- *10714 411411.14 4•10111111. A : irTTIVA_.;:taki 7 641-74v. ip, *off-fiply' Cement He g*t^5500' „ ,J, ''''''',...• 1.-D1 .. .,,u 4 HI 44 .00 4 11414 04 4 0.17,44 *A . .I OW AA 1 II iCiti %I AILL2 PM IP. 3-'1/ 14 kw.: caw w .,0 u.........-. 11111Almuon ID.2.46-.1O2 , -.. ...01 4......, ...., .8.,7 4)WA t. NAM 4$K.PATCH P.A..' 'k, 6,174'md/4277'tvd Top Schraclei ' *iitio*Z. 7,077'md i 4803'tvd Base Schrader T.,.. Cement Height-9200' ""••••-.16161 MOT 1144, r-‘0, ---i 0111 'f4f*""A 44'P•1*'''.7. "421 ,.4 VT 41**V D.USW 4 w,,,, ,.',..i.r wt...ow ID•i A. Fr..Pric.V ii•,4, ,.....,,W I ,e,,,, teX,1) 1 ', 4 iiii-or ;-L.L.7.Liro_i_oLti.•08-j . . • — nottottoo woo,- WV Lif.' 01216.11 f:All 0*-1-.A.A Ailk I A I 414111111 1.7•*a2A1 • 10141 2,11.0,-01***-- $11.Me*.A.P•aewber,£044•4 4.44.11dirl,04. 0.1 T 04,- moo.. 4...1.0 up.Pi. 10,200'md/6612tvd Top Kuparuk I . . .. , •• •Tcp r.,,,i•ifI 20,. n,,,, _......_,...„. • 3 • • Regards, Josh Tempel GWO BP Alaska I Well Integrity Engineer I Mobile: +1 (907)891 5930 I Office 742A 4 • • Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday,January 09, 2018 9:59 AM To: Loepp,Victoria T(DOA) Cc: Tempel,Joshua Subject: Withdraw sundry#'s 317-447 &317-527 for V-119(PTD#204-041) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please withdraw sundry#'s 317-447 and 317-527 for V-119(PTD#204-041).We will be submitting a new sundry today to replace these previously approved ones. If you have any questions, please don't hesitate to let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-8496 Office: (907) 564-4091 BP Exploration Alaska1900 E. Benson Blvd.IRoom: 788DlAnchorage, AK SCANT `,i Loepp, Victoria T (DOA) From: Tempel,Joshua <Joshua.Tempel@bp.com> Sent: Thursday, December 07, 2017 12:19 PM To: Loepp,Victoria T(DOA) Subject: RE:Change Request V-119(PTD 204-041, Sundry 317-447) Reservoir Abandonment Sundry Follow Up Flag: Follow up Flag Status: Flagged Thanks! Josh Tempel GWO I BP Alaska (Well Integrity Engineer I Mobile:+1 (907)891 5930 I Office 742A From:Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, December 7, 2017 10:21 AM To:Tempel,Joshua<Joshua.Tempel@bp.com> Subject:Change Request:V-119(PTD 204-041,Sundry 317-447) Reservoir Abandonment Sundry Joshua, The outlined changes are approved for this abandonment sundry. Thank, Victoria Victoria LoeppA Senior Petroleum Engineer %We) State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From:Tempel,Joshua [mailto:Joshua.Tempel @ bp.com] Sent:Wednesday, November 29,2017 4:31 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:Change Request:V-119 Reservoir Abandonment Sundry , 1 • Hi Victoria, In reference to the 1st sundry for V-119,the reservoir abandonment sundry. 1. While we are figuring out how to best abandon the surface portion of V-119,with your permission, I would like to go ahead and start the abandonment by pumping a Kuparuk reservoir abandonment plug.The effect of this change will break up the lower plug into 2 parts.The second part of the plug would be pumped after the well finishes going through our internal review process. 2. I'm also requesting to change the pressure test on the 2nd plug from a CMIT-TxIA 2500psi to an MIT-T 2500psi. After reviewing the potential for subsidence damage on this well I am very concerned about damaging the production casing and causing problems for the remainder of the abandonment. These changes have no negative effect on the competency of the abandonment. I've attached a redlined Sundry with the proposed changes and I've cut and pasted the diagrams below. Please let me know if you have any questions or concerns on these changes.Thank you working with us to get this well properly P&A'd. 2 • 0 • • flit. 4.4-lecitY -WEigirm0-7--fite OtIT SIMkW illtkalmolot annum o*tor mato)011. Pm 0101.1 111111,tteeteri.i.re mewo. no.t.fitY^ st r _ Off .&IV• itt 7 et an,- !6144 • WVI VW j- ii tho mmo• Sr ott moor iit.a•IND. IOW' Cow IVO. AWS.1.• 814941,0 FAVIIIKA . 4 .r r'r ., tt•:-"T; :it — S 4.1112 U* SA. mr.,:. two IIK I '011101, Cement Height—5500'..,_ Mr .1 1 stet axe: It Or;7 -IW W II II2fA101: . VI IPI...2 11,‘ IA 0 1 wool I i rxeotsa ':1AIleivaem ID.2Ar.DOT 1 fl,,,,,,,ts:A, :, or% OAK 11 KISC.... fa* IRrt ', I VW t+I BAKER 41 KB PATCH i 6,174'md/427T tvd Top Schrader 7,077md/4803'tvd Base Schrader Pc -4! f I:on—,.r:11.7--,1 •ek 0,7,..1qpi I..,:.4• . • •.•.1.-!.-.I7.7:47jr):Irj ,:.!vr WI,11,11.LAG.0.5W W li••..,,,, 1 Z05./, i 11014 , .I2•.7..,I.f/Ca II.*1 AliEj PiPtOPOOOM PAMPA, las LOC,OAS ONCAI40I AKILA Al torn* 57 IIII WSCI NW AW Sr AsWilefe no tt Nielp.•AI pm,Olga , . , -lor." 6 • Iclei..e...ts' 10,200'md/6612'tvd Top Kuparuk *Top pert 10,208'rod -41 4t,w ors — if . i*Mei.MO otmoomtilotriPOMM 4:-Iti•,A- AS, V-1,19 Proposed .111 4444 44414419 M Mir Worm Om 0.4,1111V' If P. 21.-4I.• tit' PO ao,- 4)14; VW• WC', 0 '—f t. 1/-1•04, WA AI- WWI W...p.,•.`C.,- Gottms Witt/litittelt . 707).0j._tig_l_64(OjikM!IlortOSOf no,t CernHeg ; 5w ent -5 ' ,-niriit-teat- .. '% C7i1 1.3AI SI IqtAt: 4 .41}1i 4}0 A , I NIA;WM SI KM.7 eli. /a ' •••••-4 rilirtIment ICI.2Ar 6 11402- . . . . ., toe ttta .1 i!IMRE*44 KS PATCH 6,174'md/4277'tvd Top Schradet 4,..„1.-1 7,077 and/4803'tvd Base Schradet Cement Heiht-9200' 4 0111 ..... , - --- NOT,ster-l-Lotolletatttlettp,t tortvelti j iii*' 521' ...., 1 ., .,. ,1.6.411.4:11i01 - 1t X41 . •. ..... . li-i7i-iii,a--6-6,-.74-4.0,-- •,--i-,—.~-7., :., .0c43- i :1,2."St -H ‘..1.41' c*,•,..1.4'...• 40tOMmttios KOttovor '.,4')' '‘.% FP:on elite cit0•1•01 ....4'1 *MI Al PCP AA SP AKa.III., a P., -","'It' w ..,-{-16-144.- ',womo)4...• Irmo mow to IAIW law 121 No..04.•ewe,4.11a 1.11.1 1 I-SO INIIIA,.: 6WWIls/' EA II .i..744#i"WM Iter" t ' exc.e...nt° O . alo•ota ',e '. , 10 200'md/6612'tvd Top Kuparuk 1 , :.;•;‘,€j.44,; •Top pert 10,208'and 3 • Regards, Josh Tempel GWO I BP Alaska I Well Integrity Engineer I Mobile: +1 (907)891 5930 I Office 742A I 4 ti OF Tx • • • s., THE STATE Alaska Oil and Gas ;,;,- i � of e T e csConservation Commission � 1 1L1 ��'�l l .�z 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Op Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Joshua Tempel Drilling Engineer BP Exploration(Alaska), Inc. SCANNED JAN 0 9 2018 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU V-119 Permit to Drill Number: 204-041 Sundry Number: 317-527 Dear Mr. Tempel: 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, Hollis S. French Chair DATED this Zk day of November, 2017. 7 ;a-73 L k--f ,eta 2 2 IIP STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVIIII 20 AAC 25.280 1175)I7 �nI c� i� (al/71. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Ni tldn6shatlin❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Chan A .rov d PPr'o1►grra'mm 0 .. Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other �r�d( ,. 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-041 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service 0' 6. API Number 50-029-23201-00-00 ' 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 EI PBU V-119 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028240&028245 ' PRUDHOE BAY,BOREALIS OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10483 6867 L 2214 2066 2214 None Casing Length LL Size MD TVD Burst Collapse Structural Conductor 79 20" 30-109 31-110 1490 470 Surface 3320 9-5/8" 29-3350 29-2725 5750 3090 Intermediate Production 10447 7" 28-10475 28-6862 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10208-10256 6699-6728 4-1/2"12.6# L-80 26-10056 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and ND(ft): 9995, 6567.70 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0' 14.Estimated Date for Commencing Operations: December 1,2017 - 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended EI ' 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel,Joshua be deviated from without prior written approval. Contact Email: Joshua.Tempel@bp.com Authorized Name: Tempel,Joshua Contact Phone +1 907 891 5930 Authorized Title: Drillin Engineer Authorized Signature: ,J" Date: ///6,// 7 �r®� COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: • cr�J Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance tr' n ;11 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 NoI SSubsequent Form Required: /c 9 APPROVED BYTHE Approved by: dig-----1COMMISSIONER COMMISSION Date: t` 1'11 a 1/7- i i 11.7---1 i�- 0 RBE:LS (A. L':.: 2 :, 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate rra'_,, �'., /( /f7 tIP bp • S V-119 Suspend Well Interventions Engineer: Josh Tempel (907)891-5930 Pad Engineer: Eric Zoesch (907) 564-4695 Expected Start Date: 12/1/2017 History V-119 is a Kuparuk injector drilled in 2004. The well was shut in in 2010 due to a tubing leak, a patch was successfully installed in 2011. The well remained shut in due to a surface casing leak. An unsuccessful surface casing x conductor top job was performed in August 2017. Current Status The well currently has no remaining value, and no sidetrack opportunities. V-119 is classified as "Not Operable" by BP and is shut-in due to a surface casing leak. *Reservoir abandonment from prior sundry is planned to be performed by December 1st, 2017. Objective fi^d o� 3(7-yr7 The objective of this job is suspending the well by placing a surface abandonment plug, removing the wellhead, and welding a plate on the well. Procedural steps Eline 1. Perforate tubing and production casing from 1490'-1500' MD. Fullbore 1. Circulate hydrocarbons out of Tubing, IA, and OA. 2. Cement Tubing, IA and OA by pumping the below volumes of 15.8ppg class G cement. • Tubing = 23bbls __" • IA = 28 bbls • OA = 43 bbls • Excess = 20 bbls Total cement volume: 114 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to be equal to lab +/-0.1 ppg Slurry Temperature 80° to 110° F API Fluid Loss 40-100cc (20-50cc/30 min) Compressive Strength 2000 psi in 96 hrs Thickening Time Minimum 5 hours • Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 2 Cement contamination 1 Safety 2 Minimum required thickening time: 5 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 76 90 1200 1:00 114 80 1200 2:00 114 70 1200 3:00 114 60 1200 4:00 114 50 1200 5:00 114 40 1200 Special Projects (minimum 96 hours after cement in place) 1. Photo document all steps of this process. 2. Cut off wellhead -1' below pad level. o h /1-°4-7e° �� — w, f K? 5c ho , f-� 3. Top off annuli/tubing with cement as needed.— /t/ 4. Install marker plate on outermost casing string. -- • Marker Plate to meet requirements i. Minimum 1/4" Thick • Marker plate should have the following bead welded: BP Exploration Alaska Permit #: 2040410 Well V-119 API#: 50-029-23201-00 5. Photograph and backfill. Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. 2 !Het.= , 4-1/16"aw WELLHEAD= FMC • V-1 1 9 SAFONOTEB:H2S READINGS AVERAGE 125 ppm ACTUATOR= NA WHEN ON MI. WELL REQUIRES A SSSV WHEN ON OKB.ELEV= 81.7" MI. REF B_EV= 81.T BF.ELEV= 53.64' KOP= 600' 2214' —14-1/2"i IM X NP,ID=3.813' M3X Angle= 570 @ 6007' I1B11 , 2214 I—4-1/2"PX PLUG(08/09/16) Datum1.13= 10180' - Datum TVD= 6600'SS GAS LFT MANDRELS 9-5/8"CSG,40#,L-80,0=8.835' H 3349' k ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3127 2598 55 KBG-2 DMY BK 0 12/29/04 5 4343 3306 55 KBG-2 DMY BK 0 04/21/04 1Li 4 5901 4206 56 KBG-2 MAY BK 0 12/29/04 3 7438 5094 54 KBG-2 DMY BK 0 12/29/04 2 8502 5713 54 KBG-2 DMY BK 0 12/29/04 Minimum ID =2.45" @ 9402' 1 9865 6489 53 KBG-2 DMY BK 0 1W27/08 BAKER 45 KB PATCH IS . 9402' 9429' H BKR 45 KB PATCH,13=2.45"(8/5/11) Z. E I I 9931' i—4-1/2"HES X NIP,13=3.813" 7‹ X 9993' —r X 4-1/2'BKR PREM PKR-1 I I 10021' ---14-1/2"HES X NP,D=3.813" I I 10041' —14-112"HES XN NIP,ID=3.725" \ , ' 4-1/2"TBG, 12.6#,L-80,.0152 bpf,13-=3.958" —1 10053' / 10054' 1-14-1/7VVLEG,D=3.958" PERFORATION SUMMARY REF LOG: QUAD ON 04/14/04 ANGLE AT TOP PERE: 52°@ 10210' N3te:Refer to Production DB for historical perf data III 10143' H 7"MARKER JT SIZE SPE INTERVAL Opn/Sqz DATE 3-3/8" 6 10208- 10256 0 06/25/04 • [ 10368' —7"MARKER JT 1 R3TD —1 10425' 11111V1111 ...•.•.•I•.1....I**. ..........4 k4.04.4.4.0.0. 7"CSG,26#,L-80,.0383 bpf,13=6.276" —1 10473' DATE REV BY COMIENTS DATE REV BY COM.ENTS BOREALIS UNIT 04/21/04 KAK ORIGINAL COMPLETION 08/11/16 JMG/JMD SET PX PLUG(08/09/16) WELL V-119 06/25/04 LDK/KAK PBRFS 06/30/17 JNJJkil3 ADDED REF&BF ELEV FERMT No: 2040410 02/15/11 Ivf3/JM) ADDED SSSV SAFETY NOTE AR No: 50-029-23201-00 08/15/11 SRO/PJC SET PATCH(08/05/11) SEC 11,T11N, R11E,4645'NSL&1803'WEL 09/21/11 JOIN PJC MN ID CORRECTION 01/19/12 Tri&VJMD ADDED I-QS SAFETY NOTE BP Exploration(Alaska) . S • Post Reservoir Abandonment TRH-= 4-V16.CON I YsILLHEAD- RC SAFETY NOT1425 READINGS AVERAGE 12.5 ppm ACTUATOR. NA V-119 VIHDI ES ON NC WELL REQUIRES A SSSY WHEN ON OKB REV= Sir Ml. !REF mei• sir 1BF B_EV. S364 KOP- 600 P II---, I 2214' --4 I-.7,-HF---9 x MP ED 3 1 MIA Are- 5 r a,eqor Illuturn RC mei. [Datum IVO &&XV.5 GAS LI-1 1.4V43E1S 1 -S.,:1'L,',G 4CiA ,60 U 5 d)t 3.349' 1 A I ST he -TVD r cei TY FE -VLV LATCH ECM DVTE 6 3127 2586 55 i KBG-2 OW BK 0 1212904 Cement Height—5500, I il 5 4343 33E1i 55 K13G-2 CM BK 0 040101 4 5901 4205 56 ,, KEG-2 (.W BK 0 12/20434 3 ran sow 54 1 000G2, LA,.., BK o 12r2oms : ., 2 6502 5713 54 ° KB0-2 LAP, BK 0 12729434 ! Minimum ID=2.45"fa 9402* . . , I 9564, 6489 ',3 , KEIG2 IA. BK 0 1E327G8 BAKER 45 KB PATCH ., .- .,,, . 6,174'md / 4277' tvd Top Schrader 7,077' md / 4803' tvd Base Schrader , ,a4 NOV-1142V 1-10KR 46 KB PATO-I.LI=2 45 48)501) I 911131.' H4-ur Hes x Pap.D.3 sir I WSW r x 4-irr oxRPIREM PKR '' ' , I 10021' H4-1 rr KM X PIP.I).lair 1 , 10041 4 VT HES%NW,0•3 723' I . . [4-vr 186.12 ON,1.-so, ols2 bpi 0=3 9i.9- 1 0053' 10064' }-4 1,7 Vsi FG 0 3 g•se"i •. i FiliFOR1110,454.11MPARf „ REF LOG QUAD(8 104114/01 ,..ikI APCLE A T TOPiT RIF Sr a 10210' ,_ 14:44 Reef bo Production CO lor Kalamai pail dais '4;.., ,, i .t . 1 101 —1 r W4PKER Jr Si2E SFW: NTERVAL 'OpKGEII CATE 3-3Ar 6 I 1020e-102% , o CE/25004 1 • 10)200'nrid / 6612' tvd Top Kuparuk J 1 *T o p perf 10,208' md ,7:... - ..14 . A .115 •,, 1 Pew i— 10425' J ' 01111 = • 4.4.1.•• PA r coo.zee.L so 0363 W.o-8278 1o4177 — ' 3 Post Suspension TTEE 4-1/16.CON MELLHEAD FAC V-1 1 9 SAFETY NOTES 1125 READINGS AVERAGE 12S ppm ACTUATOR• NA, Cement Depth AMEN ON MI WELL.REQUIRES A SSSV WHEN ON 0003 = sir I REF HEV• atr1 -1500' 01 El EV >3641 r KEA' ll • - 2214' j--(4-yr i x.4.111•3111r 1 .11,41e. 5/ 4 600, Daum 64) 10180' MAIM IVO• 660055, GAS LFT!MANDRELS I 9 SIT CS4' ILA L SL' u 6 3349' ST AO IVO DEV WEE VLV LATCH FORT GATE 6 3127 2503• 55 KE1G-2 C6111 MC 0 12r29,04 1-4 5 4343 3106 55 ICBG-2 mar OK 0 04/21c4 Cement Height-5500 4 5901 4204 56 KBG-2 OW OK 0 12/29004 • 43 3 71 5084 54 KEG-2 CAW 13C 0 12179.04 ,et • t.,Aiiirr.•• 2 6502 5713 54 K83.2 CM' BK 0 12/2%04 Minimum ID =2.45" 9402' ,%$4,I 1 9865 6469 S 13G 7 04.11' BK 0 10127038 BAKER 45 KB PATCH " * 6 174'md / 4277' tvd Top Schrader .I4'4'0 7,077 md / 4803' tvd Base Schrader • 8407_D429' 47 KB PAR3-1. + 11 1 911110M1—{4-11T HES X NP,13.3 sir eaff fr x+i-ur SKR PIVE40 PKR ( 10021' H4-1/2-FES X Ali,El.3113' 1100,' 10041' 1/2'HES XN0ip 0•3 726' \ itr+Atm D.3 9511- 14-yr ma 12 6A ir ao 0w,2 =3 our 10053' ' ' PEWORA TM%WART REF LOG 01.140 ON 0411404 '0* • 1. 0 APIILE AT TOP FERF SFfl 10210 , 10143 —ir RaER Jr tete Refer lo Producing+DB lor 044130c41 pert Pala SIZE SPF 14TERVAL Opn/Sqz GATE 3-3ir e I 10206 1(256 0 0612901 10 200'md / 6612' tvd Top Kuparuk 10386t vAPAC,-.1 *To p perf 10,208' md . • I Rot, 10425' 0$1.1.4.• ft**. r 1041r , 1,14 III ircsa.rivIso 0383 bp/ LI 6 718" 4 • • Loepp, Victoria T (DOA) From: Tempel, Joshua <Joshua.Tempel@bp.com> Sent: Friday, November 17, 2017 8:50 AM To: Loepp, Victoria T (DOA) Subject: V-119 Surface Plug Sundry Hi Victoria, May I get an update on the Surface Plug Sundry for V-119?Once a Sundry is approved we've got a rigorous internal process we put our P&As through that can be a bit slow. I'd like to start the process as soon as possible to make sure we are meeting the 90 day deadline assigned to this well. Thank you, Josh Tempel GWO I BP Alaska I Well Integrity Engineer Mobile: +1 (907)891 5930 I Office 742A� Da VC ) �� w p p �oV 1 C (A1C 10- pc 5� 1/SJ 90 V✓ c � o bc) 5 " c) �� o , � 5v ✓ c "rG P /00,1 117-011Y U,vY 5s /171' W + • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request. Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend El• Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2 Operator Name: BP Exploration(Alaska),Inc 4 Current Well Class: 5, Permit to Drill Number: 204-041 • 3 Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 6 99519-6612 Stratigraphic ❑ Service 0• API Number 50-029-23201-00-00 7. If perforating: 8. Well Name and:,N " k'IVED What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Cd PBU V-119 I. ( 9 :, , 9. Property Designation(Lease Number): 10. Feld/Pools: ADL 028240&028245 PRUDHOE BAY,BOREALIS OIL ' ,rn r /0,1/ 11. PRESENT WELL CONDITION SUMMARY A (11L1 Total Depth MD(ft). Total Depth TVD(ft) Effective Depth MD: Effective Depth TVD MPSP(psi/. Plugs(MD): Junk(MD): 10483 ' 6867 • 2214 2066 2214 None Casing Length ' Size MD TVD Burst • Collapse Structural Conductor 79 20" 30-109 30-109 1490 470 Surface 3320 9-5/8 29-3350 29-2725 5750 3090 Intermediate Production 10447 7" 28-10475 28-6862 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10208-10256 6699-6728 4-1/2"12.64 L-80 26-10056 Packers and SSSV Type. 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and TVD(ft): 9995/6568 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 Service 0 ' 14.Estimated Date for Commencing Operations: October 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended E/1 • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel,Joshua be deviated from without prior written approval Contact Email: Joshua.Tempelabp.com Authorized Name: Tempel,Joshua Contact Phone' C./ ._ Pet i s€4 3C.1 Authorized Title: Drilling Engineer q Authorized Signature: ]—�.1 Date: ///7 // 7 COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number: // 317-yy� Plug Integrity p BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Svrf,s, e 1.v5p $ ' ° ^ ¢o eccvr 14,'7th,`n 9D ci 4y 5 - S�'per-4 ). svv)cl r r-c u fvrc - Post Initial Injection MIT Req'd? Yes 0 No IN" Spacing Exception Required? Yes 0 No G3" Subsequent Form Required: 1 0--- 40-q-- APPROVED BYTHE k O '1.4 It airr J Approved by: COMMISSIONER COMMISSION Date VTL- 10/11 ,A ie 69717 47 �Jck(�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 • ti of TyJ� • \��j�,s� THE STATE Alaska Oil and Gas N� ►�it � Conservation Commission of LAS 333 West Seventh Avenue " t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 C)'4 ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov Joshua Tempel Drilling Engineer BP Exploration(Alaska), Inc. scANNED DEC 0 8 2017, PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU V-119 Permit to Drill Number: 204-041 Sundry Number: 317-447 Dear Mr. Tempel: 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, Hollis S. French Chair DATED this @ day of October, 2017. RBD IS \t/ O t 5 2017 • STATE OF ALASKA *LASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROV 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend H• Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-041 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic ❑ Service H. 6. API Number: 50-029-23201-00-00• 7. If perforating: 8. Well Name an 1 V What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No H PBU V-119 9. Property Designation(Lease Number): 10. Field/Pools: SEP 1 9 ZU1 ADL 028240&028245 PRUDHOE BAY,BOREALIS OIL ' ors' 1 U 1 7 11. PRESENT WELL CONDITION SUMMARY ,O Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10483 ' 6867 • 2214 2066 2214 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 30-109 30-109 1490 470 Surface 3320 9-5/8 29-3350 29-2725 5750 3090 Intermediate Production 10447 7" 28-10475 28-6862 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10208-10256 6699-6728 4-1/2"12.6# L-80 26-10056 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and ND(ft): 9995/6568 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: October 1,2017 15. Well Status after proposed work: . Oil 0 WINJ 0 WDSPL 0 Suspended H • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel,Joshua be deviated from without prior written approval. Contact Email: Joshua.Tempel@bp.com Authorized Name: Tempel,Joshua Contact Phone: 9 e.,1 igat/ S cr 543 Authorized Title: Drilling Engineer Authorized Signature: Date: 9/ /9 /17 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number:7 Plug Integrity / BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 3i T—4 �q Other: S1Cr{:4 C C S v 5P-t vl 5 /O ''''`• ¢o ©C C(.r 0.7 11-1-,1`n q 0 c1 a�I S - J�Cpf rcf�,° S vv)d r1 Cr�v"'v-t c1 _ J Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No lit/ Subsequent Form Required: ` C —4 0 APPROVED BYTHE (O 'C3 ILR Approved by: COMMISSIONER COMMISSION Date: V7L. fl//l/II' ,�� 7 /071747 "ki\uRIGINAL RBD -iStit/ OCT 25 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in cD�uplicate bp RECEIVED V-119 Reservoir Abandonment SEP 1 9 2017 Well Interventions Engineer: Josh Tempel (907)891-5930 AOGCC Pad Engineer: Eric Zoesch (907) 564-4695 Expected Start Date: 10/1/2017 History V-119 is a Kuparuk injector drilled in 2004. The well was shut in in 2010 due to a tubing leak, a patch was successfully installed in 2011. The well remained shut in due to a surface casing leak. An unsuccessful surface casing x conductor top job was performed in August 2017. Current Status The well currently has no remaining value, and no sidetrack opportunities, it is currently classified J` as "Not Operable" by BP and is shut-in due to a surface casing leak. Objective The objective of this job is to perform a reservoir abandonment on this well. • Procedural steps Slickline 1. Pull TTP Eline 2. Punch tubing at -9400' MD above the patch. Fullbore 3. Pump reservoir abandonment 148bbls of 15.8ppg class G cement. Target top is 5,500' MD in the tubing and IA which covers all perforations and both the Kuparuk and Shrader Bluff reservoirs.Cement top is -650' above the Shrader Bluff formation. Slickline 4. Drift and tag TOC. A D 6 C C rhsJ2 cc f o r -Fp yr -to X55 fag a� cj Pr Fullbore 5. CMIT-TxIA to 2500psi • • • Cement Type/weight: Class G 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours Activity Time(hours) Shearing time, quality control, PJSM 1 Cement displacement 2 Cement contamination 2 Safety 1 Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3500 2:00 140 3500 3:00 150 3500 4:00 160 3500 7:00 160 3500 15:00 160 3300 2 • O • TREE= 4-116'C3A/ WELLFEAD.. RC V-119 Current SAFETY NOTE:H2S READINGS AVERAGE 125 ppm ACTUATOR- 14,1 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON OKB.ELEV= 611' ML REF ELB/• 81.7' I3F ELEV= 53 64' KOP- 600' I [ 2214' H Ks x PiP,1)=3.513' 1 Mai Angle= 5r is 5(0r 2214' I-14-1/7-PX PLUG(08/)9r16) Datum MD= 10180' Datum TVD-- 6600SS GAS LET IJAN3RB_S 9 5/8'(... -6 40i L 80,1)-&835 ' 3348. j—A ST ID TVD DEV TYPE VLV LATCH-FORT— RATE 6 3127 2598 55 KE3G-2 CIW BK 0 12/29/04 5 4343 3306 55 KBG-2 CAW BK 0 04/21/04 Mi 4 5901 4206 56 KBG-2 DAY BK 0 12/29/04 3 7438 5094 54 KBG-2 MY BK 0 12'29/04 2 8502 5713 54 KBG-2 CMY BK 0 12/231/04 Minimum ID =2.45" @ 9402' 1 9865 6489 53 KBG-2 CAW BK 0 10127108 BAKER 45 KB PATCH 9402*-942W H8KR 45 ice PATCH,V=2 45-(8/5/11) $ : I , I. 9131' H-1/2-'l413 X MP,0-3 813' 9993' I--r x 4-1)7 BKR PREM PKR I I 10021' J-4-1I7 Fes x MD,n=3813' I I 100437—H4-112'HS XN 14P,0•3 725* 1 / \ 10064' --4-1/7 WL193,D=3.9-1-51-17" 4-1/7 MG,12 8O,L-80, 0152 W,I)•306W lacer POIFORAT1ON SUIANRY REF LOG: WAD ON 04/14/04 ANGLE AT TOP PERE 57 . 10210' Note Refer to Rodoction DB for historical perf data • 10144'1Hr trAnKen sr SIZE SPF' INTERVAL Opfi/Sqz DATE — 3-3/8' 6 1 10206-10256 0 06125/04 1 • 1036W I—7'MARKER JT I mro 1— 1842, i .80.88 •••• •18080.880 0810 4881 IT C8G,201,L-80. 0383 bpi,ID- H 104739 k............04.4. 3 • 4-*IW( N iMallEAD FPC V-119 Proposed SAFETY NOTES K2S REAUNGS AVERAGE 126 ppm ACILATOR NA WHEN ON MI. WELL REQUIRES A SSSV WHEN ON O 433 ELEV= air *IF&EV= BE ELEV 516e 1030= 600 f 221 4• ' 1-14-172"t-156 X NP =3 51Y I hitz Am ok- 574001 -demo - -TO-190 Dew IVO." 00005S OAS LET WPS e-sor CSO.400.L10,ct taw 3349 ST M) ND I(P1 TYFE VEY LATCH SCAT CATE 6 3127 2596• 56 1004 CW BK 0 12723104 Cement Height-55130'N 5 4343 3305 55 1010-2 Okit BK 0 04/21/04 4 5,51 4205 56 KEK3-2 OW BK 0 1242904 3 143/3 50114 54 K130.2 O1W BK 0 1209104 2 6502 5713 54 KBG 2 01119 BK 0 1212904 Minknum ID=2.45"ta 9402 6469 53 KM-2 MN BK 0 ity27o06 BAKER 45 KB PATCH 6 174inid / 4277' tvd Top Shrader • 7,077' md 4803' tvd Base Shrader war-oar SKR 45 033 PAT04,ID-2 45' 1 611031' 4-1,9'HOS x Kr.0 3 sir MT Fir x 4-112.aim Fc69.4 Pot 1 4.= - t =4 10021* HrP x 33 3 sir 1 -4 10661' H4,1/2- xi4 MP,D 3735J i t.-so,.0152 bpi. 3,9sr H liner Jm 100" 4'Ff 3 95—ilr " - PUP:PATCH SWIPARY BEE LOG QUAD OW04714414 ANGLE AT TOP PEW sr 10210 " Pt e Refer*Production 113 for hoslorLail pert du* • woo<ER.rr_, E scf-' NTE OpeuSqz 13%/E 3.3ar 6 to2oe.102'W o mast% 10 200"md / 6612' tvd Top kuparuk *Top perf 10,208' md FWD 10426' It*• I r cso,zw.1.44 maw,lo•6.27r jflioia* f-- 4 Loepp, Victoria T (DOA) From: Tempel,Joshua <Joshua.Tempel@bp.com> Sent: Thursday, September 28, 2017 2:30 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU V-119(PTD 204-041,Sundry 317-447) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Currently,the surface suspension is unplanned.We are waiting to see the results of the reservoir suspension. If the reservoir suspension resolves the fluid leak through the conductor x surface then the plan is to put this well on the list of P&A candidates we are considering for 2017. If the fluid leak is not resolved then we will be submitting another sundry for the surface suspension and we will be performing the work as soon as scheduling safely allows. Regards, Josh Tempel GWO I BP Alaska I Well Integrity Engineer I Mobile:+1 (907)891 5930 I Office 742A l From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,September 28,2017 9:47 AM To:Tempel,Joshua<Joshua.Tempel@bp.com> Subject: PBU V-119(PTD 204-041,Sundry 317-447) Joshua, When is the surface suspension planned?Why isn't it included in this sundry? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal taw.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 STATE OF ALA • ALASKA OIL AND GAS CONSERVATIONSKA COMMISN 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 IV1 Re-enter Susp Well 0 Other:Cond Top Job-Failure I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 204-041 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number 50-029-23201-00-00 7. Property Designation(Lease Number): ADL 0028245 *2-.W.40 8. Well Name and Number PBU V-119 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10483 feet Plugs measured 2214 feet true vertical 6867 feet Junk measured feet SEP 1 9 2017 Effective Depth: measured 2214 feet Packer measured 9995 feet � true vertical 2066 feet Packer true vertical 6568 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 30-109 30-109 1490 470 Surface 3320 9-5/8"40#L-80 29-3350 29-2725 5750 3090 Intermediate Production 10447 7"26#L-80 28-10475 28-6862 7240 5410 Liner Perforation Depth: Measured depth: 10208-10218 feet 10218-10236 feet 10236-10256 feet True vertical depth: 6699-6705 feet feet 6705-6716 feet 6716-6728 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"Baker Premier Packer 9995 6568 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Surface of OA. Treatment descriptions including volumes used and final pressure: 10 Bbls Fresh Water w/F103,33 Gallons SLB AS1 Cement,Atmospheric Pressure. SCANNED f� 22.016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1719 0 2031 Subsequent to operation: Shut-In 0 1600 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development ❑ Service H 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 0 WINJ 0 WAG II GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-306 Authorized Name: Worthington,Aras J Contact Name: Worthington,Aras J Authorized Title: Intery ntions&Integrity Engin Contact Email: Aras.Worthington@bp.com Authorized Signature:�� Date: 9////�1,4919' Contact Phone: +1 907 564 4102 Form 10-404 Revised 04/2017 V-7-1-I( 2,1118 RBDNIS i "SEP 2 5 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission RECEIVED 333 West Seventh Avenue Anchorage, AK 99501-3572 SEP 1 9 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 19, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Failed Conductor Top Job for Well V-119, PTD # 204-041. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. 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WELL REQUIRES A SSSV WHEN ON OKB.ELEV= 81.7" ML REF ELEV= 81.7" BF, ELEV= 53.64' KOP= 600' { 2214' H4-1/2"HES X NP,ID 3-813" Max Angle= 57"@ 6007' Datum MD= 10180 2214' —14-112'PX PLUG(08/09/16) Datum ND= 6600'SS GAS LFT MANDRELS 9-5/8"CSG,40#,L-80,ID=8.835" —1 3349' -4 ' ST MD TVD DEV TYPE VLV LATCH FORT DATE 6 3127 2598 55 KBG-2 DMY BK 0 12/29/04 5 4343 3306 55 KBG-2 DMY BK 0 04/21/04 4 5901 4206 56 KBG-2 DMY BK 0 12/29/04 3 7438 5094 54 KBG-2 DMY BK 0 12/29/04 2 8502 5713 54 KBG-2 DMY BK 0 12/29/04 Minimum ID =2.45" @ 9402' 1 9865 6489 53 KBG-2 DMY BK 0 10/27/08 BAKER 45 KB PATCH 9402'-9429' HBKR45 KB PATCH,D=2.45"(8/5/11) I I ( 9931' H4-1/2"HES X NP,D=3.813" 1 ><- 9993 —f7"X 4-1/2"BKR PREM PKR ' ' 10021' —4-1/2"HES X NP,D=3.813" I I 10041' --14-1/2"HES XN NP,D=3.725" 4-1/7 TBG, 12.6#,L-80, .0152 bpf,D=3.958" — 10053' 7 — 10054' �4 112"WLEG,D=3 958' PERFORATION SUMMARY REF LOG: QUAD ON 04/14/04 ANGLE AT TOP PERF: 52"@ 10210' Wte:Refer to Production DB for historical perf data • 10143' H 7"MARKER JT SIZE SPF NTTRVAL Opn/Sqz DATE 3-3/8" 6 10208- 10256 0 06/25/04 L• { 10368 ......N7"MARKER.!- FBTD H 10425' 'R't'R'R'•'�'�'�'�'�. 111111111111111111111 7"CSG,26#,L-80, .0383 bpf,D=6.276" —1 10473' DATE REV BY COMMENTS DATE REV BY COPv?U'/TS BOREALIS MAT 04/21/04 KAK ORIGINAL COMPLETION 08/11/16 JMG/JMD SET PX PLUG(08/09/16) WELL: V-119 06/25/04 LDK/KAK IF'RFS 06/30/17 JNJJMD ADDED REF&BF ELEV PERMf Pb: 2040410 02/15/11 MB/JMD ADDEDSSSV SAI-E!Y NOTE AR No: 50-029-23201-00 08/15/11 SRD/PJC SET PATCH(08/05/11) SEC 11,T11N, R11E,4645'NSL&1803'WEL 09/21/11 JCM'PJC D CORRECTION 01/19/12 TM4'JMD ADDED H2S SAFETY NOTE BP Exploration(Alaska) OF ?It THE STATE Alaska Oil and Gas ofALAS K ® Conservation Commission }fix _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Y' Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington ',n j 7 Interventions & Integrity Engineer WARS J U"" 2 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU V-119 Permit to Drill Number: 204-041 Sundry Number: 317-306 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, Hollis S. French Chair DATED this day of July, 2017. RBDMS L L--JUL 1 1 2017 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM! ION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other Top Job 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-041 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ID 99519-6612 Stratigraphic 0 Service H• 6. API Number: 50-029-23201-00-00 ' 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 0 PBU V-119 • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028240&028245' PRUDHOE BAY.BOREALIS OIL ' J Ul N 3 0 2 fl 17 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): (I f . 10483 ' 6867 • 2214 2066 2214 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 31-110 32-111 1490 470 Surface 3320 9-5/8" 31-3351 31-2726 5750 3090 Intermediate Production 10450 7" 28-10478 28-6864 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10208-10256 6699-6728 4-1/2"12.6# L-80 26-10056 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and TVD(ft): 9995/6568 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0• 14.Estimated Date for Commencing Operations: July 15,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 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: Interventio Integrity Engineer ? Authorized Signature: e : Date: 60/70A4.19 9 � /� COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31-7- 00(..0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No Fl Spacing Exception Required? Yes 0 No lit/ Subsequent Form Required: I 0 �L�0 It' i APPROVED BYTHE "'I- I q i I Approved by: COMMISSIONER COMMISSION Date: A , 11 M.- -7/7/i OR1GINAL RBDMS i_ __ JUL 1 1 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,-�/1/(-7 'S.:._ 7 3, 17 • • • bp • 44, V-119 Conductor Top Job Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Eric Zoesch (907) 564-4695 Estimated Start Date: July 15th 2017 History V-119i is a vertical Kuparuk injector in the Borealis reservoir. V-1191 was SI early January 2010 for TxIA communication. A tbg patch was set (@ 9402'MD) in August 2011and successfully stopped the TxIA leak. However, in September 2011 a SC leak was discovered at 15' below the surface. V- 119i has remained SI since 1/11/2010. V-119i has a passing MIT-IA to 2500psi post-patch and a LLR of 1.09gpm with 25psi pressure on the OA but is-drassified as "Not Operable" due to the surface casing leak. The well was secured with a plug in the SSSV nipple in August of 2016. In June of 2017 fluid was noted in the conductor and cellar with some hydrocarbons evident. Approximately 3 bbls of fluid were evacuated from the conductor and cellar on the 27th of June 2017. Current Status The well is currently classified as "Non Operable" by BP due to the OA x Conductor leak. The well is secured with a plug in the SSSV nipple. Objective Perform a conductor top job to eliminate any leaking of fluid from the surface casing leak and into the conductor/cellar. Procedural steps DHD/Special projects 1. Steam clean the Conductor x Surface Casing Annulus to top of good cement. 2. Circulate cement or LockCem into the conductor from the top of existing cement to surface until clean cement returns are observed. TREE= " 4-1/16"CNV UVEt_LHEAD= FMCV 119 SAFETY NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= NA WHEN ON MI. WELL REQUIRES A SSSV WHEN ON OKB.ELEV= 82.5' MI. REF ELE1/= 81.T BF.ELEV= 53.64' 2214' H4-1/2"HES X NP,ID=3.813" Nix Angle_=_ 57°-6-50-077 �� Datum MD= 10180' 2214' H4-1/2"PX PLUG(08/09/16) Datum TVD= 6600'SS GAS LIFT MANDRELS 9-5/8"CSG,40#,L-80,ID=8.835" H 3349' --4 ' ST MD ND DEV TY FE VLV LATCH PORT DATE 6 3127 2598 55 KBG-2 DMY BK 0 12/29/04 5 4343 3306 55 KBG-2 DMY BK 0 04/21/04 4 5901 4206 56 KBG-2 DMY BK 0 12/29/04 3 7438 5094 54 KBG-2 DMY BK 0 12/29/04 2 8502 5713 54 KBG-2 DMY BK 0 12/29/04 Minimum ID =2.45" @ 9402' 1 9865 6489 53 KBG-2 DMY BK 0 10/27/08 BAKER 45 KB PATCH 9402'-9429' H BKR 45 KB PATCH,D=2.45"(8/5/11) C 9931' —4-1/2"HES XNP,D=3.813" 9993' --17"X 4-1/2"BKR PREM PKR 10021' —14-1/2"HES X NP,D=3.813" ' 1 10041' H4-1/2"HES XN MP,D=3.725" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" —I 10053' / --I 10054' —i4-1/2"WLEG,D=3.958" PERFORATION SUMMARY REF LOG: QUAD ON 04/14/04 ANGLE AT TOP FERE: 52'@ 10210' Note:Refer to Production DB for historical perf data • 10143' —17"MARKER JT SIZE SPF NITERVAL Opn/Sqz DATE 3-3/8" 6 10208-10256 0 06/25/04 • 10368' H7"MARKER JT FBTD H 10425' 1111111111 111111111111111111111 7"CSG,26#,L-80,.0383 bpf,D=6276" —I 10473' DATE REV BY CONVENTS DATE REV BY COMMENTS BOREALIS UNIT 04/21/04 KAK ORIGINAL COMPLETION 08/11/16 JMG/JMD SET PX RUG(08/09/16) WELL: V-119 06/25/04 LDK/KAK IPERFS 06/30/17 JMUJMD ADDED REF 8 BF ELEV PERMIT No: 2040410 02/15/11 MB/JPoD ADDED SSSV SAFETY NOTE AR No: 50-029-23201-00 08/15/11 SRD/PJC SET PATCH(08/05/11) SEC 11,T11 N, R11 E,4645'NSL 8 1803'WEL 09/21/11 JCM PJC MWJ D CORRECTION 01/19/12 TNWJND ADDED H2S SAFETY NOTE BP Expbration(Alaska) • • OF TJi • e"\\\I 77i4'cv THE STATE Alaska Oil and Gas if of 1,AsKA Conservati®n Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 SO' Aras Lv www.aogcc.alaska.gov S Aras Worthington Wells Engineer _ o (� BP Exploration(Alaska), Inc. cD 0�' _T P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS V-119 Sundry Number: 315-560 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, Cathy P. oers of r deryChair DATED this of September, 2015 RBDMS SEP + 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N • APPLICATION FOR SUNDRY APPROVA S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ ✓ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing V ' Change�tApproved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ® Re-enter Susp Well 0 Ot�er OA Down ze • ifit 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 204-041 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612Stratigraphic 0 Service a, 6. API Number: 50-029-23201-00-00 • 7. If perforating: 8. Well Name and Num j What Regulation or Conservation Order governs well spacing in this pool? Yes 0 Nom BRLS V-119 . 4A Will planned perforations require a spacing exception? _ ,. 9. Property Designation(Lease Number): 10. Field/Pools: SEP 0 9 20',n ADL 0028245• PRUDHOE BAY,BOREALIS OIL • OTS Il l 11. PRESENT WELL CONDITION SUMMARY 0UaCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10483 ' 6867 ' 10425 • 6832 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"91.5#H-40 31 -110 31 -110 1490 470 Surface 3320 9-5/8"40#L-80 30-3351 30-2726 5750 3090 Intermediate Production 10450 7"26#L-80 27-10477 27-6863 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10208-10256 6698.78-6728.49 4-1/2"12.04 L-80 25-10055 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and TVD(ft): 9994, 6567.70 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal RI 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 10 ' GINJ ❑ WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Worthington,Aras J Email Aras.Worthington@bp.com Printed NameWorthington,Aras J Title Wells Engineer Signature , / il1/3' Phone +1 907 564 4102 Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315 —5tQo Plug Integrity 0 BOP Test 0 Mechanical Integrity Test V Location Clearance 0 Other: --a,,f-'C t —I 1 vi r 5 5-ccl ,--1A, IT-1 ,-� 17—e-cL L- l'.-r.CI 4 1:-f"ri-- i---.4, 1?-1 )15,,e-ci 1/ ,p' APPROVED BYTHE 1h.jcCh ' Spacing Exception Required? Yes 0 No LvJ Subsequent Form Required: i C— 4 c '7 PApproved by: COMMISSIONER COMMISSION Dater/m /5— ORIGINAL RBDMA7 SEP 271015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /ylt : 4/5-- • • V-119 OA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: James Shrider (907) 564-4755 History V-119i is a vertical Kuparuk injector in the Borealis reservoir. V-119i was SI early January 2010 for TxIA communication. A tbg patch was set (@ 9402'MD) in August 2011 and successfully stopped the TxIA leak. However, in September 2011 a S C leak was discovered at 15' below the surface. V- 119i has remained SI since 1/11/2010. V-119i has a passing MIT-IA to 2500psi post-patch and a LLR of 1.09gpm with 25psi pressure on the OA. The proposed plan forward is to cement the OA to seal off the leak. • Current Status The well is currently classified as "Non Operable" by BP due to the OA x Conductor leak. The well is therefore currently shut-in until the leak is fixed. Objective The objective of this job is to cement the OA (9-5/8" x 7") annulus and make this well operable. Cement will be pumped down the OA from surface in two stages (if needed). The goal is to have cement in the OA from the 9-5/8" casing shoe to surface. Any voidage in the OA left after the cement jobs will be filled/squeezed with well lock or Squeezecrete if needed. Procedural steps Fullbore 1. Establish injectivity rate and pressure down the OA with diesel. Cementers 1. RU to the OA. 2. Pump enough Class G cement to fill OA to surface, SI and allow cement level to reach equilibrium. 3. WOC to build strength. 4. Pump a second cement job to refill OA to surface (if needed). Special Projects 1. WOC to build strength. 2. Strap the TOC in the OA. 3. Fill and squeeze the remaining void in the OA with well lock if needed. _,. • III ,-REE. 4-1/16"CTW WELLHEAD= FMC SAFETY NOTES:MS READINGS AVERAGE 125 ppm ACTUATOR= NA )4_V-1 1 9 WHEN ON Ml. WELL REQUIRES A SSSV WHEN ON KB. ELEV= 82,5' Mk BF.ELEV= KOP= 600' ei i 72- / Max Angie= 57 6007*Da \i .- tum IND= 10180' ti'') / - [ 2214' —4-1/7'HES X NIP,ID=3.813- II Datum ND= 6600SS / I -- ,-- 7 GAS LIFT MANDRELS 9-5/8-CSG,40#, L-80,ID=8.835 — 3349' 1-47 „t ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3127 2598 55 KBG-2 DMY BK 0 12/29/04 1....Jd 5 4343 3306 55 KBG-2 DA/TY BK 0 04/21/04 4 5901 4206 56 KBG-2 DMY BK 0 12/29/04 3 7438 5094 54 KBG-2 DM' BK 0 12/2804 2 8502 5713 54 KBG-2 DMY BK 0 12/29/04 Minimum ID = 2.45" @ 9402' 1 9865 6489 53 KBG-2 DMY BK 0 10/27/08 BAKER 45 KB PATCH 9402' -9429' HBKR 45 KB PATCH,ID=2.45"(8/5/11) J E , , 9931' —14-112"HES X NIP,ID=3.813" X- r 9993' —7"X 4-1/7'BKR PREM FKR 1 r--..-1 10021' —4-1/2-HES X NIP,0=3.813" I I 10041' —4-1/2"HES XN NIP,ID=3.725" 3.958"' I— = 4-1/7'TBG,12.6#,L•80,.0152 bpf,ID=3.958" — 10053 / \ 100E4 4-1/2”VVLEG,ID' PERFORATION SUMMARY REF LOG: QUAD ON 04/14/04 ANGLE AT TOP PERF: 52'al 1021d Note:Refer to Production DB for historical perf data • 10143' —7'MARKER JT SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10208• 10256 0 06/25104 111 1101 10368' —7 MARKER JT PBTD — 10425' *1.$41+.0**0.. •0 14• ********4 7'CSG,28%,L-80,.0383 bpi,0=6,276- I— 10473' 14.44.44........... DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 04421/04 KA K ORIGINAL COMPLETION '02/15/11 WM) ADDED SSSV SAFETY NOTE WELL: V-119 06/15/04 JLJ/KAK GLVCIO 7 08/15111 SRO/PJC SET PATCH(08/05/11) FERMI No: ' 040410 06/25/04 LDK/KAK IFERFS 09/21/11 JCM PJC MIN ID CORRECTION AR No: 50-029-23201•00 t. 12/29/04'RAC/TLP GLV C/0 01/19112 TINN/JAK) ADDED H2S SAFETY NOTE SEC 11,T11N, R11E,4645'NSL&1803 VVEL 09/01/08 ?/PJC *GLV C/0(07/27/08) 11/10/08 KDC/SV GLV C/O(10/27/08) , _ _ BP Exploration(AlasIo) 2 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a Q Lþ - 0 lJ- J Well History File Identifier Page Count from Scanned File: «? 5" (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~YES CMaOa) Date 7/ J. <6 fÓÞ If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided 1111111111111111111 RESCAN DIGITAL DATA \Æ1Óiskettes, No. I ~ther, NolType: C 1) No o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: ~ Date7/:L8/0~ Date 7 f:J-'6j o(p ~ X 30 = _&;;D Project Proofing BY: ~ Scanning Preparation BY: Date: Production Scanning Stage 1 BY: Stage 1 BY: Date: Maria Scanning is complete at this point unless rescanning is required. o Rescan Needed 111111111111111I111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mP /5/ 1111111111111111111 /5/ r11P +....') U. = TOTAL PAGES <?If ~t does not include cover sheet) /5/ ,f 1111111111111111111 NO /5/ Y\1 f NO /5/ 1IIII1I111111111111 ReScanned BY: Maria Date: /5/ Comments about this file: 1111111111111111111 Quality Checked 11111111I11I111111I 10/6/2005 Well History File Cover Page.doc NOT OPERABLE: Injector V -119 (PTD #2040410) Confirmed Surface Clog Leak Page 1 of x A Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Tuesday, September 13, 2011 6:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr Cc: Walker, Greg (D &C); Reynolds, Charles (Alaska); Greaves, Damien C; Clingingsmith, Mike J (Swift) Subject: NOT OPERABLE: Injector V -119 (PTD #2040410) Confirmed Surface Casing Leak All, Injector V -119 (PTD #2040410) has been confirmed to have a surface casing leak. An MIT -OA was attempted and fluid was observed inflowing to the conductor when the OA was pressured up. The well is currently shut in and freeze protected and should remain shut in until repaired. The well has been reclassified as Not Operable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Afri ,a) S } 1 4 2n Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, September 12, 2011 7:12 PM To: 'Regg, James B (DOA); 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr Cc: Walker, Greg (D &C); Reynolds, Charles (Alaska); Greaves, Damien C; Clingingsmith, Mike 3 (Swift) Subject: UNDER EVALUATION: Injector V -119 (PTD #2040410) Suspected Surface Casing Leak All, Injector V -119 (PTD #2040410) was reported to have crude and water coming out of the conducter when placed on injection on 09/11/2011. The well has been shut in and is reclassified as Under Evaluation while diagnostics are conducted to evaluate a potential surface casing leak. The plan forward is: 1. D: MIT -OA, establish LLR 9/14/2011 STATE OF ALASKA • • ALASKAIDAND GAS CONSERVATION COMMISSICID REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 TUBING PATCH Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ 9402 -9429 Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ .. 204 -0410 3. Address: P.O. Box 196612 Stratigraphic Service El 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 23201 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028245 . V -119 10. Field /Pool(s): PRUDHOE BAY FIELD / BOREALIS POOL 11. Present Well Condition Summary: Total Depth measured 10483 feet Plugs (measured) None feet true vertical 6866.86 feet Junk (measured) None feet Effective Depth measured 10425 feet Packer (measured) 9402 9424 9993 feet true vertical 6831.72 feet (true vertical) 6229 6241 6566 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 101# H -40 30 - 110 30 - 110 1650 650 Surface 3321' 9 -5/8" 40# L -80 29 - 3350 29 - 2726 5750 3090 Production 10447' 7" 26# L -80 26 - 10473 26 - 6861 7240 5410 Production Liner o , n , � Liner A .; �:44i� Atj } ". ■ Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ • - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 10054 24 - 6604 3 -1/2" 8.81# L -80 9402 - 9429 6229 - 6241 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker 45 KB Packer -° 9402 — 6229 3 -1/2" Baker45 KB Packer 9424 6241 4 -1/2" Baker Premier Packer t ,..�� 9993 6566 12. Stimulation or cement squeeze summary: kj6 % 9 Mt Intervals treated (measured): Treatment descriptions including volumes used and final pressure: a AntheTege 1& GEttG OO•G4 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: ,., Copies of Logs and Surveys Run Exploratory0 Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: •• Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP❑ SPLUG ❑ 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: 311 -216 Contact Joe Lastufka Printed Na - Last a , Title Petrotechnical Data Technologist Signatu _ Phone 564 -4091 Date 8/26/2011 RBDMS AUG 2 9 201 . °'`( Form 10 -404 Revised 10/2010 Submit Original Only V -119 204 -041 PERF ATTACHMENT ' Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -119 6/25/04 PER 10,208. 10,218. 6,698.78 6,704.98 V -119 6/25/04 PER 10,218. 10,236. 6,704.98 6,716.13 V -119 6/25/04 PER 10,236. 10,256. 6,716.13 6,728.49 V -119 3/18/10 BPS 10,041. 10,256. 6,595.79 6,728.49 V -119 4/2/11 MLK 9,412. 9,413. 6,234.57 6,235.13 V -119 7/27/11 BPP 10,041. 10,256. 6,595.79 6,728.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • V -119 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/4/2011; 'WELL SHUT IN ON ARRIVAL * * *(ELINE PATCH) INITIAL T /I /O= 550/700/0 PSI INITIAL VALVE POSITIONS: M /SSVNALVE TO CASING= OPEN, SWAB/WING= CLOSED RIGGED UP AND EXPERIENCED PROBLEMS WITH THE LOGGING UNIT. RIG DOWN AND BRING UNIT BACK TO PRUDHOE TO TROUBLESHOOT. 1 FINAL T /I /0= 550/700/0 PSI FINAL VALVE POSITIONS: M /SSVNALVE TO CASING= OPEN, SWAB/WING= CLOSED ** *JOB TO BE CONTINUED ON 5 -AUG- 2011 * ** 8/5/2011 ` ** *JOB CONTINUED FROM 4- AUG - 2011 * * *(ELINE PATCH) INITIAL T /I /O= 550/700/0 PSI INITIAL VALVE POSITIONS: M /SSVNALVE TO CASING= OPEN, SWAB/WING= 'CLOSED ! SET BAKER 45KB STRADDLE PATCH FROM 9404'- 9424.6' MEASURED FROM THE INNER ELEMENT SEALS. SEALING ELEMENTS ARE 0.40' LONG FOR THE TOP AND BOTTOM PACKER. TOP OF PATCH = 9402.4'. BOTTOM OF PATCH= 9428.9'. PATCH WEIGHT= 360 #. ID OF PACKERS= 2.45 ", ID OF 3.5" L -80, 3TUBING= 2.972 ". FINAL T /I /O= 550/600/0 PSI FINAL VALVE POSITIONS: M /SSVNALVE TO CASING= OPEN, SWAB/WING= CLOSED ]***JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL TREE= - 4-1/16" CM/ • WELLHEAD = FMC � SA E Y N WELL REQUIRES A SSSV WHEN ACTUATOR = NA KB. ELEV = 82.5' BF. ELEV = 28.2.' - - - KOP = 600' Max Angle = 57 @ 6007' Datum MD = 10180' ' I ( 2214' 1- 14 -1/2" HES X NIP, ID = 3.813" Datum TVD= 6600'SS GAS LIFT MANDRELS 19 -5/8" CSG, 40 #, L -80, ID = 8.835" H 3349' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3127 2598 55 KBG -2 DMY BK 0 12/29/04 5 4343 3306 55 KBG -2 DMY BK 0 04/21/04 4 5901 4206 56 KBG -2 DMY BK 0 12/29/04 3 7438 5094 54 KBG -2 DMY BK 0 12/29/04 2 8502 5713 54 KBG -2 DMY BK 0 12/29/04 Minimum ID = 3.725" @ 10041' ss— Asa —. KJ-2 BK 0 10/27/08 4 -1/2" HES XN NIPPLE 9402' - 9429' BKR45 KB PATCH, ID =2.45" (8/5/11) 1 1 I 9931' H 4 -1 /2" HES X NIP, ID = 3.813" I 1 9993' H " X 4 -1/2" BKR PREM PKR I 10021' 1 HES X NIP, ID = 3.813" I 1 1 ( 10041' I - 14 - 1/2" HES XN NIP, ID = 3.725" 1 I4 -1 /2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" — 10053' I —� 10054' H / 2" WLEG, ID = 3.958" I -- PERFORATION SUMMARY REF LOG: QUAD ON 04/14/04 ANGLE AT TOP PERF: 52° @ 10210' •-1 10143' 1 MARKER JT I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10208 -10256 O 06/25/04 • 10368' 1-1 7" MARKER JT I PBTD I-1 10425' � 1 7" CSG, 26 #, L -80, .0383 bpf, ID = 6.276" I — I 10473' k att *At1'.* DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 04/21/04 KAK ORIGINAL COMPLETION 03/21/10 RCT /SV SET PX PLUG (03/18/10) WELL: V -119 06/15/04 JLJ /KAK GLV C/0 1 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: '2040410 06/25/04 LDK/KAK IPERFS 07/30/11 CDJ/ PJC PULL PX PLUG (07/27/11) API No: 50- 029 - 23201 -00 12/29/04 RAC/TLP GLV C/O 08/15/11 SRD/ PJC SET PATCH (08/05/11) SEC 11, T11 N, R11 E, 4645' NSL & 1803' WEL 09/01/08 ? /PJC GLV C/0 (07/27/08) 11/10/08 KDC/SV GLV C/O (10/27/08) _ BP Exploration (Alaska) OPERABLE: Injector V -119 (PTD #2040410) Tubing Integrity Restored Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Sunday, August 14, 2011 9:42 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr Cc: Walker, Greg (D &C); Reynolds, Charles (ALASKA); Greaves, Damien C; Clingingsmith, Mike J (Swift) Subject: OPERABLE: Injector V -119 (PTD #2040410) Tubing Integrity Restored Attachments: MIT PBU V -119 08 -11 -11 .xls; V- 119.pdf All, Injector V -119 (PTD #2040410) passed an MIT -IA on 08/11/2011 after a tubing patch was set to repair TxIA communication. The passing test verifies two competent barriers and the well has been reclassified as Operable. Once the well is on injection and stabilized, the AOGCC will be notified for a witnessed MIT -IA. Please let me know if you have any questions. «MIT PBU V -119 08 -11 -11 .xis» «V- 119.pdf» Thank you, -t' 20 jt Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 8/15/2011 • 0 % roi; h RA a SEAN PARNELL, GOVERNOR r ° 1 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Damien Greaves Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 ®(� Anchorage, AK 99519 -6612 jP { Re: Prudhoe Bay Field, Borealis Pool, V -119 Sundry Number: 311 -216 �iV E41t.I. -4'`LUU`� Dear Mr. Greaves: ;1, Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday - weekend. Sin -r ‘ el h . . Nor an ■ iss' • . ner DATED this /3 day of July, 2011. Encl. E C EN STATE OF ALASKA �3 1 ALASKA 411AND GAS CONSERVATION COMMISSIO ',� �� / i APPLICATION FOR SUNDRY APPROVALS pp�1�q 5y ee�ttL[� KL1 tl pp n 20 AAC 25.280 " N `a3�'� :,,l1! 'Pi t• e? t nos. e. 01 misswn 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change ApOrbVAd'Pn ram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: TUBING PATCH - Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 204 -0410 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23201- 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: Spacing Exception Required? Yes ❑ No ❑ V -119 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 028245 - PRUDHOE BAY Field / BOREALIS Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10483 - 6866.86- 10425 - 6831.72 - 10041 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 101# H-40 30 110 30 110 1650 650 Surface 3321' 9 -5/8" 40# L -80 29 3350 29 2726 5750 3090 Production 10447' 7" 26# L -80 26 10473 26 6861 7240 5410 Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 24 10054 Packers and SSSV Tvoe: 4 -1/2" Baker Premier Packer Packers and SSSV MD and TVD (ft): 9993 6566 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/19/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DAMIEN GREAVES Printed Name DAMIEN GREAVES Title PE Signature - � '' :�� Phone Date 564 -4852 7/5/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY ■ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 — O t ( p Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Subsequent Form Required: ` " Y / i . APPROVED BY Approved by: COMM ` ONER THE COMMISSION Date: Vet.3/// ;�BDMS � JUL 14 i � ORIGINAL 7 -« Form 10-403 Revised 1/2010 e T� ,' / 31 Submit in Duplicate � 1 V -119 204 -041 _ PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -119 6/25/04 PER 10,208. 10,218. 6,698.78 6,704.98 V -119 6/25/04 PER 10,218. 10,236. 6,704.98 6,716.13 V -119 6/25/04 PER 10,236. 10,256. 6,716.13 6,728.49 V -119 3/18/10 BPS 10,041. 10,256. 6,595.79 6,728.49 V -119 4/2/11 MLK 9,412. 9,413. 6,234.57 6,235.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • EM SQZ MECHANICAL ISOLATED REMOVED QZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • V -119i: Tubing Patch • • ABRVPDWL19 bp To: J. Bixby/T. Norene ADW Wireline T/L Date: June 30, 2010 C.Olsen/T. Norene ADW Well Service T/L From: Damien Greaves Borealis PE AFE: ABRVPDWL19 Est. Cost: Subject: V -119i: Set Patch to restore well integrity, well currently IOR: 60 secured and offline Job Sequence: 1 S Pull Plug. Drift well with dummy patch, SBHP 2 E Set Patch 3 F MIT -IA 3000 psia Current Status SI: Not Operable; TxIA communication Last WT WHP — 2000 psia, Rate — 1900 BWPD BHP Est. 3200 psig @ 6600 ft SS estimated, last SBHP taken in 2005 @ 2919psi Max Deviation 57 deg @ 6007 ft MD Minimum ID 3.725" @ 10,041' HES XN Nipple Last Tag 10.023 ft. MD on 03/20/2011 before running LDL Last Downhole OP LDL on 3/31/2011 Latest H2S Value N/A OBJECTIVE: The primary objective of this intervention is to restore well integrity by setting a tubing patch in V -119i to return well as WAG injector. A LDL run in March 2011, suggest a leak at 9414' ELMD. HISTORY: V -119 is a pre - produced injector that supports L -117 in the Borealis field. The ability to place well on MI will yield IOR benefits of 60 BOPD over a five (5) year period. 1 of 5 V -119i: Tubing Patch • • ABRVPDWL19 V119i is a deviated WAG injector that is currently SI due to TxIA communication. The well has never had an MI slug. The well failed MIT -IA and TxIA on 1/13/2010 while on water injection. The LLR recorded is 0.23 bpm @ 2780 psia. The well did pass a CMIT -TxIA to 3000 psia. A calliper was run on well in March 2010, which showed tubing in good condition. Most probably leak path is via DGLVs The only valve that has been changed is the valve in station #1 during the bright water trial in October 2008. In March 2011, a LDL was able to determine a possible leak at 9414' ELMD. Well Integrity History Pre - produced injector Secured w/ PXN TTP @ 10041' MD - 03/18/10 > 04/17/04: Rig MITIA Passed to 4000 psi > 12/29/04: Ran DGLVs > 01/27/05: MITIA Passed to 2500 p si > 02/05/05: AOGCC MITIA Passed to 2500 psi > 06/12/05: MITIA to 4000 psi Passed > 01/10/06: FO bled IAP & OAP - IA FL NS, OA FL NS > 10/27/08: DGLV #1 > 02/05/09: AOGCC MITIA Passed to 4000 psi > 01/09/10: PO reported IAP— 2120 psi > 01/13/10: MIT -IA Failed, LLR 0.23 bpm @ 2780 psi > 03/18/10: Caliper Tbg from 10100', 261 jts 10 -24 %; Set TTP @ 10041'; MIT -T Failed, CMIT- TxIA Passed to 3000 psi > 04/01/11: LDL found leak at 9414' Contacts: Damien Greaves Production Engineer Office / Cell: 564 - 4852/250 -7856 cc: Well File Slickline: Pre -Patch 1. RU SL 2. Drift to 4 -1/2" nipple @ 4308' MD with 4 -1/2" x 16' Dummy patch 3. Pull 4 -1/2 TTP set @ 10,041' MD 4. Perform SBHP as per attached program 2 of 5 V -119i: Tubing Patch • • ABRVPDWL19 Patch Specs 4 -1/2" Baker packer — L -80 Patch single run system. Use manufacturer's recommended setting procedure. Patch Depth • Patch Setting Depth th is 9404' - 9424' ELMD • Patch Length: 20' element to element. • Casing collar @ 9398' ELMD on PDS LDL 3/31/2011 E -line: Set 5. RU E -Line. Conduct PJSM with the crew. 6. RIH and set 20 ft long one run w/ 4 -1/2" Baker 35KB Straddle. 7. Log w /CCL and Set Packer at 9404' - 9424' elm per manufacturer's recommendations. POOH. 8. Depth is referenced to PDS LDL 03/31/11 9. RDMO Fullbore 10. MIT -IA to 3000 psi. Hand well over to pad operator to place on well injector. Before placing on injection operator should ensure IA is bled to 500 psi. Discuss with WIE to determine suitability of placing well online. 3 of 5 V -119i: Tubing Patch • ABRVPDWL19 LDL — March 31, 2011 cc_ , _1. f ti 1 iitt— Line Speed , i C I i4 Head Tarlton . t ' 1 ;, _ PDS LDL: 313112011 • --- Temperature . Temperature t ti ! .< .,.. =w ,, .., Temperature ---*. 1 4') I _ r f t 4 t i r t . 7 _ 3 i 1 St. L S = WLD-B r • , \ I . + 1 t i .. i r . r i r I 3 24' Baker Patch. single run } L -80 _ eak Signature' a. 940V-9424' ELMD i o i _ 't. In __ . I _ 1 ! _ I 1 T . i, i i i I I r 3 7 A t d ._.. P f processed wittr,CuteP evaluation fdition www.CutePDF.com 4 of 5 V-119i: Tubing Patch • • ABRVPDWL19 V-119i WBS TREE 4 1116 AELL MEAD - SAFETY 83T83: WELL REQUIRES A SSW 11 ACTUATOR - NA V -1 1 9 ON in ial Ely 82. BF. MEV - 28.2' A 1309 Ma Angie - 57 422 6037 Minn 4.43 10 isa 2214" H4 177' FES X P. D - 181 7 I De Xrn TV D - amiss I 9 .5.47 CSG, 40II, L-80, D' 8835 334 r GAS L ITT MA.4CRELS ST MD NT) nor TYPE Vt.V A TC.14 Farr DATE 8 31 27 2598 95 KEIG-2 DIFY EK 0 1829704 5 4343 3306 55 003G-2 WY BK 0 0421704 4 9901 4206 58 +MG- 2 MY 1229434 3 7438 5094 54 03302 CBOY EM 0 1 829434 I Min hviu m ID = 3.72S" 10641' 2 asca 5713 54 KEIG-2 Y EIK 0 12564 4412" HES XN NIPPLE 1 9665 6489 53 43G-2 13MY 8K 0 1(527.05 • • 9031 1. 14:S x o • r I ial x 4. 1 SKR PREM PIM I • • I 10021* H4 VT IES X NIP D • 181 7 I 10041 4.1)7 MES 20.1 48P, - 3-725 10041 4. 1 72 PX re_uo 403 iar, al 1 1 4- in- TEG, 1 2_61I, L-80 , A 152 WC, .• 3 958 H 10051 I--- 10054 h4 I)? ACM. 3 .958 PEFFORA TON SLIIIIARY FIEF LOG. 011 CAI 0471404 A NGL EA TTOP PIFF 52 @ 102 10' MU1.111 kil=1 1. 1 lo Pricluctin LIB listarical pert dale SE 9: INTERV AL Op 44 Sqz DATE 3,38 - 6 10208 - 1 0256 0 miasma 7117 1:13 10425 I 9 .•400•411t* 41111 41414.114 IPA %%VA CSG, 2610, a -80 , D 6.2707 10471 DATE REV BY COMMENTS (Sit F1131 BY COMIers wawa:As air O41dO9 KAIC GRIMM/ COMPLINION OM 1 710 RCM'S! SET PX PLUG 0 3/18 1 CI} Any_ V 119 08/1904 .9_441UAK QV C20 021 5/1 1 818L1143 A CLEO SSSV SAFETY NOTE PERIAT Nu it 0404 10 0642904 LOKIKAK FEFFS API Ncr 56-0562320i -00 12/2se04 RACITLP GLV 00 SEC 1 1 T11 41, RI 1E 4945' NSL 8 1807 Ian 09.431.39 'WM Gil V 00(07V(8) 1111010B KTICPSV GLV 00110274(8y BP Ex pkraitn 1414444 y 5 of 5 III • WELL LOG (.... TRANSMITTAL II. PROActivE DiA SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 � 900 Benson Blvd. - • _ 0 • Anchorage, Alaska 99508 and ( —o�j 0. o�lo-, ProActive Diagnostic Services, Inc. Attn: Robert A. Richey F 130 West International Airport Road `SAY 2' 3 MI Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 � Leak Detection - WLD 29- Mar-11 L -111 BL / EDE 50 -029- 23069 -00 / l 2) Leak Detection - WLD 31-Mar-11 V -119 BL EDE _ + 7 1 -0• Signed : Date : APR 19 2011 Print Name: < << •:n PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E - MAIL : pdsanchoraue(memorvlog.com WEBSITE : www.memorvloa.com C:\Documents and Settings\Diane Williams \Desktop\BP_Transmit.docx NOT OPERABLE: V-119 (PTD #2040410) for Sustained Casing Pressure due to TxIA C... Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, January 14, 2010 10:08 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad LV; GPB, Wells Opt Eng; GPB, Optimization Engr; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Oakley, Ray (PRA) Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: V-119 (PTD #2040410) for Sustained Casing Pressure due to TxIA Communication Attachments: MIT PBU V-119 01-13-10.x1s; V-119.pdf; V-119 TIO Plot 01-09-10.doc AI I, Well V-119 (PTD #2040410) has been confirmed to have TxIA communication with a failing MITIA conducted on 01113/10. The well has een reclassified as Not Operable. Please ensure the well is shut-in and freeze protected as soon as safely possible. A downhole plug will be set to secure the well while further diagnostics are completed. An MITIA form has been included. «MIT PBU V-119 01-13-10.x1s» «V-119.pdf» «V-119 TIO Plot 01-09-10.doc» Please let us know if there are any questions. Thank you, Anna ~u6e, ~ ~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 .y .. ,. ^l r,e~:~a..~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, January 09, 2010 4:27 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Oakley, Ray (PRA) Cc: Quy, Tiffany; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: V-119 (PTD #2040410) for Sustained Casing Pressure on the IA All, Well V-119 (PTD #2040410) is a WAG injector showing signs of TxIA communication while on water injection. The wellhead pressures were tubing/IA/OA equal to 2040/2120/100 psi on 01/09/10. The well has been reclassified as Under Evaluation to perform diagnostics while on injection. The wells most recent AOGCC witnessed MITIA passed on 02/05/09. The plan forward is as follows: ~~ 1. Pumping: MIT-IA to 3000 psi, est LLR if fails ~~~,5 2. WIC. Eval for AA pending MITIA results ~ ~C© 3. APE: Eval for LDL, caliper 4/29/2010 NOT OPERABLE: V-119 (PTD #2040410) for Sustained Casing Pressure due to TxIA C... Page 2 of 2 • A wellbore schematic and TIO plot have been included for reference. « File: V-119.pdf» « File: V-119 TIO Plot 01-09-10.doc» Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4/29/2010 • • V-119 (PTD# 2040410) TIO Plot ~~ ~_ Tbg ~~ Y ~ YY ~"'.«~~ L`.~ !~ ~~~~"~~ J t IA -+- OA i i OOA OOOA Dn Email to:jim.regg~alaska.gov; phcebe.brooks~afaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Expfaration (Alaska}, Inc. Prudhae Bay /PBU ! V pad 01 /13/10 Anna Dube __ Packer h Pretest Initial 15 Min. 30 Min. Well V-119 T In . W ND 6,566` Tut>; 300 380 . Interval O P.T.D. 2040410 T test P Test 1642 Casi 160 3,400 PIF F Notes: MITIA to eval TxIA. IA pressure would rxat exceed OA 100 2780 3400 i while m 'n . LLR of 9.5 at 3400 i. Pressure increase rested on tut>in . Well T In'. ND Tutu Interval P.T.D. T test Test ~ P/F Notes: OA Well T In'. ND Tut-i Interval P.T.D. T test Test P/F Notes: OA Well T In'. ND Tubi Interval P.T.D. T test Test i Casi P/F Notes: OA Well T Iri . ND Tu ~ Interval P.T.D. T test Test Casi PIF Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitorir~ P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Arxxnay Survey D = Dilferenlial Temperature Test INTERVAL Codes I = Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU V-119 01-13-10.x1s ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 t. , f,#st~y~~ ".;~'' ' ~~, ' ~uL:~ i~~;,,~~t~~ti .. ~ bp ~~~~~~~~ OCT 0 ~i 2009 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, Ai~lta Uil & Gas Cons. Ga~mm~~~~n~ AnchorAge ~~~`a~l V~ ~! -! 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 ~ ~ 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 inhibitod 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-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 s0029230740000 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 225 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 2031 Q30 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 13.1 5/9/2009 V-117 2030900 5002923156000~ NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-12t 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 5002923328000o NA 1.5 NA 6.8 5/10/2009 V-2oi 2012220 5002923054000o 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 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6l29/2009 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-215 2070410 500292335t0000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 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 "~ 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 10/10/08 ~~rll~~mb~r~~~i~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN; Beth Wpll .Inh e NO.4923 Company: State of Alaska c ;eats,,)-~, ; ;,r~ r; ,~ ~~ti~ Alaska Oil & Gas Cons Comm w is -~„ i~~~~~ 1~ 1. .~ ? tJti Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 n.. 03-31 12103678 PRODUCTION PROFILE (~ 09/24/08 1~ 1 J-18 12103680 PRODUCTION PROFILE 09/25/08 1 07-306 12083412 MEM CEMENT BOND r at' 09/24/08 1 1 01-10 12034925 LDL -(~C( 10/02/08 1 1 Ot-33 11999052 PRODUCTION PROFILE -~ ~ ( 10/09/08 1 1 J-12 11999049 USIT ~d ' 10/05/08 1 1 06-19A 40017404 OH MWD/LWD EDIT ~ 07/12/08 2 PRINTS & 1 CD HAND DELIVERED SEPARATEILY 10/10/08 H-36A 12005226 MCNL 08/22/08 1 1 V-119 12103677 INJECTION PROFILE G.(~ 09/19!08 1 1 V-119 12103677 SFRT (_ 09/19/08 1 1 L-205L5 40016955 OH MW /LWD EDIT 07/03/08 2 PRINTS & 1 CD HAND DELIVERED SEPARATEILY 10/07/08 nl L-ACC wnvwl ~~wil ~~~~ we. ~~.e~.~ w.. w.w. ....w ..... ~~~..~.....~ .-._ -_. ___ .._..... .. ~~~ ~.~ .._~~.. .-. v.v.,~.,.~~......v . •v ,v~~I~~~~vl vI~IV VVr ~ GF1V ~l 1 V. BP Exploration (Alaska) Inc. ,. -- Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 '' `' ~i~ r Date Delivered • Alaska Data & Consulting Services 2525 Gambell Street, Suit 400 ~ ' Anchorage, AK 99503-2 8 ~% ATTN: Beth Received by: ~~> 10/10/08 5chlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh S N0.4923 Company: State of Alaska Alaska Oil & Gas Cons Comm r . ; *? ~^ Attn: Christine Mahnken ~'t'I~(~ '~` _'_ ~4ai~ e~~ ~- ~ ~° 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i .... ne ...:,,.. 03-31 12103678 PRODUCTION PROFILE - (p 09/24/08 1~ 1 J-18 12103680 PRODUCTION PROFILE 09/25/08 1 1 07-306 12083412 MEM CEMENT BOND r D~ 09/24/08 1 1 01-10 12034925 LDL - <-( ~ 10/02/08 1 1 Oi-33 11999052 PRODUCTION PROFILE -' ~ ( 10!09/08 1 1 J-12 11999049 USIT ~-(} 10/05/08 1 1 06-19A 40017404 OH MWD/LWD EDIT 07/12/08 2 PRINTS & 1 CD HAND DELIVERED SEPARATEILY 10/10/08 H-36A 12005226 MCNL 08/22/08 1 1 V-119 12103677 INJECTION PROFILE u r 09/19/08 1 1 V-119 12103677 SFRT pC~ _ 09/19/08 1 1 L-205L5 40016965 OH MWD/LWD EDIT 07/03/08 2 PRINTS & 1 CD HAND DELIVERED SEPARATEILY 10/07/08 e~ ~wc~o wnvw~nun rra.~ ..~ i.~...~ .... ...... .............~__.._....._ __._ _____ -_ _.. -_ ___ ~_ ..___.. .....-........- ..•.. v..~ vvr ~ ~nv~ ~ ~ v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 "~' `~ Date Delivered: • • Alaska Data & Consulting Services 2525 Gambell Street, Suit 400 -~ i Anchorage, AK 99503-2 8 ATTN: Beth Received by: GCS STATE OF ALASKA 4 ~s, r... ~ .: AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WEL~'L Q1~t~~TIONS ~~ 1. Operations Abandon ~ Repair Well Q , Plug Perforations ~ Stimula4e ~ Other ~ Bright Water Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ Treatment Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ! 204-0410 3. Address: P.O. Box 196612 Stratigraphic Service - ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23201-00-00 7. KB Elevation (ft): 9. Well Name and Number: 81.7 KB PBU V-119 8. Property Designation: 10. Field/Pool(s): ADLO-028245 Prudhoe Bay Field/ Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured 10483 - feet Plugs (measured) None true vertical 6866.86 ~ feet Junk (measured) None Effective Depth measured 10425 ~ feet true vertical 6831.72 - feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 101.1 H-40 30 - 110 30 - 110 1650 650 Production 10447 7" 26# L-80 26 - 10473 26 - 6860.8 7240 5410 29 - 2725.5 5750 3090 Surface 3321 9-5/8" 40# L-80 29 - 3350 ~~jj s , Perforation depth: Measured depth: See Attached - _ _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 10054 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker Premier Packer 9993 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 5114 1000 2034 Subsequent to operation: 2505 300 1253 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~~ WAG ~' ~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 9/24/2008 Form 10-404 Red 04/~O~i6~' s '`~~" ~ f`' ~ ~ _'~ ~' ~'~`"' ~~ I°~ ~ ~) 4~, ~QQ~ Submit Original Only ~ ~ ,` °~ ~. V-119 204-0410 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Me_a_s De th Top Meas Depth Base Tvd Depth Top Tvd Depth Base V-119 6/25/04 PER 10,2 0 8. 10,218. 6,698.78 ~ 6,704 .98 V-119 6/25/04 PER ___ _ . 10,218. 10,236. 6,704.98 _ _ 6,716.13 V-119 6/25/04 PER 10,236. 10,256. 6,716.13 6,728.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • ACTIVITYDATE v-119 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY 8/1/2008 Started pumping the Bright Water chemical into well V-119 at a rate of 76 GPH !EC9378A Polymer) and 44 GPH (EC9360A Surfactant). Started pumping at 1:30 PM on 7-31-08. 8/2/2008-continue to pump the Bright Water project. Pumping (EC9360A) Surfactant at 44 'GPH and (EC9378A) Polymer at 76 GPH, 24 hours a day with a water injection 8/3/2008.continue to pump the Bright Water Project at the rate of (EC9378A) Polymer at 76 ',GPH and (EC9360A) Surfactant at 44 GPH, 24 hours a day. The flow rate of the '°,well is 5100 BPD with a pressure of 2125 psi. 8/4/2008we stopped pumping the Bright Water Injection at 8 pm on 8-3-08 due to chemical ;'.delivery. we called PCC and had the water injection rate lowered to 2000 BPD 'until the injection starts back up. new load of Polymer arrived on pad at 7 am 8-4- '08 and started the (EC9360A) Surfactant back injection at 9:15 am at 44 GPH 'and the (EC9378A) Polymer at 9:45 am at 76 GPH at a pressure of 1650 psi and the water injection rate of 5000 BPD. PCC was called to adjust the water rate at 7 ' am 8-4-08 to 5000 BPD. 8/5/20083Continue to pump the Bright Water chemicals (EC9378A) Polymer at 76 GPH and (EC9360A) Surfactant at 44 GPH at 1700 psi, and the water injection rate is at '' 4900 BPD. ~" 8/6/2008 Continue to pump the Bright Water chemicals (EC9378A) Polymer at a rate of 76 GPH and (EC9360A) Surfactant at a rate of 44 GPH at a pressure of 1800 PSI. The water injection rate is 5100 BPD at 1800 PSL 8/7/2008 Continue to pump Bright Water Chemical (EC9378A) Polymer at 76 GPH and (EC9360A) Surfactant at 44 GPH. Water injection rate is 5100 BPD at 1825 psi. -.the job was completed on V-119 at 4:30 am on 8-7-08. FLUIDS PUMPED GALLONS 6410 Dispersant 9585 Polymer 15995 Total • _~ ~ _ . 111 ~~/CAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing lnspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petratechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~~~ PraActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Internat~nal Airport Road Suite C Anchorage, AK 99518 Fax: 1907) 245-8952 ~ ~ ~, a~~_~~~ ~1~.0~ ~ 1) Temperature Survey 28-Ju1.08 V 119 2) ,) Signed Print Name: ~ Ir, ft's{-t,;-o- ~(~ ~.,~,t.~~ 1 BL / EDE 50-029-23201-00 PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUFTE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL ::? `~ -a~ ~~~~?ai dC~ WE951TE ~Y~~--~i?r'~~ ~;e~C~l.. C:\Documents and Settit~s\Owner\Desktop\Transmit_BP.doc • --- MICROFILMED 03/01/2008 DO NOT PLACE :. sue;.. .~- r~. .. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc Permitto Drill 2040410 ;<s- ~~N DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. PRUDHOE BAY UN BORE V-119 Operator BP EXPLORATION (ALASKA) INC REQUIRED INFORMATION MD 10483 - TVD 6867"""""- Completion Date 6/25/2004 Completion Status 1-01L Current Status WAGIN .s: q¿>' r1;Il ~ '" AP;tJo. 50-029-23201-00-00 UIC Y Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / PWD, PEX-Triple Combo, BHC Sonic, USIT Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc 20 CAse Le( IGg ~g ! og (data taken from Logs Portion of Master Well Data Maint OH/ CH Received Comments 4/29/2004 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 3/2/2004. 4/29/2004 A Directional Survey Log is required to be submitted, This record automatically created from Permit to Drill Module on: 3/2/2004. Name Directional Survey Log Log Scale Media Interval Start Stop Run No Directional Survey Directional Survey Directional Survey Induction/Resistivity 0 (~ ~!t 8/6/2004 0 ,o~tl,.Cl 8/6/2004 2 Blu 3352 1 0460 Open 11/3/2004 5 Blu 3352 1 0460 Open 11/3/2004 5 Blu 5172 1 0400 Case 11/3/2004 2 Blu 110 10483 11/3/2004 2 Blu 110 10483 11/3/2004 2 Blu 3352 10460 11/3/2004 5172 10400 Case 11/3/2004 Sonic Cement Evaluation Induction/Resistivity Induction/Resistivity Caliper log ED C .:¡;fo.L..l~ 12831 Lie Verifi':'atioTl ~~......l . QUAD COMBO PRINT/PLATFORM EXPRESS/BHC SONIC TVD//PLA TFORM EXPRESS/BHC SONIC/MAX TEMP 151F. USIT/CEMENT & CASING EVALUATION (FINAL) VISION RESISTIVITY- CDR-MD FINAL PRINT VISION RESISTIVITY- CDR-TVD FINAL PRINT BOREHOLE PROFILE/CALIPER LOG/MAX TEMP 151F. LDWG EDIT OF USIT/GR/CCLlTENS /DSN 12831 . DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040410 Well Name/No. PRUDHOE BAY UN BORE V-119 Operator BP EXPLORATION (ALASKA) INC MD 10483 TVD 6867 Completion Date 6/25/2004 ED C ,;¡:f-'--I \ 12832 GaA:1mil ~ J",,¿ tt.c..... Completion Status 1-01L Current Status WAGIN 3171 10475 Open 11/3/2004 110 10480 Open 11/3/2004 Sample Set Sent Received Number Comments ED C U S 12833 See Notes Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? ;J¡j) Chips Received? "'-I.l:L- Daily History Received? ÒN r--. Ql)N Formation Tops Analysis Received? Ì'-/-N-- API No. 50-029-23201-00-00 UIC Y LDWG FOR AIT/GRlPEXlBHC/DSN 12832 EDIT FOR MWD/DSN 12833 . Comments: ~ Date: S J~~ ~ b Compliance Reviewed By: . , _ STATE OF ALASKA a ALAS~IL AND GAS CONSERVATION CO.SSION REPORT OF SUNDRY WELL OPERATIONS L .... 1. Operations Performed: .' '.<>.! Abandon D Repair Well 0 Plug perforationsD Stimulate D OtherŒ) .conve~ Alter CasingD Pull TubingD Perforate New Pool D WaiverD TolnjeCtO( Time ExtensionD Change Approved Program D Operation ShutdownO Perforate D Re-enter Suspended wellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 204-0410 3. Address: P.O. Box 196612 . 6. API Numbl Anchorage, AI< 99519-6612 Stratigraphic D ServiceD 50-029-23201-00-00 7. KB Elevation (ft): 9. Well Name and Number: 81.70 V-119 8. Property Designation: 10. Field/Pool(s): ADL-028245 Prudhoe Bay Field / Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured 10483 feet true vertical 6866.9 feet Plugs (measured) None Effective Depth measured 10425 feet Junk (measured) None true vertical 6831.7 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 101.1# H-40 30 - 110 30.0 - 110.0 1650 650 PRODUCTION 10447 7" 26# L-80 26 - 10473 26.0 - 6860.8 7240 5410 SURFACE 3321 9-5/8" 40# L-80 29 - 3350 29.0 - 2725.5 5750 3090 Perforation depth: Measured depth: 10208 - 10218, 10218 -10236, 10236 - 10256 True vertical depth: 6698.78 - 6704.98,6704.98 - 6716.13,6716.13 - 6728.49 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 @ 24 - 10054 Packers & SSSV (type & measured depth): 4-1/2" Baker Premier Packer @ 9993 12. Stimulation or cement squeeze summary: RBDMS BFl FEB 2 8 2005 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1394 0.9 40 188 334 Subsequent to operation: 0 0 2500 420 2153 14. Attachments: 15. Well Class after proposed work: ExploratoryO DevelopmentO Service 00 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ~ OilD GasD WAG [!J GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature Jd /1 ~........ C~~ o ¡-no~. " i64-4EJ57î Date 2/23/05 I Form 10-404 Revised 4/2004 . . V-119 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/18/05 Start WAG Injection FLUIDS PUMPED I BBLS : o TOTAL No Fluids Pumped Page 1 . . . TREE = WB...LHEAD = ACTUA TOR = KB. B...EV = BF. B...EV = KOP= Max Angle = Datum MD = Datum TV D = 4-1/16" CrN FMC NA 82.5' 28.2.' 600' 57 @ 6001' 10180' 6600'SS . V-119 ~OTES: I PBTD I I 2214' H 4-1/2" HES X NIP, ID = 3.813" I 3349' 1--4 ~ GAS LIFT MANDRB...S ST MD TVD DEV TYÆ VLV LA TCH PORT DATE U 6 3127 2598 55 KBG-2 DMY BK 0 12/29/04 5 4343 3306 55 KBG- 2 DMY BK 0 04/21/04 4 5901 4206 56 KBG-2 DMY BK 0 12/29/04 3 7438 5094 54 KBG-2 DMY BK 0 12/29/04 0041 ' 2 8502 5713 54 KBG-2 DMY BK 0 12/29/04 1 9865 6489 53 KBG-2 DMY BK 0 12/29/04 · I I 9931' H 4-1/2" HESXNIP, ID=3.813" I Z ~ 9993' 7" X 4-1/2" BKR PREM A<R I ¡.c::, I · I 10021' - 4-1/2" HES X NIP, ID = 3.813" I · I 10041' - 4-1/2" HES XN NIP, ID - 3.725" I I 10053' I 10054' - 4-1/2" WLEG, ID = 3.958" I 0' I 10143' -1 7" MARKER JT I I perf data [ DATE 06/25/04 ..... 10368' - 7" MARKERJT I I 10425' I I I 10473' I xxx x ~ 9-5/8" CSG, 40#, L-80, ID = 8.835" I Minimum ID = 3.725" @ 1 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#. L-80, .0152 bpf, ID = 3.958" ÆRFORA TlON SUMMARY REF LOG: QUAD ON 04/14/04 ANGLEATTOPÆRF: 52 @ 1021 Note: Refer to Production DB for historica SIZE SPF INTERV AL Opn/Sqz 3-3/8" 6 10208 - 10256 0 I 7" CSG, 26#, L-80. ID = 6.276" DATE 04/21/04 06/15/04 06/25/04 12/29/04 REV BY COMMENTS KAK ORIGINAL COMPLETION JLJ/KAK GLV C/O LDKlKAK IÆRFS RAClTLP GLV C/O DATE REV BY COMMENTS BOREALIS UNIT WB...L: V-119 ÆRMIT No: 2040410 API No: 50-029-23201-00 SEC 11. T11 N, R11 E, 4645' NSL & 1803' WB... BP Exploration (Alaska) TO: Jim Regg 'Ked P.I. Supervisor (1 . zlUI()<; State of Alaska Alaska Oil and Gas Conservation commiss. DATE: Wednesday, February 09, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-Il9 PRUDHOE BAY UN BORE V-I 19 'J"OLt ~ 0 lf ( MEMORANDUM FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ':Jßß-- P.I. Suprv _ ' Comm Well Name: PRUDHOE BAY UN BORE V-II9 API Well Number: 50-029-23201-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050206162514 Permit Number: 204-041-0 Inspection Date: 2/5/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well [ V-119 Type Inj. I P i TVD 6566 I IA ! 320 2520 I 2510 I 2510 r P.T. I 2040410 TypeTest I SPT I Test psi 1641.5 lOA 340 380 I 380 I 380 I Interval INITAL, PIF P Tubing 2370 , 2370 I 2370 i 2370 I I Notes: Pretest pressures were observed and found stable. The well demonstrated good mechanical integrity. SCAtBlED JAN 0 3 2007 NON-CONFIDENTIAL . .. ~.. -.... Wednesday, February 09, 2005 Page I of I Schlumberger NO. 3246 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Altn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job # Log Description Date Color BL CD . V-119 10621776 CH EDIT USIT PDC-GR) 04/20/04 1 1 V-119 40.010393 OH EDIT MWD DATA 04/13/04 2 1 V-119 10621774 OH EDIT AIT/PEX/BHC/GR DATA 04/14/04 3 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ;1 112;6 f I 1 . ~'i--t4( 10/29/04 )--...... e STATE OF ALASKA e ALASKÄ OIL AND GAS CONSERVATION COMMISSION Hnv." 6 "'1'1' REPORT OF SUNDRY WELL OPERATI~S·j ¿UU4 1. Operations Performed: .. Abandon 0 Repair Well 0 PluQ PerforationsD Stimulate 0 Other ŒJ Pre-inj production Alter Casing 0 Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate D Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 204-041. 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ 50-029-23201-00-00 7. KB Elevation (ft): 9. Well Name and Number: 81.70 V-119 8. Property Designation: 10. Field/Pool(s): ADL-028245 Prudhoe Bay Field / Borealis Oil Pool 11. Present Well Condition Summary: Total Depth measured 10483 feet true vertical 6866.9 feet Plugs (measured) None Effective Depth measured 10425 feet Junk (measured) None true vertical 6831.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 101.1# H-40 28 - 108 28.0 - 108.0 1650 650 Production 10447 7" 26# L-80 26 - 10473 26.0 - 6860.8 7240 5410 Surface 3322 9-5/8" 40# L-80 27 - 3349 27.0 - 2724.9 5750 3090 Perforation depth: Measured depth: 10208 -10218,10218 -10236,10236 -10256 True vertical depth: 6698.78 - 6704.98, 6704.98 - 6716.13, 6716.13 - 6728.49 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 - 10054 Packers & SSSV (type & measured depth): 4-112" Baker Premier Packer @ 9993 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl I Gas-Met I Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: New well, no prior production or injection Subsequent to operation: 1530 I 0 I 0 304 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentOO Service 0 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations. ! OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature lj~ C/, fr~ Phone 564-4657 Date 11/5/04 'v RBDMS BFL NOV 1 2 2004 Form 10-404 Revised 4/2004 e e V-119 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/14/04 First day of pre-produced oil production FLUIDS PUMPED BBLS : TOTAL No Fluids Pumped o Page 1 # . STATE OF ALASKA I ALASKA ~L AND GAS CONSERVATION COMM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 09/21/04, Put On Production 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other Pre-Produced Injector o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/25/2004 204-041 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/5/2004 50- 029-23201-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/13/2004 PBU V-119 4645' NSL, 1803' WEL, SEC. 11, T11 N, R 11 E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2048' SNL, 388' EWL, SEC. 13, T11N, R11E, UM 81.7' Prudhoe Bay Field / Borealis Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2262' SNL, 450' EWL, SEC. 13, T11 N, R11 E, UM 10425 + 6832 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 590500 y- 5969892 Zone- ASP4 10483 + 6867 Ft ADL 028245 TPI: x- 592778 y- 5963226 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 592843 y- 5963012 Zone- ASP4 (Nipple) 2214' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / PWD, PEX- Triple Combo, BHC Sonic, US IT 22. ~.'~ LINER AND CEMENTINGRECD~ ~~~~~t ·.SETTING )EI'1'H MD 5eTTINGŒ:PTHTVD ...... WT.Þ~Rl5l" · GRÂbe: "". p(êLE;:[) TOp .. . . I BOTTOM TOP,BOTTOM>·i 20" 91.5# H-40 Surface 108' Surface 108' 42" 260 sx Arctic Set lADDroxJ 9-5/8" 40# L-80 29' 3350' 29' 2725' 12-1/4" 536 sx Arcticset Lite, 288 sx Class 'G' 7" 26# L-80 26' 10473' 26' 6861' 8-3/4" 358 sx LiteCrete, 133 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 124. ................. ........... ,i Jl:IlNb Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10054' 9993' MD TVD MD TVD 10208' - 10256' 6699' - 6728' 1.25. ~ ,y~MI;N I ,è"f~ i' ....... .> DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 74 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 14, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL -BBl GAs-MCF WATER-BBl CHOKE SIZE 1 GAS-OIL RATIO 9/14/2004 4 TEST PERIOD .. 278 328 7 176 1,181 Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 24~ 1,560 24-HoUR RATE 1,667 1,968 42 27. CORE DATA Brief ~escriptio~ of ~ithology, por~~ity, f~actures, apparent dips and presence of oil, gas or water (~1.::0L.. I V~ r...,:Fcessary). SubmIt core chips; If none, state none.. ....( ,. .. (('"'.J " None'~0) ;f»tJ S E P 2 1 2.004 ORIGINAL k 01 & Gas Cons Commission Alas a I . II Anchorage Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE .", 28. GEOLOGIC MARKERS NAME MD TVD Ugnu 3730' 2952' Ugnu M Sands 5965' 4090' Schrader Bluff N Sands 6182' 4364' Schrader Bluff 0 Sands 6471' 4531' Base Schrader Bluff / Top Colville 7091' 4893' HRZ 9702' 6395' Kalubik 10073' 6615' Kuparuk C 10200' 6694' Kuparuk B 10258' 6730' Kuparuk A 10352' 6787' 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECE.\\/\=O SE? 2 1 ?_G04 M \(a 01\ &. Gat as p-ra::Mi\4ge 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys Signed Title 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date oq· Technical Assistant 204-041 Permit No. / A roval No. INSTRUCTIONS GENERAL: This fonm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Terrie Hubble PBU V-119 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Neil Magee, 564-5119 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate fonm for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only a STATE OF ALASKA . ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other Pre-Produced Injector o Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/25/2004 204-041 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/5/2004 50- 029-23201-00-00 4a. Location of Well (Governmental Section): 7. Date T.o. Reached 14. Well Name and Number: Surface: 4/13/2004 PBU V-119 4645' NSL, 1803' WEL, SEC. 11, T11 N, R11 E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2048' SNL, 388' EWL, SEC. 13, T11 N, R11 E, UM 81.7' Prudhoe Bay Field / Borealis Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2262' SNL, 450' EWL, SEC. 13, T11 N, R11 E, UM 10425 + 6832 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 590500 y- 5969892 Zone- ASP4 10483 + 6867 Ft ADL 028245 TPI: x- 592778 y- 5963226 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 592843 y- 5963012 Zone- ASP4 (Nipple) 2214' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / PWD, PEX- Triple Combo, BHC Sonic, USIT 22. CASING, liNER AND CEMENTING RECORD ~~fi~G ., .~EnlÍ/G :J:;PTHMD §ETtING ~~€., ,., WT, PÊR'FT. ·~~[)e ...;;.; PULl-ED Top BØ'I'T'OM Top IB<:rttoM ,.¡¡ 20" 91.5# H-40 Surface 108' Surface 108' 42" ?60 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 3350' 29' 2725' 12-1/4" 536 sx Arcticset Lite, 288 sx Class 'G' 7" 26# L-80 26' 10473' 26' 6861' 8-3/4" 358 sx LiteCrete, 133 sx Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 24. ..,' T 1<> ""t:> ¡¡..¡¡.¡.. ...... .. ii¡iii·iiiiiiiiiiii·' Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10054' 9993' MD TVD MD TVD 10208' - 10256' 6696' - 6728' 25.. [ _.. "Y!~!~. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 74 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test Hours Tested PRODUCTION FOR Oil -BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED ~ Oll-Bsl GAs-MCF W A TER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". j¡J None -=~~-- 031JI!13i\ ORtGtNAL arm ~(:: ~ , Form 10-407 Revised 12 CONTINUED ON REVERSE SIDE RBDMs RFt JUt 2 ~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3730' Ugnu M Sands 5965' Schrader Bluff N Sands 6182' Schrader Bluff 0 Sands 6471' Base Schrader Bluff I Top Colville 7091' HRZ 9702' Kalubik 10073' Kuparuk C 10200' Kuparuk B 10258' Kuparuk A 10352' 2952' None 4090' 4364' 4531' 4893' 6395' 6615' 6694' 6730' 6787' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ - Title Technical Assistant Date 0'7-..2..6'0 PBU V-119 Well Number Prepared By Name/Number: Drillíng Engineer: Terrie Hubble, 564-4628 Neil Magee, 564-5119 204-041 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e 3.88 (ppg) PM :46:51 Printed: 4/30/2004 (psi (psi (ppg) (It t LOT 4/17/2004 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2004 Rig Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 4/4/2004 05:00 - 06:00 1.00 MOB P PRE Blow down pits, and prep Rig for Move 06:00 - 08:00 2.00 MOB P PRE Wait on trucks for move, Rig currently moving on Spine road. 08:00 - 10:30 2.50 MOB P PRE PJSM, With truck drivers, move pits, camp and truck shop, Move rig off V-115 10:30 - 14:00 3.50 MOB P PRE Spot sub on V -119 Level sub and burm necessary equipment. 14:00 - 16:00 2.00 MOB P PRE Lay Matts for pits, spot pits,and cuttings tank, Hook up service lines. 16:00 - 20:00 4.00 RIGU P PRE Accept Rig @ 1600 hrs. 4/4/2004. Nipple Up 20" Hydrill, Riser ,flow line and 16" Diverter line, take on spud mud. 20:00 - 23:30 3.50 RIGU P PRE PJSM. Pickup 26 jts 4" HWDP and 6.5" Jars and rack in Derrick. Function Test diverter. Witness of the diverter test was waived by John Crisp with AOGCC. 23:30 - 00:00 0.50 RIGU P PRE Hoist BHA tools to rig floor 4/5/2004 00:00 - 01 :00 1.00 RIGU P PRE PJSM. Makeup 12.25" BHA as-per Directional Driller 01 :00 - 01 :30 0.50 RIGU P PRE Held Pre-spud meeting with Company rep, Toolpusher, rig crew and service companys 01 :30 - 02:00 0.50 RIGU P PRE PJSM. Rig up Sperry Sun wire line unit, and Gyro 02:00 - 02:30 0.50 RIGU P PRE Make up XO and UBHO sub, makeup top drive 02:30 - 03:00 0.50 RIGU P PRE Fill hole with mud and check for leaks, Test high pressure mud line, for leaks 03:00 - 06:00 3.00 DRILL P SURF Tag Bottom at 108' Drill form 108' to 273' pump rate 450 gpm, with 420 psi. 40 rpm. torque 1,000 ftllbs pick up weigth = 45,000# down weight = 45,000# 06:00 - 06:30 0.50 DRILL P SURF Circulate hole clean at 273' circulating rate 500 9pm @ 650 psi. POH to 83' to pickup remaining BHA 06:30 - 07:30 1.00 DRILL N RREP SURF The Topdrive pipe handler, hydraulic drive motor, that rotates the pipe handler, sheared a pin that holds the gear to the shaft. Made necessary repairs. 07:30 - 08:00 0.50 DRILL P SURF Pickup Remaning BHA, and RIH to 273' 08:00 - 12:00 4.00 DRILL P SURF Directional Drill 12.25" surface hole from 273' to 500'. Pump rate 590 gpm, at 900 psi. WOB = 15,000# ,60 rpm, torque = 1000 ftllbs. off bottom 1,500 ftllbs on bottom. Pickup weight = 55,000# Down weight = 55,000# Ran Gyro Survey @ 380' ART = 4.43 ART = .58 12:00 - 12:30 0.50 DRILL P SURF Held PTSM. Drill from 500' to 560' Pump rate 590 gpm, at 900 psi. WOB = 15,000# ,60 rpm, torque = 1000 ftllbs. off bottom 1,500 ftllbs on bottom. Pickup weight == 55,000# Down weight = 55,000# Strin9 weight = 55,000# ART = .50 12:30 - 13:00 0.50 DRILL P SURF Gyro Survey @ 560' 13:00 - 14:30 1.50 DRILL P SURF Directional Drill 12.25" hole from 560' to 740' Pump rate 550 9pm, at 1080 psi. off bottom 1,200 psi on bottom,WOB == 25,000# ,60 rpm, torque == 1500 ftllbs. off bottom 2,500 ftllbs on bottom. Pickup weight = 60,000# Down weight == 60,000# String weigth = 60,000# ART == .76 AST == .64 14:30 - 15:00 0.50 DRILL P SURF Gyro Survey @ 740' 15:00 - 18:00 3.00 DRILL P SURF Directional Drill 12.25" hole from 740' to 1010' Pump rate 550 gpm, at 1230 psi. off bottom 1,330 psi on bottom,WOB = Printed: 4/30/2004 1 :47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 4/5/2004 4/20/2004 Spud Date: 4/5/2004 End: 4/20/2004 4/5/2004 15:00 - 18:00 3.00 DRILL P SURF 30,000# rotating WaB sliding = 40,000# ,50 rpm, torque = 2,000 ftllbs. off bottom 3,000 ftllbs on bottom. Pickup weight = 70,000# Down weight = 65,000# String weigth = 70,000# ART = .86 AST = 1.13 18:00 - 19:00 1.00 DRILL P SURF PJSM. Rig down Sperry Sun, Gyrodata tools 19:00 - 19:30 0.50 DRILL P SURF Directional Drill 12.25" hole from 1,010' to 1052' Pump rate 550 gpm, at 1230 psi. off bottom 1,330 psi on bottom,WOB = 30,000# rotating WaB sliding = 40,000# ,50 rpm, torque = 2,000 ftllbs. off bottom 3,000 ftllbs on bottom. Pickup weight = 70,000# Down weight = 65,000# String weigth = 70,000# AST = .54 19:30 - 20:00 0.50 DRILL N RREP SURF Repair drag chain, The chain jumped the sprocket on the drive motor end, Removed master link, put chain back over sprocket, and reconnected chain. 20:00 - 00:00 4.00 DRILL P SURF Directional Drill 12.25" hole from 1,052' to 1,393 ' Pump rate 550 gpm, at 1220 psi. off bottom 1,495 psi on bottom, WOB = 35,000# rotating WaB sliding = 40,000# ,60 rpm, torque = 3,000 ftllbs. off bottom 4,500 ftllbs on bottom. Pickup weight = 75,000# Down weight = 65,000# String weigth = 70,000# ART = 1.32 AST = 1 .4 4/6/2004 00:00 - 03:30 3.50 DRILL P SURF Directional Drill 12.25" hole from 1 ,393' to 1 ,776' Pump rate 550 gpm, at 1630 psi. off bottom 1,870 psi on bottom, WOB = 30,000# rotating WaB sliding = 40,000# ,60 rpm, torque = 3,000 ftllbs. off bottom 6,500 ftllbs on bottom. Pickup weight = 80,000# Down weight = 68,000# String weigth = 78,000# ART = 1.19 AST = 1.37 03:30 - 04:15 0.75 DRILL P SURF Circulate bottoms up pump 550 gpm @ 1,650 psi. rotating 60 rpm. 04:15 - 06:00 1.75 DRILL P SURF POH to BHA, Monitor well 06:00 - 07:00 1.00 DRILL P SURF Change Bit and adjust motor to 1.5 deg. 07:00 - 09:30 2.50 DRILL P SURF RIH to 1,673' no problem, wash last stand from 1,673' to 1,776' 09:30 - 12:00 2.50 DRILL P SURF Directional Drill 12.25" hole from 1 ,776' to 2,200' Pump rate 545 gpm, at 2030 psi. off bottom 2200 psi on bottom, WOB = 30,000# rotating WaB sliding = 40,000# ,60 rpm, torque = 3,500 ftllbs. off bottom 6,000 ftllbs on bottom. Pickup weight = 85,000# Down weight = 65,000# String weigth = 78,000# ART = 1.34 AST = .46 12:00 - 19:30 7.50 DRILL P SURF Held PTSM. Directional Drill 12.25" hole from 2,200' to 3,360 ' Pump rate 650 gpm, at 2795 psi. off bottom 2840 psi on bottom, WOB = 30,000# rotating WOB sliding = 40,000# ,110 rpm, torque = 4,000 ftllbs. off bottom 7,000 ftllbs on bottom. Pickup weight = 90,000# Down weight = 65,000# String weigth = 80,000# ART = 3.55 AST = 1.57 19:30 - 21 :30 2.00 DRILL P SURF Circulate until shakers are clean, pump rate 650 gpm, @ 2750 psi. Rotating drill string 110 rpm. Keeping bit within 40' of bottom. Printed: 4/30/2004 1 :47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 4/5/2004 4/20/2004 Spud Date: 4/5/2004 End: 4/20/2004 4/6/2004 21 :30 - 00:00 2.50 DRILL P SURF POH. Pull to 2,420' started seeing excess drag of 20-30k and partial swabbing, Makeup Topdrive and pumped from 2,420 to 1,678' with 500 gpm. 1530 psi. Monitor well. ok 4/7/2004 00:00 - 00:45 0.75 DRILL P SURF Held PTSM. RIH from 1,678 to 3,360', no hole problems, no fill 00:45 - 02:15 1.50 DRILL P SURF Circulate 2.5 bottoms up, pumping 650 gpm, 2,710 psi. rotating drill string 110 rpm. circulated until shakers are cllean. monitor well. 02:15 - 05:30 3.25 DRILL P SURF PJSM. POH SLM, pulled to 1,844, started seeing some over pull 20-30k Made up Topdrive and pumped out to 1,720' with 400 gpm 1050 psi. did not experience any further problems. Monitor well at BHA (SLM no correction) 05:30 - 07:30 2.00 DRILL P SURF Lay down BHA, Clear rig floor of all directional tools. 07:30 - 09:00 1.50 CASE P SURF Rig up 9.625" Casing equipment 09:00 - 09:30 0.50 CASE P SURF Pickup 9.625" Landing joint and hanger, and make dummy run. 09:30 - 12:00 2.50 CASE P SURF PJSM. With Co.Rep and Toolpusher, Run 9.625" 40# L-80 BTC. Casing 12:00 - 15:30 3.50 CASE P SURF PTSM. Continue running 9.625" 40# L-80 BTC. casing to 3,349' Casing went to bottom without problems. Ran a total of 80 Joints. 15:30 - 16:30 1.00 CEMT P SURF Circulate and condition mud for cement job, with Franks fill up tool, pump rate 500 gpm @ 800 psi. 16:30 - 17:00 0.50 CEMT P SURF Lay down Franks tool and Makeup cement head. 17:00 - 18:30 1.50 CEMT P SURF Circulate and condition mud, pump rate 500 gpm @ 800 psi. 18:30 - 19:30 1.00 CEMT N WAIT SURF Continue Circulating at 500 gpm.@ 800 psi. Waiting on Dowell Cementers 19:30 - 20:00 0.50 CEMT P SURF Pump 5 bbls water and test lines to 3,500 psi. Drop bottom plug and Pump 75 bbls 10.3 ppg Mudpush initial rate 5 bpm @ 300 psi. final rate 3 bpm. @ 200 psi. Dowell having problems, with Slurry pump. (Had no cement in pipe) 20:00 - 21 :00 1.00 CEMT N CEMT SURF Shut down cementing operation, Dowells primary slurry pump went down, unable to get cement from mixing tank to cement pump, rig up to secondary pump. 21 :00 - 23:30 2.50 CEMT P SURF Began pumping 10.7 ppg Lead cement, Initial rate 5 bpm @ 560 psi, pumped at this rate for 50 bbls, then transfer pumps in brine tanks were not able to supply enough water to keep pumping at 5 bpm. Slowed rate to 3 bpm. @ 200 psi. stayed at this rate until 130 bbls pumped. while a Vac truck, with 80 deg water was hooked directly to Dowell, to supply water. Increased rate to 7 bpm. @ 695 psi. maintained this rate while pumping remainder of lead cement, final rate was 7 bpm. @ 730 psi. Pumped a total of 427 bbls 10.7 ppg. lead cement. Began pumping Tail cement weighted to 15.8 ppg. rate 6.8 bpm @ 1450 psi. final rate 6.8 bpm @ 1470 psi. pumped a total of 60 bbls. Dropped top plug and pumped 10 bbls water, switched to rig pumps started displacing at 12 bpm.@ 1100 psi. At 70 bbls into the displacement, started getting mudpush back to surface, continued pumping at 12 bpm. @ 1380 psi. At 186 bbls. into displacment had good 10.6 ppg cement to surface. Diverted cement to cellar, and slowed rate to 3 bpm. @ 1020 psi. Bumped plug with calculated strokes, pressured up to 3,500 psi. Bled pressure off. Floats held. 63 bbls clean cement to surface. Full returns through out job. CIP @ 11:10 23:00 - 00:00 1.00 CEMT P SURF PTSM. Rig down cement lines,and cement head. Printed: 4/30/2004 1:47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2004 Rig Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 PTSM. Rig down casing equipment, Flush cement from diverter system, back out landing joint, Nipple down 20" riser,flow line, Hydril, 16" diverter line. 03:30 - 07:00 3.50 SURF Nipple up FMC starting head, and Nipple up BOPS 07:00 - 07:30 0.50 SURF Rig up BOP test equipment 07:30 - 12:00 4.50 SURF Test BOPS to 250 psi low, 4000 psi. high, annular to 250 low, 3,500 high, as-per 7-ES testing procedure. Witness of the BOP test was waived By John Spalding AOGCC. 12:00 - 12:30 0.50 SURF Rig down testing equipment, pull test plug and install wear bushing 12:30 - 15:00 2.50 P PROD1 RIH picking up 60 joints 4" DP, POH rack back in derrick 15:00 - 18:00 3.00 P PROD1 Pickup 8.75" Intermedieate BHA, orient MWD tools,and change out jars, RIH with 4" HWDP, Shallow test MWD. 18:00 - 20:30 2.50 P PROD1 RIH with 8.75" BHA Picking up 4" DP, RIH to 3218' 20:30 - 21 :00 0.50 P PROD1 Circulate Bottoms up @ 450 gpm with 900 psi. 21 :00 - 22:00 1.00 P PROD1 Rig up testing equipment, and test casing to 3500 psi. record on chart. Rig down test equipment. 22:00 - 00:00 2.00 P PROD1 Drill cement and float equipment from 3,265' to 3,347', pump rate 450 gpm @ 950 psi, 40 rpm, torque 2000 ftIlbs. pickup weigth = 85,000# down weight = 73,0003 rotating weigth = 80,000# Change over to new 9.5 ppg. LSND while drilling the shoe track. 4/9/2004 00:00 - 01 :00 1.00 P PROD1 PTSM Drill float shoe from 3,347' to 3,349' and 20' of new hole to 3,380' pump rate 450 gpm @ 1000 psi, 40 rpm. 3-8K wob. 01 :00 - 01 :30 0.50 P PROD1 Circulate bottoms up, pump rate 450 gpm @ 1,000 psi, prior to LOT. mud weigth 9.5 ppg. 01 :30 - 02:00 0.50 P PROD1 Perform LOT with 9.5 ppg Mud @ 2731 TVD (Shoe). Leak off Pressure = 621 psi LOT = 13.87 ppg. EMW. Establish baseline clean hole ECD. With 120 rpm, 530 gpm ECD = 10.25, 120 rpm 550 gpm. ECD = 10.29, 120 rpm 580 gpm ECD = 10.3, Calculated clean hole ECD is 10.0 02:00 - 12:00 10.00 P PROD1 Directional Drill 8.75" hole from 3,380' to 5,178 pump rate 580 gpm @ 1,850 psi. off bottom, 1,980 psi on bottom, 120 rpm. torque on bottom = 5,500 ftIlbs torque off bottom = 4000 ftllbs. Pickup weigth = 105,0000# Down weight = 85,000# rotating weight = 90,000#. Encountered Hydrates @ 3500' at 3700' Hydrates had cleaned up. Maintaining a 10.6 to 10.8 ECD ART = 3.46 AST = 1,17 12:00 - 00:00 12.00 P PROD1 Directional Drill 8.75" hole from 5,178' to 6,970' pump rate 580 gpm @ 2480 psi. off bottom, 2850 psi on bottom, 120 rpm. torque on bottom = 7200 ftllbs to 10,000 ftIlbs torque off bottom = 5500 ftIlbs. Pickup weigth = 125,0000# Down weight = 90,000# rotating weight = 107,000#. ART = 4.78 AST = 1.77 4/10/2004 00:00 - 11 :00 11.00 P PROD1 Directional Drill 8.75" hole from 6,970' to 8,481' pump rate 580 gpm @ 3500 psi. off bottom, 3860 psi on bottom, 120 rpm. torque on bottom = 10,000 ftIlbs, off bottom = 7,500 ftllbs. Pickup weigth = 144,0000# Down weight = 95,000# rotating weight = 115,000#. ECD = 11.7 Calculated clean hole ECD = 11.1 Began adding 12.3 ppg spike fluid at 8,000' to increase weight to 10.1 ppg. by 8,380' the mud was 10.1 ppg Printed: 4/30/2004 1 :47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2004 Rig Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 4/10/2004 00:00 - 11 :00 11.00 P PROD1 ART = 4.92 AST = 2.22 11 :00 - 12:00 1.00 N DPRB PROD1 Drill string packed off after connection, @ 8,481 '. Up weight remained 144,000#. Unable to circulate, back ream out to 8,290' pumping at 1 bpm with 550 psi. no returns, hole swabbing .Working pipe out of hole 45,000#, overpull torque 23,800 ftllbs At the time the hole packed off (lost returns) had a sweep on the back side @ 4,600' 12:00 - 00:00 12.00 N DPRB PROD1 Continue back reaming out from 8,290' to 4,500', At 7,500' torque and drag decreased, when bit reached depth of the reamer. Up weight was normal with a occasional spike to 10-20k over, Torque has been fluctuating from 9,000 ftllbs to 20,000 ftllbs. Unable to establish circulation Tried working string down, in an attempt to un ball BHA, this did not help. Continue pumping @ .5 to .7 bpm. 550 to 600 psi, to keep hole full. Hole continues to swab while back reaming. Mud losses from noon to Midnight were 26 bbls. 4/11/2004 00:00 - 09:30 9.50 N DPRB PROD1 Continue back reaming out from 4,500'. Hole continues to swab. At 3,480' we saw a indication on the flow meter 2%, which is the most that has been seen so far, tried working pipe back down slow, no circulation.Down movement of the drill string pushes mud away. No increase in torque or drag pulling into the shoe. With the bit inside 9.625" casing, still unable to circulate. Continue backreaming, 20-100 rpm, Torque 4,000 to 5,000 ftllbs. pumping .5 to 1.0 bpm. with 400 to 500 psi. Losses from midnight 14 bbls. 09:30 - 11 :30 2.00 N DPRB PROD1 Stand back DC's and LD remaining BHA. From HWDP to bit, all BHA was balled up. 11 :30 - 12:00 0.50 N DPRB PROD1 Clean rig floor of cuttings that were stripped from BHA. 12:00 - 14:30 2.50 N DPRB PROD1 Lubricate rig, service TDS, change dies in TDS grabber 14:30 - 15:30 1.00 N DPRB PROD1 PJSM, Slip and cut drilling line 15:30 - 17:00 1.50 N DPRB PROD1 P/U BHA, bit, motor, MWD, adjust motor and orient same 17:00 - 17:30 0.50 N DPRB PROD1 RIH to 1,008', Flow test MWD. 475 GPM, 1127 psi, 195 SPM 17:30 - 18:30 1.00 N DPRB PROD1 RIH 3,298' 18:30 - 19:00 0.50 N DPRB PROD1 Circ 1 btm's up. MW 10.1, 350 GPM, 1062 psi. 19:00 - 19:30 0.50 N DPRB PROD1 RIH from 3,298' to 4,367' 19:30 - 20:00 0.50 N DPRB PROD1 Circ 1 btm's up. MW 10.1, 386 GPM, 1367 psi., 158 SPM 20:00 - 20: 15 0.25 N DPRB PROD1 RIH from 4,367' to 5,308' 20:15 - 20:45 0.50 N DPRB PROD1 Circ and condition hole. MW 10.1, 400GPM, 1583 psi., 10.9 ECD 20:45 - 21 :00 0.25 N DPRB PROD1 RIH from 5,308' to 6,265 21 :00 - 21:45 0.75 N DPRB PROD1 Circ and condition hole. MW 10.1,354 GPM, 1477 psi., 10.9 ECD 21 :45 - 22:15 0.50 N DPRB PROD1 RIH from 6,265 to 7,200' 22:15 - 23:15 1.00 N DPRB PROD1 Circ and condition hole. MW 10.1,400 GPM, 1800 psi., 10.8 ECD 23:15 - 00:00 0.75 N DPRB PROD1 RIH from 7,200' to 8,273' 4/12/2004 00:00 - 02:30 2.50 N DPRB PROD1 Wash and ream from 8,273' to bottom 8,481'. On initial circulation a sudden increase in pump pressure of 300 psi was noted, at the same time there was a loss of returns. Immediately slowed pump rate to 1 BPM, regained circulation and continued washing to bottom. 02:30 - 12:00 9.50 P PROD1 Drill from 8,481' to 9,326 (TVD 6,190'). ART = 3.72 AST = 1,95 Printed: 4/30/2004 1 :47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2004 Rig Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 4/12/2004 02:30 - 12:00 9.50 P PROD1 PU=160K SO = 103K RT = 125K 580 GPM off btm = 4200 psi 550 GPM on btm = 4300 psi 120 RPM Off btm torq = 7900 On btm torq = 9200 12:00 - 21 :00 9.00 P PROD1 Drill from 9,326' to 10,861'. ART = 4.26 AST = 1.67 PU = 175K SO = 100K RT = 135K 580 GPM off btm = 4186 psi 556 GPM on btm = 4278 psi 120 RPM Off btm torq = 6000 On btm torq = 8000 21 :00 - 23:00 2.00 N RREP PROD1 Wash pipe packing began leaking. POOH from 10,186 to 9,613 in order to position bit approximately 100' above top of HRZ. 200K maximum P/U weight observed. 23:00 - 00:00 1.00 N RREP PROD1 PJSM. Change out wash pipe packing on TDS. Circulate hole with 10.1 ppg mud at 104 SPM, 246 GPM, 1,103 psi through head pin and cement line while effecting repairs. Clear all personnel and equipment from TDS and reciprocate pipe every 10 minutes to assure pipe remains free. No problems encountered. 4/13/2004 00:00 - 01 :00 1.00 DRILL N RREP PROD1 PJSM. Continue changing out wash pipe packing on TDS. Circulate hole with 10.1 ppg mud at 104 SPM, 246 GPM, 1,103 psi through head pin and cement line while effecting repairs. Clear all personnel and equipment from TDS and reciprocate pipe every 10 minutes to assure pipe remains free. No problems encountered. 01 :00 - 01 :30 0.50 DRILL N RREP PROD1 TIH from 9,613'. Precautionary wash last stand to bottom. No fill encountered. 01 :30 - 04:30 3.00 DRILL P PROD1 Drill from 10,186' to 10,474' 523 GPM @ 4360 psi. Torque on Bottom = 9850 ft/lbs P/U Wt. = 175K, S/O Wt. = 11 OK, ROT WI. = 130K. Calculated ECD = 10.95 ppg. Actual ECD = 11.11 ppg. 04:30 - 06:00 1.50 DRILL P PROD1 Circulate and condition mud prior to wiper trip while repairing pop-off on #1 pump. 290 GPM @ 1550 psi. Rot @ 120 RPM 06:00 - 06:30 0.50 DRILL P PROD1 Drill additional 8 3/4" Hole to 10,483'. Same parameters. Daily total ART = 2.23 Hrs. 06:30 - 07:00 0.50 DRILL P PROD1 Circulate - 560 GPM @ 4300 psi. Rotating @ 130 RPM. 07:00 - 10:30 3.50 DRILL P PROD1 Wiper Trip - Pump out of Hole to 9,613', POH to 8369'. RIH to 10,378' Precautionary wash to 10,483'. 10:30 - 12:00 1.50 DRILL P PROD1 Condition Mud, Circulate 45 bbl. Hi -Vis Sweep / 550 GPM @ 4250 psi Reciprocate & Rotat @ 130 RPM w/8500 ftllbs of Torque. 12:00 - 14:00 2.00 DRILL P PROD1 Pump out of Hole from 10,483 to 9,560. @ 194 GPM & 800 psi. Drop 2.25" Rabbit. 14:00 - 19:00 5.00 DRILL P PROD1 POH from 9560' to 1008'. 19:00 - 21:00 2.00 DRILL P PROD1 Stand Back HWDP. UD BHA. Clear & Clean Floor. 21 :00 - 23:00 2.00 EVAL P PROD1 PJSM with SWS & Crew. R/U SWS w/ PEX + BHC Sonic. 23:00 - 00:00 1.00 EVAL P PROD1 RIH wI PEX / BHCS on E- Line. 4/14/2004 00:00 - 05:00 5.00 EVAL P PROD1 Continue Logging down w/ PEX + BHC Sonic. Worked through somewhat sticky sections @ 3461', 6389', 6701'. 6830', 7181' & 7916'. Able to work through all with no excessive drag up. Stopped @ 8118' - unable to work through - possibly a sand / shale ledge. Log up through Shrader. POH, UD Logging Tools. 05:00 - 05:30 0.50 EV AL P PROD1 Lay Down Jars and 2 singles HWDP. Printed: 4/30/2004 1:47:02 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 4/5/2004 Ríg Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 4/14/2004 05:30 - 00:00 18.50 EV AL P PROD1 RIH w/ DP Conveyed PEX and BHCS breaking circulation at Shoe 3349' and every 1000' of open hole. RIH to 7932'. R/U SWS Sheave in Derrick. P/U wet Latch and SES. RIH w/ Wet Latch and connect to tools. Log down from 7932' to 9360'. Log up to 7932' POH w/ E-Line & Wet Latch. UD SES. RIH w/ DP to 9143'. R/U SES. RIH w/ Wet Latch on E-Line and Latch Up. RIH to 10460' Logging down. Log up from 10,460'. P/U Wt = 180 K Down Wt. = 105K. No Drag on tools. Hole Stable - No Losses. 4/15/2004 00:00 - 02:00 2.00 EVAL P PROD1 Continue logging up w/ DPC PEX & BHCS to 9300'. 02:00 - 03:30 1.50 EVAL P PROD1 POH w/ Wet latch & E-Line. UD Wet latch, E-Line, W/L Sheaves & SES. 03:30 - 08:30 5.00 EVAL P PROD1 POH w/ DP & DPC Tools. UD Logging tools. Clear & Clean floor. 08:30 - 10:00 1.50 CLEAN P COMP P/U & M/U 8 3/4" Clean - Out BHA. 10:00 - 10:45 0.75 CLEAN P COMP RIH w/ C/O BHA on 4" DP to 3280'. 10:45 - 11 :30 0.75 CLEAN P COMP Condition Mud & Circulate Bottoms Up - 365 GPM @ 850 psi. 80 RPM reciprocating 30 ft. 11:30 -13:15 1.75 CLEAN P COMP Continue RIH to 7012'. 13:15 - 14:00 0.75 CLEAN P COMP Circulate & Condition 450 GPM @ 2333 psi. 14:00 - 16:00 2.00 CLEAN P COMP RIH to 9977'. encountering some drag. work down to 10168'. 16:00 - 20:15 4.25 CLEAN P COMP Ream from 10168' to 10483'. Torqueing Up and packing off. Worked through w/260 GPM & 35 RPM. 20:15 - 00:00 3.75 CLEAN P COMP Circulate Hole Clean. Stage up pumps & Rotary to 550 GPM @ 3850 psi. wi 130 RPM. With first Bottoms Up pressure down to 3475 psi. Pump Hi- Vis Sweep. 4/16/2004 00:00 - 00:30 0.50 CLEAN P COMP Complete Circulating Hi-Vis sweep. Clay and little sand over shaker w/ sweep. 00:30 - 01:15 0.75 CLEAN P COMP POH Wiping Hole. Pulled 20K to 30K over beginning @ 10385'. Worked through tight spots - wiped clean. Pulled tight @ 10232'. Unable to work down. Pipe Stuck. 01 :15 - 05:00 3.75 CLEAN N STUC COMP Work pipe Jarring down. Spot 9.4 ppg. Lube Pill around BHA. Continue Jarring down. Pipe free @ 05:00 Hrs. 05:00 - 06:00 1.00 CLEAN P COMP Circulate staging up Pumps to 500 GPM - 2900 psi. 06:00 - 07:30 1.50 CLEAN P COMP Backream out from 10264' to 9690'.500 GPM 2900 to 3000 psi. with 50 rpm 07:30 - 10:30 3.00 CLEAN COMP Circulate Hi-Vis sweep then spot 294 Bbl. G-Seal Pill from 7000' up to 9 5/8" Casing shoe @ 3349'. 10:30 - 15:00 4.50 CLEAN P COMP POH standing back DP & HWDP. 15:00 - 16:30 1.50 CLEAN P COMP UD BHA #5. Clear Floor. 16:30 - 17:30 1.00 BOPSU P COMP Change out Top Pipe Rams to 7" Casing. Test Door seals to 3500 psi. 17:30 - 20:30 3.00 CASE P COMP R/U to run 7" Prod. Casing. R/U Franks Fill up Tool. Make Dummy run w/landing Jt & Hgr. 20:30 - 21 :00 0.50 CASE P COMP P/U & M/U Shoe & Float Jt. Attempt to pump through float equip. w/ Franks Tool. Pressured up to 950 psi. Unable to pump. 21 :00 - 22:00 1.00 CASE N SFAL COMP Check rig surface equip. - OK. UD Franks tool. Contact GBR - on the way with replacement check valve. Rig up pump in sub and cement line & pump through floats - OK. 22:00 - 22:30 0.50 CASE P COMP Run in Hole with 3 more Jts 7" Casing. 22:30 - 23:30 1.00 CASE N SFAL COMP Check valve replaced. P/U & R/u Franks tool. Pump through Printed: 4/30/2004 1 :47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 4/5/2004 4/20/2004 Spud Date: 4/5/2004 End: 4/20/2004 4/16/2004 22:30 - 23:30 1.00 CASE N SFAL COMP same - OK. 23:30 - 00:00 0.50 CASE P COMP Continue to run 7", 26#, L-80, BTC-M Production Casing as per Program. 4/17/2004 00:00 - 03:00 3.00 CASE P COMP Continue to run 7" Production Casing, centralizing as per program. Run in to 3329'. 80 Jts total. 03:00 - 03:45 0.75 CASE P COMP Circulate 130 bbls, staging up to 7 BPM. No losses. 03:45 - 17:30 13.75 CASE P COMP Continue to run 7" casing in open Hole. Filling pipe every Jt, Breaking circulation every 10 Jts. and circulating 3 Jts. down every 35 Jts. Installing centralizers as per program. Total 254 Jts 7",26#, L-80, BTC-M Casing run + 2 ea. 20 ft. Marker Jts w/ RA Pip Tags. Shoe @ 10'473' & Float Collar @ 10,429'. Excellent returns throughout run. Only 20 Bbls Mud Lost to Hole. Circulate Landing Jt Down with Franks Tool. 17:30 - 18:30 1.00 CEMT P COMP Circulate Bottoms Up. Stage pumps up to 8 BPM w/1 006 psi & no losses. Reciprocate Casing continuously. 18:30 - 19:00 0.50 CEMT P COMP Land Hanger & Break out & UD Franks Tool. R/U Cement Head & Lines. 19:00 - 21 :00 2.00 CEMT P COMP Circulate & Condition Mud for Cement job @ 7 BPM & 910 psi. Vis = 53, YP = 15 Continue Reciprocation. Hold PJSM with Crew & Dowell. Following PJSM: Dowell Batch Mixing MudPush & Tail Cement. 21 :00 - 23:30 2.50 CEMT P COMP Dowell pressure test lines to 4000 psi. Pump 40 Bbls, 11.1 ppg MudPush @ 4.5 BPM. Drop bottom Plug Batch & Pump 157 bbls, 12.0 ppg, Class 'G' Crete Slurry w/ yield of 2.46 cU.ftIsk. Pump 28.5 Bbls., 15.8 ppg, Class 'G' Slurry w/ yield of 1.2 cu.ftlsk. Wash out Cement line to trough. Switch to Rig Pumps and chase Top Plug with 400 Bbl. 10.1 ppg Mud. Pump 1 st. 305 bbls @ 7 BPM, next 37 Bbls @ 5 BPM, next 23 bbls @4 BPM and the remaining 35 Bbls @ 2 BPM. 400 Bbls Total Displacement. Bumped plug w/ 938 psi and increased pressure to 4000 psi. 100 % Returns throughout Job. Reciprocated until Tail Cement was around Shoe. Got a bit sticky & landed Hanger in Head. 23:30 - 00:00 0.50 CASE P COMP Hold and Chart the 4000 psi. Casing Pressure Test for the required 30 Minutes. 4/18/2004 00:00 - 02:00 2.00 CASE P COMP Bleed Off Casing pressure test, R/D Cement Head, Back out Landing jt. RID all Casing Equipment Change out Bails 02:00 - 03:00 1.00 WHSUR P COMP FMC Install Pack - Off, R.I.L.D.S. & test to 4000 psi./10 Minutes - OK 03:00 - 04:30 1.50 BOPSU P COMP Remove 7" Casing Rams and Install 3 1/2" X 6" Variables Pressure test Door Seals to 4000 psi. Set Wear Bushing. 04:30 - 06:00 1.50 EVAL P COMP PJSM. Pressure test Lines to 3000 psi. Perform LOT on 7" X 9 5/8" Annulus. 10.0 ppg Mud, 2731 TVD & Leak Off @ 300 psi surface Pressure. LOT = 12.11 ppg. EMW. Established Injectivity - 1 BPM @ 800 psi. Pumped 9 Bbls, 10.0 ppg Mud into Annulus. 06:00 - 07:00 1.00 CLEAN P COMP Bring 7" Scraper BHA to Floor. , M/U Same & RIH on 4" DP. 07:00 - 08:00 1.00 CLEAN P COMP Service Top Drive. 08:00 - 12:00 4.00 CLEAN P COMP RIH w/ Bit & Scraper. Tagged plugs @ 10,425'. Simultaneous Printed: 4/30/2004 1 :47:02 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/5/2004 Rig Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 4/18/2004 08:00 - 12:00 4.00 CLEAN P COMP Ops -In 7" X 9 5/8" annulus - Injected 20 Bbls, 10.0 ppg Mud then 25 bbls, 12.5 ppg Mud, followed by 55 bbls Dead Crude to Freeze Protect. 12:00 - 13:30 1.50 CLEAN P COMP Displace 7" Casing from Mud to 8.5 ppg. Seawater. 13:30 - 14:00 0.50 CLEAN P COMP Clean Surface equipment, Flow Line, Shakers & Trough. 14:00 - 16:00 2.00 CLEAN P COMP Cut & Slip Drilling line 123'. Service Crown. 16:00 - 19:30 3.50 CLEAN P COMP POH standing back 70 srtands 4" DP for move to V -110. 19:30 - 22:00 2.50 CLEAN P COMP POH, Laying Down 92 Jts 4" DP. 22:00 - 23:00 1.00 CLEAN P COMP UD 7" Scraper BHA. 23:00 - 23:30 0.50 EV AL P COMP PJSM. R/U SWS E-Line. 23:30 - 00:00 0.50 EV AL P COMP RIH with US IT on E-Line. 4/19/2004 00:00 - 05:00 5.00 EV AL P COMP Logging USIT in 7" Production Casing. Log from 10,400' up to 5,200'. TOC at +/- 5,625'. Marginal cement across Kuparuk. Bruce Smith notified & sent log bye-mail. Bruce called back after review and said to proceed - sufficient isolation. 05:00 - 06:00 1.00 P COMP POH. PJSM & R/D SWS E-Line. 06:00 - 06:30 0.50 COMP Clear Rig Floor. Pull Wear Bushing. 06:30 - 09:00 2.50 COMP C/O Bails & Rig Up to run 4.5" Completion. 09:00 - 19:00 10.00 COMP Run 4.5", 12.6#, L-80, TC-II Completion as per program. 19:00 - 19:30 0.50 RREP COMP Adjusted Electronic Motion Sensor on Skate 19:30 - 23:00 3.50 COMP Continue Running 4.5" Completion. Total 238 Jts, 4.5",12.63, L-80, TC-II Tubing. All TC-II Joints Made Up 1st Time. No Rejected Joints. For Detail refer to "Well bore Equipment Report" in DIMS. 23:00 - 00:00 COMP R/D Compensator, M/U Tubing Hanger & landing Jt. Drain Stack. Land 4.5" Tubing Hanger - verified by FMC Rep. 4/20/2004 00:00 - 00:30 0.50 COMP R.I.L.D.S. on Tubing Hanger and Torque to 450 ftllbs by FMC Rep. 00:30 - 01 :30 1.00 COMP Reverse Circulate 48 Bbls Filtered Seawater treated w/ Corrosion Inhibitor and spot by following w/138 Bbls. Filtered Seawater. Pump @ 3 BPM. 01 :30 - 03:30 COMP Drop Roller Ball/ Rod Assy. Pressure Tubing to 4000 psi. Hold and Chart for 30 Minute test. Bleed tubing to 2500 psi. & Pressure Annulus to 4000 psi. Hold and Chart for 30 Minute test. Bleed Annulus to '0', then Tubing to '0'. Pressure Annulus to 2400 psi to shear DCK Valve In GLM # 3. Pump through both ways to verify good shear - OK. Premier Packer Set @ 9,993'. 03:30 - 04:00 COMP RID Testing Equipment. Back out & LID Landing JI. Drain Stack & have FMC Rep set TWC w/ 'T' Bar. Test from below to 1000 psi. 04:00 - 05:30 1.50 BOPSU P COMP Nipple Down BOPE. 05:30 - 07:00 1.50 WHSUR P COMP Nipple Up Adapter Flange & Tree 07:00 - 08:00 1.00 WHSUR P COMP Test Adapter Flange & Tree to 5000 psi - OK. 08:00 - 08:30 0.50 WHSUR P COMP R/U DSM Lubricator. Pull TWC. R/D Lubricator. 08:30 - 11 :00 2.50 RUNCO COMP R/U Little Red to 4.5" X 7" Annulus. Pressure test lines to 2500 psi. Pump 74 Bbls Diesel down Annulus @ 2.4 BPM. Allow to U - Tube to Freeze Protect Tubing & Annulus to 2200' MD. 11 :00 - 11 :30 0.50 WHSUR P COMP Set BPV w/ DSM. Test from below to 1000 psi. 11 :30 - 12:00 0.50 WHSUR P COMP R/D Lines. Install Gauges. Secure Well. Printed: 4/30/2004 1 :47:02 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-119 V-119 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 4/5/2004 Rig Release: 4/20/2004 Rig Number: Spud Date: 4/5/2004 End: 4/20/2004 4/20/2004 11 :30 - 12:00 0.50 WHSUR P COMP RIG RELEASED @ 12:00 HRS, 4/20/2004. Printed: 4/30/2004 1 :47:02 PM e e V-119 Prudhoe Bay Unit 50-029-23201-00-00 204-041 Accept: Spud: Release: Ri: 04/04/04 04/05/04 04/20/04 Nabors 7ES POST RIG WORK 06/13/04 PULLED BALL & ROD @ 10,000' WLM. PULLED STA# 1 (DGLV) @ 9839' SLM. 06/14/04 PULLED DGLV FROM STA# 2 @ 8476' SLM. PULLED DGLV FROM STA# 3 @ 7410' SLM. PULLED DCK-3 (SHEARED) FROM STA# 4 @ 5873' SLM. PULLED DGLV FROM STA# 6 @ 3105' SLM. SET GLV IN STA# 6, SET GLV IN STA# 4 @ 5873' SLM. SET GLV IN STA# 3 @ 7410' SLM. SET GLV IN STA# 2 @ 8476' SLM. ALL HAVE BK LATCHES. 06/15/04 SET OGLV 3/8" PORT @ 9839' SLM. PULL RHC-M PLUG BODY @ 10004' SLM. NOTIFIED PAD OP. OF WELL STATUS. 06/24/04 DRIFT WI 3 318" DUMMY GUN TAG TD @ 10397' SLM (TARGET DEPTH 10,210'). ZEROED TOOL 28' (KB) ABOVE GROUND LEVEL. DID NOT ADJUST DEPTH DURING GYRO LOG. RUN #1: GYRO FROM 0' - 10397'. TAGGED TO AT 10397'. 06/25/04 A 5 RUN JOB CONSISTING OF; A GYRO, PRESSURE TEMPERATURE PROFILE WIJEWELRY LOG AND 3 PERF RUNS WERE COMPLETED. TO WAS TAGGED @ 10420'. WELL WAS PERFORATED FROM 10208'- 10256' WITH 3 3/8" HSD POWERJET GUNS LOADED 6 SPF. ALL SHOTS WERE FIRED. WELL DID NOT . BUILD PRESSURE AFTER FIRING GUNS. WHP AT RD WAS 100 PSI. WELL WAS LEFT SHUT IN WAITING ON MOBILE TEST SEPERATOR. PAD OPERATOR NOTIFIED. RDMO. e e ò V-119 Survey Report Schlumberuer Report Date: April 26, 2004 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad f Plan V-119 (S-F) Well: V-119 Borehole: V-119 UWlfAPI#: 500292320100 Survey Name I Date: V-119/ April 9, 2004 Torti AHD I DDII ERD ratio: 134.794·/7289.80 ftf 6.176/1.062 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70 19 38.938, W 14915 57.804 Location Grid NIE YIX: N 5969892.070 ftUS, E 590499.790 ftUS Grid Convergence Angle: ->().69110892· Grid Scale Factor: 0.99990930 Survey I DLS Computation Method: Minimum Curvature f Lubinski Vertical Section Azimuth: 161.900· Vertical Section Origin: N 0.000 It, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 81.70 ftrelative to MSL Sea Bed I Ground Level Elevation: 53.70 ftrelative to MSL Magnetic Declination: 25.022· Total Field Strength: 57562.174 nT Magnetic Dip: 80.814· Declination Date: April 09, 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North '" True North: +25.022· local Coordinates Referenced To: Well Head 458.00 1.38 344.19 457.99 376.29 -2.13 2.21 1.98 -0.81 0.97 0.97 -0.86 5969894.04 590498.96 N 70.32748812 W 149.26606321 547.00 2.00 353.19 546.95 465.25 -4.73 4.83 4.55 -1.28 0.76 0.70 10.11 5969896.61 59049845 N 70.32749515 W 149.26606707 637.00 1.25 247 636.91 555.21 -7.19 7.38 7.09 -143 0.88 -0.83 10.31 5969899.15 590498.28 N 70.32750209 W 149.26606824 663.85 0.26 3344 663.76 582.06 -7.50 7.72 744 -1.38 3.86 -3.69 115.34 596989949 590498.32 N 70.32750303 W 149.26606786 754.38 143 138.92 754.28 672.58 -6.59 8.87 6.76 -0.52 1.68 1.29 116.51 5969898.82 590499.18 N 70.32750117 W 149.26606092 845.19 3.03 147.95 845.02 763.32 -3.21 1240 3.87 149 1.80 1.76 9.94 5969895.96 590501.24 N 70.32749328 W 149.26604456 936.66 4.76 153.65 936.27 854.57 2.89 18.61 -1.58 446 1.94 1.89 6.23 5969890.54 590504.27 N 70.32747839 W 149.26602049 1031.67 7.94 153.92 1030.69 948.99 13.29 29.11 -11.01 9.10 3.35 3.35 0.28 5969881.17 590509.02 N 70.32745263 W 149.26598290 1127.88 11.07 15507 1125.56 1043.86 2905 45.00 -25.36 15.91 3.26 3.25 1.20 5969866.91 590516.01 N 70.32741343 W 149.26592763 1223 03 15.62 155.03 1218.12 113642 50.85 66.95 -45.27 25.18 4.78 4.78 -0.04 5969847.12 590525.51 N 70.32735905 W 149.26585252 1319.43 19.57 156.14 1309.99 1228.29 79.81 96.09 -71.81 37.19 4.11 4.10 1.15 5969820.72 590537.84 N 70.32728654 W 149.26575510 1414.77 2147 156.08 1399.28 1317.58 113.06 129.51 -102.36 50.72 1.99 1.99 -0.06 5969790.34 590551.74 N 70.32720307 W 149.26564535 1510.02 23.64 156.12 1487.24 1405.54 14940 166.04 -135.76 65.53 2.28 2.28 0.04 5969757.12 590566.94 N 70.32711182 W 149.26552534 1606.23 28.30 156.74 1573.71 1492.01 191.33 208.16 -174.37 82.35 4.85 4.84 0.64 5969718.72 590584.23 N 70.32700633 W 149.26538892 170241 29.59 154.51 1657.88 1576.18 237.59 254.70 -216.76 101.57 1.75 1.34 -2.32 5969676.57 590603.96 N 70.32689054 W 149.26523304 1795.93 31.78 156.17 1738.30 1656.60 285.00 30242 -260.13 12146 2.51 2.34 1.78 596963344 590624.37 N 70.32677204 W 149.26507177 1890.87 34.17 157.30 1817.94 1736.24 33646 354.09 -307.61 141.86 2.60 2.52 1.19 5969586.23 590645.33 N 70.32664235 W 149.26490642 1986.77 36.89 157.73 1895.98 1814.28 392.02 409.81 -359.10 163.16 2.85 2.84 045 5969535.00 590667.25 N 70.32650168 W 149.26473368 2081.57 41.32 157.27 1969.52 1887.82 451.62 469.59 -414.32 186.05 4.68 4.67 -049 5969480 06 590690.80 N 70.32635081 W 149.26454811 2176.66 44.11 157.72 2039.38 1957.68 515.93 534.09 -473.91 210.73 2.95 2.93 047 5969420.78 590716.20 N 70.32618802 W 149.26434800 2273.32 47.60 158.24 2106.69 2024.99 585.12 603.44 -538.20 236.72 3.63 3.61 0.54 5969356.81 590742.96 N 70.32601237 W 149.26413725 2368.64 51.32 157.62 2168.64 2086.94 657.37 675.87 -605.32 263.94 3.93 3.90 -0.65 5969290.03 590770.99 N 70.32582902 W 149.26391654 2464.01 55.14 159.21 2225.72 2144.02 733.60 752.25 -676.35 292.02 4.22 4.01 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5968107.71 591187.83 N 70.32258512 W 149.26065317 3997.94 55.61 162.67 3104.52 3022.82 1990.26 2009.12 -1868.16 690.59 0.66 0.22 0.75 5968032.55 591212.80 N 70.32237897 W 149.26045812 4092.84 54.91 162.57 3158.60 3076.90 2068.24 2087.11 -1942.58 713.89 0.74 -0.74 -0.11 596795842 591236.99 N 70.32217565 W 149.26026934 4188.79 53.27 163.28 3214.87 3133.17 2145.94 2164.82 -2016.86 736.71 1.81 -1.71 0.74 596788442 591260.70 N 70.32197271 W 149.26008438 4284.73 53.88 163.52 3271.84 3190.14 2223.11 2242.01 -2090.84 758.76 0.67 0.64 0.25 5967810.72 591283.64 N 70.32177060 W 149.25990566 4380.14 54.94 164.37 3327.36 3245.66 2300.64 2319.60 -216540 780.22 1.33 1.11 0.89 596773643 591305.99 N 70.32156690 W 149.25973181 4476.07 55.22 164.12 3382.28 3300.58 2379.24 2398.26 -2241.11 801.57 0.36 0.29 -0.26 5967661 .00 591328.26 N 70.32136008 W 149.25955874 4571.56 53.96 164.39 3437.61 3355.91 2457.00 2476.08 -2316.01 822.69 1.34 -1.32 0.28 5967586.36 591350.28 N 70.32115544 W 149.25938760 4666.75 54.32 165.11 3493.37 3411.67 2534.05 2553.23 -239044 842.98 0.72 0.38 0.76 5967512.19 59137146 N 70.32095210 W 149.25922318 4762.56 54.08 165.13 354941 3467.71 2611.63 2630.94 -2465.54 862.94 0.25 -0.25 0.02 5967437.34 591392.32 N 70.32074692 W 149.25906149 4857.67 53.71 165.67 360546 3523.76 2688.33 2707.78 -2539.90 882.31 0.60 -0.39 0.57 5967363.23 591412.59 N 70.32054377 W 149.25890454 4953.24 53.72 164.71 3662.02 3580.32 2765.24 2784.82 -2614.38 902.00 0.81 0.01 -1.00 5967289.00 591433.17 N 70.32034030 W 149.25874499 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) Plan V-119 (S-F)\V-119\V-119\V-119 Generated 4/26/2004 3:00 PM Page 1 of 2 e e 5144.61 54.82 165.20 3775.18 3693.48 2919.28 2939.14 -2763.66 941.11 1.72 1.67 -0.52 5967140.22 591474.07 N 70.31993246 W 149.25842813 5241.42 55.30 164.31 3830.63 3748.93 2998.54 3018.50 -2840.23 961.98 0.90 0.50 -0.92 5967063.92 591495.86 N 70.31972328 W 149.25825905 5336.86 54.97 164.72 3885.18 3803.48 3076.77 3096.81 -2915.69 982.88 0.49 -0.35 0.43 5966988.71 591517.68 N 70.31951711 W 149.25808965 5431.87 55.42 164.41 3939.41 3857.71 3154.70 3174.82 -2990.89 1003.65 0.54 0.47 -0.33 5966913.78 591539.34 N 70.31931166 W 149.25792143 5528.02 55.26 164.26 3994.09 3912.39 3233.71 3253.91 -3067 04 1025.00 0.21 -0.17 -0.16 5966837.90 591561.61 N 70.31910362 W 149.25774843 5623.85 55.09 163.77 4048.82 3967.12 3312.33 3332.57 -3142.67 1046.67 0.46 -0.18 -0.51 5986762.55 591584.18 N 70.31889701 W 149.25757292 5719.23 54.82 163.55 4103.59 4021.89 3390.38 3410.66 -3217.60 1068.63 0.34 -0.28 -0.23 5966687.89 591607.05 N 70.31869229 W 149.25739494 5815.11 55.63 161.51 4158.28 4076.58 3469.12 3489.41 -3292.71 1092.28 1.94 0.84 -2.13 5966613.08 591631.60 N 70.31848708 W 149.25720336 5911.44 56.19 160.62 421227 4130.57 3548.89 3569.19 -3368.17 1118.17 0.96 0.58 -0.92 5966537.94 591658.40 N 70.31828093 W 149.25699361 6006.54 56.52 159.81 4264.96 4183.26 3628.02 3648.36 -3442.66 1144.97 0.79 0.35 -0.85 5966463.78 591686.09 N 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5923.44 5841.74 5968.87 5989.80 -5660.59 1893.90 0.85 -0.73 0.51 5964255.26 592461.65 N 70.31201781 W 149.25071079 8972.56 54.90 163.29 5978.49 5896.79 6048.12 6069 08 -5736.53 1916.68 0.67 -0.67 -0.03 5964179.61 592485.34 N 70.31181033 W 149.25052640 9068.14 53.42 162.99 6034.46 5952.76 6125.59 6146.56 -5810.68 1939.15 1.57 -1.55 -0.31 5964105.74 592508.70 N 70.31160775 W 149.25034449 9163.23 52.70 163.45 6091 .60 6009.90 6201.57 6222.56 -5883.44 1961.09 0.85 -0.76 0.48 5964033.25 592531.51 N 70.31140894 W 149.25016684 9259.18 54.71 162.75 6148.40 6066.70 6278.88 6299.89 -5957.43 1983.57 2.18 209 -0.73 5963959.55 592554.89 N 70.31120680 W 149.24998481 9355.23 56.02 161.72 6202.99 6121.29 6357.90 6378.92 -6032.68 2007.69 1.62 1.36 -1.07 5963884.60 592579.91 N 70.31100119 W 149.24978957 9451.08 56.62 163.09 6256.14 6174.44 6437.66 6458.68 -6108.71 2031.80 1.34 0.63 1.43 5963808.87 592604.93 N 70.31079347 W 149.24959441 9546.81 57.00 162.81 6308.55 6226.85 6517.76 6538.79 -6185.30 2055.29 0.47 0.40 -0.29 5963732.58 592629.34 N 70.31058421 W 149.24940426 9641.36 56.21 163.84 6360.59 6278.89 6596.67 6617.73 -6260.92 2077.94 1.24 -0.84 1.09 5963657.25 592652.90 N 70.31037762 W 149.24922088 9737.33 55.45 165.11 6414.49 6332.79 6675.99 6697.13 -6337.42 2099.20 1.35 -0.79 1.32 5963581.02 592675.07 N 70.31016860 W 149.24904884 9832.57 53.73 165.21 6469.67 6387.97 6753.48 6774.75 -6412.45 2119.08 1.81 -1.81 0.11 5963506.24 592695.86 N 70.30996361 W 149.24888793 9929.05 52.61 165.59 6527.51 6445.81 6830.56 6851.97 -6487.18 2138.55 1.20 -1.16 0.39 5963431.75 592716.22 N 70.30975944 W 149.24873038 10025.20 52.28 164.65 6586.11 6504.41 6906.67 6928.20 -6560.85 2158.12 0.85 -0.34 -0.98 5963358.34 592736.68 N 70.30955817 W 149.24857198 10119.17 51.92 164.24 6643.84 6562.14 6980.74 7002.35 -6632.28 2178.00 0.52 -0.38 -0.44 5963287.15 592757.42 N 70.30936301 W 149.24841105 10215.94 51.65 164.19 6703.70 6622.00 7056.71 7078.38 -6705.45 2198.68 0.28 -0.28 -0.05 5963214.25 592778.98 N 70.30916311 W 149.24824366 10311.05 52.20 164.20 6762.36 6680.66 7131.52 7153.25 -6777.49 2219.08 0.58 0.58 0.01 5963142.47 592800.24 N 70.30896629 W 149.24807862 10407.66 52.72 163.43 6821.22 6739.52 7208.08 7229.85 -6851.05 2240.43 0.83 0.54 -0.80 5963069.17 592822.48 N 70.30876529 W 149.24790560 10483.00 52.72 163.43 6866.86 6785.16 7268.01 7289.80 -6908.51 2257.53 0.00 0.00 0.00 5963011.93 592840.26 N 70.30860831 W 149.24776743 Leaal Description: Northina IVI IftUS! Eastina IXI IftUSl Surface: 4645 FSL 1804 FEL S11 T11N R11E UM 5969892.07 590499.79 BHL: 3017 FSL 4833 FEL S13 T11N R11E UM 5963011.93 592840.26 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) Plan V-119 (S-F)\V-119\V-119\V-119 Generated 4/26/2004 3:00 PM Page 2 of 2 1REE= WELLHEAD = AClUA TOR = KB. B..EV = BF KO fila Ca Ca 4-1/16" CIW FMC NA 82.5' V-119 I SAFETY NOTES: . B..EV = 28.2.' P- 600' x Angle - 57 @ 6007' turn rvo - 1 0180' . 2214' 4-1/2"HESXNIP,ID=3.813" I turn lVD= 6600'SS I I 9-5/8" CSG, 40#, L-80, ID = 8.835" 3349' 1---4 It. GAS LIFT MANæB..S ST rvo lVD DEV lYÆ VLV LATŒi FORT" DATE W 6 3127 2598 55 KBG-2 DOME BK 16 06/15/04 5 4344 3307 55 KBG-2 DMY BK 0 04/21/04 4 5902 4207 56 KBG-2 DOME BK 16 06/15/04 3 7438 5094 54 KBG-2 DOME BK 16 06/15/04 2 8502 5713 54 KBG-2 DOME BK 16 06/15/04 1 9866 6490 53 KBG-2 SO BK 24 06/15/04 Minimum ID = 3.725" @ 10041' 4-112" HES XN NIPPLE I 9931' 4-1/2" HES X NP, 10= 3.813" I tg ~ 9993' 7" x 4-112" BKR PRBIA R<R I I.2S I I 10021' 4-1/2" HES X NIP, 10 - 3.813" I I I 10041' 4-1/2" I-ES XN NIP,ID = 3.725" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 =3.958" 10053' J-- ') I 10054' 4-112" WLEG, D =3.958"1 PERFORA nON SUMMARY REF LOG: QUAD ON 04/14/04 ANGLEAT TOP PERF: 52@ 10210' I\bte: Refer to A'oductbn œ for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 10143' H 7" MA RKER JT I 3-3/8" 6 10208 - 10256 0 06/25/04 111 .... 10368' 7" MARKERJT I I PBm I 10425' I 7" G 2 - = " , CS , 6#, L 80, ID 6.276 H 10473 DATE 04/21/04 06/15/04 06/25/04 REV BY COMrvENTS KAK ORIGINAL COMPLETION JLJ/KAK GLV C/O LDKiKA K IÆRFS DATE REV BY COfv'lli1ENTS BOREA LIS UNIT WB..L: V -119 ÆRMT I\b: 2040410 APII\b: 50-029-23201-00 SEC 11, T11 N, R11 E. 4645' NSL & 1803' WEL BP Exploration (Alaska) e e RECEIVED Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Alaska Oil & Gas Cons. Commiss on Anchorage Customer BP Exploration Dispatched To: Robin Deason Well No V-119 Date Dispatched: 4-Apr-04 Installation/Rig Nabors 7ES Dispatched By: N.Rose Data No Of Prints No of Floppies Surveys 2 Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 nrosel@slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, 10-02-03 Schlumberger Private Å(J ~l- CJL( ( ~ Client. . . . . . . . . . . . . . . . . . .: BPXA Field. . . . . . . . . . . . . . . . . . . .: BPU-WOA Well.....................: V-119 API number...............: 50-029-23201-00 Engineer....... ........ ..: B.Barnes Rig:.. .......... .........: Nabors 7ES STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference........ ..: Drillers Pipe Tally GL above permanent.......: 53.7 ft KB above permanent.......: N/A Top Drive OF above permanent.......: 81.7 ft ----- Vertical section origin---------------- Latitude (+N/S-) ..... ....: 0.00 ft Departure (+E/W-) ..... ...: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) .........: -999.25 ft Departure (+E/W-)........: -999.25 ft SCHLUMBERGER Survey report Azimuth from rotary table to target: 161.90 degrees [(c)2004 IDEAL 108 1C_01] 13-Apr-2004 11:17:22 Spud date....... . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 5-Apr-04 13-Apr-04 112 0.00 ft 10483.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2003 Magnetic date............: 04-Apr-2004 Magnetic field strength..: 1151.26 HCNT Magnetic dec (+E/W-) .....: 25.03 degrees Magnetic dip.............: 80.81 degrees ----- MWD survey Reference Reference G..............: Reference H. ........... ..: Reference Dip.......... ..: Tolerance of G...........: Tolerance of H... ........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.26 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.03 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.03 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction e ~ ~ I ~ ~) ü r"\ e ~ SCHLUMBERGER Survey Report 13-Apr-2004 11:17:22 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (it) Incl angle (deg) Azimuth angle (deg) Course length (it) TVD depth (it) Vertical section (it) Displ +N/S- (it) Displ +E/W- (it) Total displ (it) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 1 2 3 4 5 0.00 100.00 200.00 284.00 368.00 0.00 0.07 0.05 0.11 0.51 1. 38 2.00 1. 25 0.26 1. 43 3.03 4.76 7.94 11. 07 15.62 19.57 21.47 23.64 28.30 29.59 31.78 34.17 36.89 41. 32 44.11 47.60 51.32 55.14 56.41 55.57 0.00 300.71 298.90 303.15 344.96 344.19 353.19 2.47 33.44 138.92 147.95 153.65 153.92 155.07 155.03 156.14 156.08 156.12 156.74 154.51 156.17 157.30 157.73 157.27 157.72 158.24 157.62 159.21 159.97 159.66 [(c)2004 IDEAL ID8_1C_Ol] 6 7 8 9 10 458.00 547.00 637.00 663.85 754.38 11 12 13 14 15 845.19 936.66 1031.67 1127.88 1223.03 16 17 18 19 20 1319.43 1414.77 1510.02 1606.23 1702.41 21 22 23 24 25 1795.93 1890.87 1986.77 2081. 57 2176.66 26 27 28 29 30 2273.32 2368.64 2464.01 2559.59 2656.09 0.00 100.00 100.00 84.00 84.00 90.00 89.00 90.00 26.85 90.53 90.81 91. 47 95.01 96.21 95.15 96.40 95.34 95.25 96.21 96.18 93.52 94.94 95.90 94.80 95.09 96.66 95.32 95.37 95.58 96.50 0.00 100.00 200.00 284.00 368.00 457.99 546.95 636.91 663.76 754.28 845.02 936.27 1030.69 1125.56 1218.12 1309.99 1399.28 1487.24 1573.71 1657.88 1738.30 1817.94 1895.98 1969.52 2039.38 2106.69 2168.64 2225.72 2279.48 2333.45 0.00 -0.05 -0.12 -0.21 -0.65 -2.13 -4.73 -7.19 -7.50 -6.59 -3.21 2.89 13.29 29.05 50.85 79.81 113.06 149.40 191. 33 237.59 285.00 336.46 392.02 451. 62 515.93 585.12 657.37 733.60 812.57 892.51 0.00 0.03 0.08 0.15 0.55 1. 98 4.55 7.09 7.44 6.76 3.87 -1. 58 -11.01 -25.36 -45.27 -71.81 -102.36 -135.76 -174.37 -216.76 -260.13 -307.61 -359.10 -414.32 -473.91 -538.20 -605.32 -676.35 -750.42 -825.50 0.00 -0.05 -0.14 -0.24 -0.41 -0.81 -1. 28 -1. 43 -1.38 -0.52 1. 49 4.46 9.10 15.91 25.18 37.19 50.72 65.53 82.35 101.57 121.46 141.86 163.16 186.05 210.73 236.72 263.94 292.02 319.57 347.17 0.00 0.06 0.17 0.28 0.68 2.14 4.73 7.24 7.56 6.78 4.15 4.73 14.28 29.94 51. 80 80.87 114.24 150.75 192.84 239.38 287.09 338.74 394.43 454.18 518.65 587.96 660.36 736.70 815.63 895.53 0.00 300.71 300.23 300.89 323.50 337.84 344.27 348.63 349.48 355.56 21.11 109.53 140.44 147.89 150.92 152.62 153.64 154.24 154.72 154.89 154.97 155.24 155.56 155.82 156.03 156.26 156.44 156.65 156.93 157.19 DLS (deg/ 100f) 0.00 0.07 0.02 0.07 0.52 0.97 0.76 0.88 3.86 1. 68 1. 80 1. 94 3.35 3.26 4.78 4.11 1. 99 2.28 4.85 1. 75 2.51 2.60 2.85 4.68 2.95 3.63 3.93 4.22 1. 48 0.91 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ TIP Gyro Survey Gyro Survey Gyro Survey Gyro Survey Gyro Survey Gyro Survey Gyro Survey Gyro Survey MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 13-Apr-2004 11:17:22 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 2752.06 2847.42 2942.68 3038.70 3133.41 36 37 38 39 40 3229.68 3289.11 3422.09 3518.97 3614.97 41 42 43 44 45 3710.88 3806.26 3901.84 3997.94 4092.84 46 47 48 49 50 4188.79 4284.73 4380.14 4476.07 4571.56 51 52 53 54 55 4666.75 4762.56 4857.67 4953.24 5049.60 56 57 58 59 60 5144.61 5241.42 5336.86 5431.87 5528.02 57.53 55.94 55.06 55.25 54.49 56.00 55.36 52.90 53.39 53.20 53.62 55.76 55.40 55.61 54.91 53.27 53.88 54.94 55.22 53.96 54.32 54. 08 53.71 53.72 53.23 54.82 55.30 54.97 55.42 55.26 161.11 160.67 160.25 163.23 162.66 162.21 161. 94 161.45 161. 92 162.20 162.24 161.97 161. 95 162.67 162.57 163.28 163.52 164.37 164.12 164.39 165.11 165.13 165.67 164.71 165.69 165.20 164.31 164.72 164.41 164.26 [(c)2004 IDEAL 108 lC 01] 95.97 95.36 95.26 96.02 94.71 96.27 59.43 132.98 96.88 96.00 95.91 95.38 95.58 96.10 94.90 95.95 95.94 95.41 95.93 95.49 95.19 95.81 95.11 95.57 96.36 95.01 96.81 95.44 95.01 96.15 2386.35 2438.66 2492.61 2547.48 2601. 98 2656.86 2690.37 2768.28 2826.39 2883.77 2940.94 2996.07 3050.09 3104.52 3158.60 3214.87 3271.84 3327.36 3382.28 3437.60 3493.37 3549.41 3605.46 3662.02 3719.37 3775.18 3830.63 3885.18 3939.41 3994.09 972.54 1052.26 1130.74 1209.53 1286.98 -900.92 -976.26 -1050.24 -1125.07 -1199.12 1366.07 -1274.52 1415.15 -1321.22 1522.90 -1423.52 1600.42 -1497.11 1677.38 -1570.34 1754.39 -1643.67 1832.22 -1717.73 1911.06 -1792.70 1990.26 -1868.16 2068.24 -1942.58 2145.94 -2016.86 2223.11 -2090.84 2300.64 -2165.40 2379.24 -2241.11 2457.00 -2316.01 2534.05 -2390.44 2611.63 -2465.54 2688.33 -2539.90 2765.24 -2614.38 2842.54 -2689.24 2919.28 -2763.66 2998.54 -2840.23 3076.77 -2915.69 3154.70 -2990.89 3233.71 -3067.04 374.04 400.14 426.40 451.08 473.80 497.67 512.78 546.61 570.97 594.68 618.19 642.11 666.53 690.59 713.89 736.71 758.76 780.22 801.57 822.69 842.98 862.94 882.31 902.00 921.78 941.11 961.98 982.88 1003.65 1025.00 975.48 1055.08 1133.50 1212.13 1289.33 1368.24 1417.24 1524.86 1602.30 1679.17 1756.08 1833.82 1912.60 1991. 72 2069.60 2147.20 2224.26 2301.68 2380.14 2457.79 2534.72 2612.19 2688.79 2765.61 2842.84 2919.50 2998.71 3076.90 3154.80 3233.79 157.45 157.71 157.90 158.15 158.44 158.67 158.79 158.99 159.12 159.26 159.39 159.50 159.60 159.71 159.82 159.93 160.05 160.19 160.32 160.44 160.57 160.71 160.84 160.96 161.08 161.19 161.29 161.37 161.45 161.52 DLS (deg/ 100f) 2.40 1.71 0.99 2.55 0.94 1. 61 1.14 1. 87 0.64 0.31 0.44 2.26 0.38 0.66 0.74 1. 81 0.67 1. 33 0.36 1. 34 0.72 0.25 0.60 0.81 0.96 1.72 0.90 0.49 0.54 0.21 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 13-Apr-2004 11:17:22 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 5623.85 5719.23 5815.11 5911.44 6006.54 55.09 54.82 55.63 56.19 56.52 55.57 55.30 54.83 54.44 53.69 54.41 54.70 54.47 54.05 53.86 54.64 55.02 54.75 53.89 54.12 53.77 54.01 55.02 55.18 54.66 54.33 53.89 54.39 55.00 54.66 163.77 163.55 161.51 160.62 159.81 159.60 160.54 161.16 161.23 161. 73 161.80 162.46 163.28 162.88 163.38 163.05 162.31 163.06 162.48 161.69 161.03 160.95 160.19 160.31 160.27 160.17 160.42 160.29 160.15 159.88 [(c)2004 IDEAL ID8_1C_01J 66 67 68 69 70 6102.28 6198.13 6294.47 6389.21 6485.01 71 72 73 74 75 6580.19 6675.83 6771.89 6867.27 6963.34 76 77 78 79 80 7059.34 7154.29 7250.25 7346.47 7441.46 81 82 83 84 85 7537.29 7632.96 7728.65 7824.62 7919.64 86 87 88 89 90 8016.12 8111.45 8207.45 8302.57 8398.14 95.83 95.38 95.88 96.33 95.10 95.74 95.85 96.34 94.74 95.80 95.18 95.64 96.06 95.38 96.07 96.00 94.95 95.96 96.22 94.99 95.83 95.67 95.69 95.97 95.02 96.48 95.33 96.00 95.12 95.57 4048.82 4103.59 4158.28 4212.27 4264.96 4318.44 4372.82 4427.99 4482.82 4539.04 4594.92 4650.38 4706.05 4761.76 4818.29 4874.38 4929.07 4984.27 5040.39 5096.22 5152.62 5209.00 5264.55 5319.46 5374.07 5430.10 5485.99 5542.22 5597.20 5652.24 3312.33 -3142.67 3390.38 -3217.60 3469.12 -3292.71 3548.89 -3368.17 3628.02 -3442.66 3707.38 -3517.15 3786.27 -3591.35 3865.23 -3665.96 3942.48 -3739.09 4020.05 -3812.64 4097.10 -3885.82 4175.01 -3959.98 4253.29 -4034.79 4330.69 -4108.86 4408.35 -4183.19 4486.24 -4257.78 4563.85 -4331.88 4642.33 -4406.82 4720.48 -4481.47 4797.33 -4554.59 4874.80 -4628.00 4952.08 -4701.08 5029.98 -4774.55 5108.65 -4848.63 5186.38 -4921.84 5264.89 -4995.74 5342.09 -5068.45 5419.87 -5141. 73 5497.46 -5214.77 5575.54 -5288.19 1046.67 1068.63 1092.28 1118.17 1144.97 1172.51 1199.42 1225.33 1250.23 1274.87 1298.98 1322.89 1345.95 1368.48 1391. 02 1413.52 1436.63 1459.99 1483.14 1506.78 1531.54 1556.72 1582.64 1609.24 1635.46 1662.04 1688.08 1714.24 1740.51 1767.21 3312.38 3390.42 3469.15 3548.93 3628.07 3707.44 3786.34 3865.32 3942.57 4020.14 4097.19 4175.10 4253.37 4330.76 4408.41 4486.29 4563.89 4642.37 4720.51 4797.36 4874.84 4952.12 5030.02 5108.71 5186.45 5264.96 5342.17 5419.96 5497.56 5575.66 161.58 161. 63 161. 65 161. 63 161. 60 161.56 161. 53 161.52 161. 51 161.51 161.52 161.53 161.55 161.58 161.61 161. 63 161. 65 161. 67 161.69 161.69 161.69 161.68 161.66 161.64 161. 62 161. 60 161. 58 161.56 161. 54 161. 52 DLS (deg/ 100f) 0.46 0.34 1. 94 0.96 0.79 1. 01 0.86 0.72 0.42 0.89 0.76 0.64 0.74 0.56 0.46 0.86 0.75 0.70 1. 02 0.72 0.67 0.26 1. 24 0.20 0.55 0.35 0.51 0.53 0.65 0.42 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA · SCHLUMBERGER Survey Report -------- ------ ------- -------- ------ ------- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 Incl angle (deg) Azimuth angle (deg) 13-Apr-2004 11:17:22 Page 5 of 5 TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- 95.28 95.53 95.89 95.58 95.62 96.52 95.58 95.09 95.95 96.05 95.85 95.73 94.55 95.97 95.24 96.48 96.15 93.97 96.77 95.11 96.61 75.34 5707.80 5762.90 5816.69 5869.84 5923.44 5978.50 6034.46 6091.61 6148.40 6202.99 6256.14 6308.55 6360.59 6414.49 6469.67 6527.51 6586.11 6643.84 6703.70 6762.35 6821. 22 6866.86 5652.90 -5360.89 5730.90 -5434.32 5810.27 -5509.29 5889.71 -5584.84 5968.87 -5660.59 6048.12 -5736.53 6125.59 -5810.68 6201.57 -5883.44 6278.88 -5957.43 6357.90 -6032.68 6437.66 -6108.71 6517.76 -6185.30 6596.67 -6260.92 6675.99 -6337.42 6753.48 -6412.45 6830.56 -6487.18 6906.67 -6560.85 6980.74 -6632.28 7056.71 -6705.45 7131.52 -6777.49 1793.79 1820.20 1846.28 1870.85 1893.90 1916.68 1939.15 1961.09 1983.57 2007.69 2031.80 2055.29 2077.94 2099.20 2119.08 2138.55 2158.12 2178.00 2198.68 2219.08 5653.03 5731. 06 5810.43 5889.86 5969.01 6048.25 6125.70 6201. 67 6278.97 6358.00 6437.75 6517.83 6596.74 6676.04 6753.52 6830.58 6906.68 6980.75 7056.72 7131. 52 At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 11210483.00 91 92 93 94 95 8493.42 8588.95 8684.84 8780.42 8876.04 8972.56 9068.14 9163.23 9259.18 9355.23 9451.08 9546.81 9641.36 9737.33 9832.57 9929.05 10025.20 10119.17 10215.94 10311.05 111 10407.66 54.00 55.56 56.19 56.25 55.55 54.90 53.42 52.70 54.71 56.02 56.62 57.00 56.21 55.45 53.73 52.61 52.28 51. 92 51. 65 52.20 159.95 160.49 161.14 162.83 163.32 163.29 162.99 163.45 162.75 161.72 163.09 162.81 163.84 165.11 165.21 165.59 164.65 164.24 164.19 164.20 52.72 163.43 52.72 163.43 [(c)2004 IDEAL 108 lC 01] Course length (ft) 161. 50 161.48 161.47 161.48 161.50 161. 52 161.55 161.57 161.58 161. 59 161.60 161.62 161. 64 161.67 161. 71 161. 75 161. 79 161. 82 161. 85 161. 87 7208.08 -6851.05 2240.43 7208.08 161.89 7268.01 -6908.51 2257.53 7268.01 161.90 DLS (deg/ 100f) 0.70 1. 70 0.86 1. 47 0.85 0.67 1. 57 0.85 2.18 1. 62 1. 34 0.47 1. 24 1. 35 1. 81 1. 20 0.85 0.52 0.28 0.58 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA e MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA 0.83 MWD IFR MSA e 0.00 Projected to TO , ... Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP EXPLORATION V-PAD V119 MAST TRUCK PRUDHOE BAY, AK AK0604G_511 JULY 11,2004 . " Serving the Worldwide Energy Industry with Precision Survey Instrumentation JO'-(-l)q\ A Gyrodata Directional Survey for B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY, Lease: V-PAD Well: V-119, TUBING . Job Number: AK0604G 511 Run Date: 7/11/20043:21:08 PM Surveyor: JAMIE MCCRIMMON, BRYAN J. STEFFEN Calculation Method: MINIMUM CURV A TURE Survey Latitude: 70.327481 deg. N Longitude: 149.266056 deg. W Sub-sea Correction trom Vertical Reference: 81.70 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated trom Well Head Location . Closure Calculated trom Well Head Location Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg.l feet 100 ft. . 0.00 0.00 -81.7 0.00 0.00 0.00 0.00 N 0.00 E ----------------...---------------------------------------------------------------------------------------------------------------------------------------------------------- RATE GYROSCOPIC CONTINUOUS SURVEY RUN INSIDE 41/2" TUBING. ALL MEASURED DEPTHS AND COORDINATES ARE REFERENCED TO THE ORIGINAL RKB OF 26.4'. --------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 108.01 108.01 26.3 0.11 326.53 0.10 0.08 N 0.06W 133.01 133.01 51.3 0.11 328.99 0.02 0.12 N 0.08W 158.01 158.01 76.3 0.11 331.45 0.02 0.16 N O.lOW 183.01 183.01 101.3 0.11 333.92 0.02 0.21 N O.13W 208.01 208.01 126.3 0.11 336.35 0.02 0.25 N 0.15W 233.01 233.01 151.3 0.15 337.00 0.16 0.30 N 0.17W 258.01 258.01 176.3 0.19 337.66 0.16 0.37 N 0.20W 283.01 283.01 201.3 0.23 338.31 0.16 0.45 N 0.23W 308.01 308.01 226.3 0.27 338.96 0.16 0.55 N 0.27W . 333.01 333.01 251.3 0.41 340.10 0.56 0.69 N 0.32W 358.01 358.01 276.3 0.55 341.24 0.56 0.89 N 0.39W 383.01 383.01 301.3 0.69 342.38 0.56 1.14 N 0.47W 408.01 408.00 326.3 0.83 343.53 0.56 1.46 N 0.57W 433.01 433.00 351.3 1.07 345.50 0.97 1.86 N 0.68W 458.01 458.00 376.3 1.31 347.48 0.98 2.36 N 0.80W 483.01 482.99 401.3 1.55 349.46 0.98 2.97 N 0.92W 508.01 507.98 426.3 1.79 351.44 0.98 3.69 N 1.04 W A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G_511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 451.3 1.71 352.68 0.33 4.45 N 1.15W . 533.01 532.97 558.01 557.95 476.3 1.64 353.93 0.33 5.17 N 1.23W 583.01 582,94 501.2 1.57 355.18 0.33 5.87 N 1.30W 608.01 607.94 526.2 1.49 355.81 0.31 6.53 N 1.35W 633.01 632.93 551.2 1.29 298.41 5.39 6.99 N 1.62W 658.01 657.93 576.2 1.09 241.01 4.63 7.01 N 2.08W 683.01 682.92 601.2 0.89 183.61 3.88 6.70 N 2.30W 708.01 707.92 626.2 0.70 126.21 3.13 6.41 N 2.19W 733.01 732.92 651.2 1.15 131.73 1.84 6.16 N 1.88W 758.01 757.91 676.2 1.60 137.71 1.91 5.73 N 1.46W 783.01 782.90 701.2 2.06 143.70 1.98 5.11 N 0.96W 808.01 807.88 726.2 2.52 149.68 2.06 4.28 N 0.41 W 833.01 832.85 751.1 2.93 150.83 1.69 3.24 N 0.17 E 858.01 857.81 776.1 3.35 151.92 1.69 2.04 N 0.83 E . 883.01 882.76 801.1 3.77 153.02 1.70 0.66 N 1.55 E 908.01 907.70 826.0 4.19 154.11 1.70 0.89 S 2.32 E 933.01 932.62 850.9 4.90 153.75 2.85 2.67 S 3.19 E 958.01 957.52 875.8 5.62 153.37 2.87 4.72 S 4.21 E 983.01 982.38 900.7 6.33 152.99 2.87 7.05 S 5.39 E 1008.01 1007.21 925.5 7.05 152.61 2.87 9.64 S 6.72 E 1033.01 1032.00 950.3 7.91 152.06 3.46 12.52 S 8.23 E 1058.01 1056.73 975.0 8.78 151.50 3.47 15.72 S 9.95 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-1l9, TUBING Job Number: AK0604G_511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. . 1083.01 1081.41 999.7 9.64 150.94 3.47 19.22 S 11.87 E 1108.01 1106.02 1024.3 10.51 150.38 3.48 23.03 S 14.02 E 1133.01 1130.56 1048.9 11. 73 150.60 4.89 27.23 S 16.39 E 1158.01 1154.98 1073.3 12.96 150.83 4.92 31.89 S 19.00 E 1183.01 1179.28 1097.6 14.18 151.07 4.92 37.02 S 21.85 E 1210.00 1205.37 1123.7 15.42 152.74 4.86 43.10 S 25.10 E 1235.00 1229.42 1147.7 16.27 155.97 4.87 49.26 S 28.04 E 1260.00 1253.35 1171.7 17.37 156.27 4.45 55.87 S 30.97 E 1285.00 1277.14 1195.4 18.41 156.88 4.21 62.92 S 34.02 E 1310.00 1300.80 1219.1 19.37 157.40 3.90 70.38 S 37.17 E 1335.00 1324.35 1242.7 19.77 157.79 1.69 78.12 S 40.36 E 1360.00 1347.85 1266.2 20.12 157.90 1.38 86.02 S 43.57 E 1385.00 1371.28 1289.6 20.73 158.10 2.47 94.11 S 46.84 E . 1410.00 1394.61 1312.9 21.41 157.87 2.75 102.44 S 50.21 E 1435.00 1417.85 1336.2 21.80 157.74 1.56 110.96 S 53.69 E 1460.00 1441.04 1359.3 22.14 157.64 1.36 119.61 S 57.24 E 1485.00 1464.12 1382.4 23.04 157.83 3.61 128.50 S 60.88 E 1510.00 1487.06 1405.4 23.77 157.88 2.92 137.70 S 64.62 E 1535.00 1509.89 1428.2 24.31 157.84 2.17 147.13 S 68.46 E 1560.00 1532.58 1450.9 25.38 157.75 4.28 156.86 S 72.43 E 1585.00 1554.99 1473.3 27.27 157.46 7.57 167.11 S 76.65 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZllvfUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. . 1610.00 1577.06 1495.4 28.74 156.73 6.03 177.92 S 81.22 E 1635.00 1598.93 1517.2 29.19 156.41 1.89 189.03 S 86.04 E 1660.00 1620.75 1539.1 29.29 156.40 0.41 200.22 S 90.92 E 1685.00 1642.54 1560.8 29.42 156.36 0.53 211.44 S 95.83 E 1710.00 1664.29 1582.6 29.67 156.33 1.02 222.74 S 100.78 E 1735.00 1685.97 1604.3 30.00 156.34 1.30 234.13 S 105.77 E 1760.00 1707.54 1625.8 30.79 156.61 3.20 245.72 S 110.82 E 1785.00 1728.93 1647.2 31.51 157.03 3.03 257.61 S 115.91 E 1810.00 1750.20 1668.5 31.90 157.25 1.61 269.72 S 121.01 E 1835.00 1771.38 1689.7 32.32 157.68 1.94 281.99 S 126.11 E 1860.00 1792.40 1710.7 33.25 158.16 3.84 294.54 S 131.19 E 1885.00 1813.19 1731.5 34.23 158.62 4.07 307.45 S 136.31 E 1910.00 1833.82 1752.1 34.52 158.64 1.14 320.59 S 141.45 E 1935.00 1854.38 1772.7 34.83 158.60 1.27 333.83 S 146.64 E . 1960.00 1874.77 1793.1 35.87 158.55 4.13 347.30 S 151.92 E 1985.00 1894.80 1813.1 37.67 158.47 7.22 361.22 S 157.40 E 2010.00 1914.44 1832.7 38.73 158.41 4.26 375.60 S 163.08 E 2035.00 1933.86 1852.2 39.31 158.45 2.31 390.24 S 168.87 E 2060.00 1953.06 1871.4 40.34 158.43 4.14 405.13 S 174.75 E 2085.00 1971.92 1890.2 41.70 158.47 5.43 420.39 S 180.78 E 2110.00 1990.55 1908.8 41.97 158.49 1.06 435.90 S 186.90 E 2135.00 2009.06 1927.4 42.49 158.44 2.09 451.53 S 193.07 E A Gyrodata Directional Survey RP. EXPLORA nON Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. . 2160.00 2027.30 1945.6 43.81 158.48 5.28 467.44 S 199.34 E 2185.00 2045.22 1963.5 44.62 158.49 3.27 483.65 S 205.74 E 2210.00 2062.92 1981.2 45.22 158.51 2.40 500.08 S 212.21 E 2235.00 2080.42 1998.7 45.96 158.54 2.95 516.70 S 218.75 E 2260.00 2097.59 2015.9 47.29 158.80 5.38 533.63 S 225.36 E 2285.00 2114.27 2032.6 48.99 159.12 6.84 551.00 S 232.04 E 2310.00 2130.59 2048.9 49.49 159.13 2.03 568.69 S 238.79 E 2335.00 2146.75 2065.1 49.98 159.12 1.96 586.52 S 245.59 E 2360.00 2162.54 2080.8 51.68 158.97 6.79 604.62 S 252.52 E 2385.00 2177.89 2096.2 52.52 159.03 3.38 623.04 S 259.59 E 2410.00 2193.05 2111.3 52.86 159.03 1.36 641.60 S 266.70 E 2435.00 2207.96 2126.3 53.89 159.49 4.36 660.37 S 273.81 E 2460.00 2222.44 2140.7 55.33 160.29 6.33 679.50 S 280.81 E 2485.00 2236.49 2154.8 56.26 161.06 4.52 699.02 S 287.65 E . 2510.00 2250.34 2168.6 56.47 161.12 0.86 718.71 S 294.40 E 2535.00 2264.17 2182.5 56.38 161.18 0.43 738.42 S 301.13 E 2560.00 2278.04 2196.3 56.22 161.21 0.66 758.11 S 307.83 E 2585.00 2291.97 2210.3 56.07 161.24 0.58 777.77 S 314.51 E 2610.00 2305.99 2224.3 55.68 161.09 1.64 797.35 S 321.19 E 2635.00 2320.12 2238.4 55.50 161.05 0.75 816.86 S 327.88 E 2660.00 2334.31 2252.6 55.32 161.00 0.72 836.32 S 334.58 E 2685.00 2348.52 2266.8 55.41 161.03 0.36 855.77 S 341.27 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 1 00 ft. . 271 0.00 2362.66 2281.0 55.69 161.07 1.15 875.27 S 347.96 E 2735.00 2376.57 2294.9 56.75 162.04 5.31 894.98 S 354.54 E 2760.00 2390.21 2308.5 57.10 162.15 1.47 914.92 S 360.98 E 2785.00 2403.79 2322.1 57.08 162.19 0.17 934.90 S 367.40 E 2810.00 2417.47 2335.8 56.56 162.00 2.19 954.81 S 373.84 E 2835.00 2431.32 2349.6 56.14 161.81 1.79 974.59 S 380.30 E 2860.00 2445.32 2363.6 55.75 161.71 1.60 994.26 S 386.78 E 2885.00 2459.42 2377.7 55.60 161.65 0.63 1013.86 S 393.27 E 2910.00 2473.60 2391.9 55.30 161.61 1.23 1033.40 S 399.76 E 2935.00 2487.90 2406.2 54.89 161.67 1.63 1052.86 S 406.22 E 2960.00 2502.33 2420.6 54.64 161. 80 1.10 1072.25 S 412.62 E 2985.00 2516.84 2435.1 54.40 162.15 1.49 1091.61 S 418.92 E 3010.00 2531.35 2449.7 54.59 162.80 2.23 1111.02 S 425.05 E . 3035.00 2545.80 2464.1 54.80 163.40 2.13 1130.54 S 430.98 E 3060.00 2560.19 2478.5 54.90 163.48 0.45 1150.14 S 436.81 E 3085.00 2574.58 2492.9 54.82 163.49 0.31 1169.74 S 442.62 E 3110.00 2589.04 2507.3 54.55 163.44 1.09 1189.29 S 448.43 E 3135.00 2603.60 2521.9 54.21 163.15 1.66 1208.76 S 454.27 E 3160.00 2618.19 2536.5 54.38 163.11 0.69 1228.18 S 460.16 E 3185.00 2632.70 2551.0 54.64 163.13 1.02 1247.66 S 466.07 E 3210.00 2647.09 2565.4 55.07 163.04 1.77 1267.22 S 472.02 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-l19, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 2661.36 2579.7 55.30 163.03 0.92 1286.85 S 478.00 E . 3235.00 3260.00 2675.58 2593.9 55.37 162.89 0.53 1306.51 S 484.03 E 3285.00 2689.81 2608.1 55.24 162.84 0.52 1326.15 S 490.09 E 3310.00 2704.27 2622.6 54.09 162.79 4.61 1345.64 S 496.11 E 3335.00 2719.00 2637.3 53.75 162.79 1.38 1364.94 S 502.09 E 3360.00 2733.85 2652.2 53.32 162.78 1.72 1384.14 S 508.04 E 3385.00 2748.84 2667.1 53.05 162.71 1.09 1403.26 S 513.97 E 3410.00 2763.89 2682.2 52.93 162.76 0.52 1422.32 S 519.90 E 3435.00 2779.03 2697.3 52.53 162.75 1.57 1441.32 S 525.80 E 3460.00 2794.19 2712.5 52.80 162.76 1.07 1460.30 S 531.69 E 3485.00 2809.27 2727.6 52.98 162.77 0.72 1479.35 S 537.60 E 3510.00 2824.29 2742.6 53.19 162.80 0.84 1498.44 S 543.51 E 3535.00 2839.24 2757.5 53.34 162.88 0.64 1517.58 S 549.42 E 3560.00 2854.15 2772.4 53.42 162.89 0.32 1536.76 S 555.33 E 3585.00 2869.07 2787.4 53.28 162.98 0.62 1555.93 S 561.22 E . 3610.00 2884.02 2802.3 53.28 162.98 0.01 1575.09 S 567.08 E 3635.00 2899.02 2817.3 52.97 163.00 1.24 1594.22 S 572.93 E 3660.00 2914.10 2832.4 52.82 162.96 0.64 1613.28 S 578.77 E 3685.00 2929.17 2847.5 53.09 162.95 1.09 1632.36 S 584.62 E 3710.00 2944.04 2862.3 53.87 162.96 3.14 1651.57 S 590.51 E 3735.00 2958.68 2877.0 54.47 163.03 2.38 1670.95 S 596.43 E 3760.00 2973.14 2891.4 54.87 163.11 1.63 1690.46 S 602.37 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G_511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 2987.46 2905.8 55.23 163.20 . 3785.00 1.47 1710.08 S 608.31 E 3810.00 3001.65 2919.9 55.57 163.24 1.38 1729.78 S 614.25 E 3835.00 3015.76 2934.1 55.74 163.29 0.71 1749.55 S 620.19 E 3860.00 3029.82 2948.1 55.81 163.32 0.29 1769.35 S 626.13 E 3885.00 3043.92 2962.2 55.49 163.29 1.29 1789.12 S 632.06 E 3910.00 3058.08 2976.4 55.53 163.22 0.28 1808.85 S 638.00 E 3935.00 3072.20 2990.5 55.69 163.24 0.63 1828.60 S 643.95 E 3960.00 3086.30 3004.6 55.65 163.31 0.27 1848.37 S 649.89 E 3985.00 3100.38 3018.7 55.80 163.35 0.61 1868.16 S 655.82 E 4010.00 3114.45 3032.8 55.69 163.47 0.61 1887.97 S 661.72 E 4035.00 3128.60 3046.9 55.37 163.48 1.27 1907.73 S 667.58 E 4060.00 3142.86 3061.2 55.03 163.49 1.36 1927.41 S 673.42 E 4085.00 3157.16 3075.5 55.19 163.48 0.64 1947.07 S 679.25 E 4110.00 3171.47 3089.8 55.02 163.58 0.75 1966.73 S 685.06 E . 4135.00 3185.97 3104.3 54.04 163.81 4.00 1986.28 S 690.78 E 4160.00 3200.73 3119.0 53.58 163.88 1.86 2005.66 S 696.39 E 4185.00 3215.61 3133.9 53.41 163.89 0.70 2024.96 S 701.97 E 4210.00 3230.53 3148.8 53.27 163.89 0.54 2044.23 S 707.53 E 4235.00 3245.44 3163.7 53.50 163.89 0.90 2063.51 S 713.10 E 4260.00 3260.29 3178.6 53.64 164.02 0.71 2082.84 S 718.66 E 4285.00 3275.06 3193.4 53.90 164.03 1.03 2102.23 S 724.21 E 4310.00 3289.75 3208.1 54.15 164.07 0.99 2121.68 S 729.77 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 3304.39 3222.7 54.17 164.16 0.30 2141.17 S 735.32 E . 4335.00 4360.00 3318.94 3237.2 54.65 164.55 2.34 2160.75 S 740.80 E 4385.00 3333.27 3251.6 55.37 164.77 2.94 2180.50 S 746.22 E 4410.00 3347.40 3265.7 55.80 164.88 1.77 2200.40 S 751.62 E 4435.00 3361.47 3279.8 55.74 164.91 0.27 2220.36 S 757.00 E 4460.00 3375.60 3293.9 55.41 165.15 1.52 2240.28 S 762.33 E 4485.00 3389.85 3308.2 55.11 165.25 1.27 2260.14 S 767.58 E 4510.00 3404.13 3322.4 55.20 165.25 0.38 2279.98 S 772.80 E 4535.00 3418.51 3336.8 54.57 165.21 2.54 2299.76 S 778.02 E 4560.00 3433.06 3351.4 54.27 165.25 1.20 2319.42 S 783.20 E 4585.00 3447.71 3366.0 53.98 165.32 1.19 2339.01 S 788.34 E 4610.00 3462.45 3380.8 53.74 165.44 1.04 2358.55 S 793.44 E 4635.00 3477.20 3395.5 53.97 165.52 0.96 2378.09 S 798.50 E 4660.00 3491.84 3410.1 54.37 165.53 1.59 2397.71 S 803.56 E . 4685.00 3506.34 3424.6 54.69 165.53 1.30 2417.43 S 808.65 E 4710.00 3520.80 3439.1 54.68 165.56 0.13 2437.18 S 813.75 E 4735.00 3535.32 3453.6 54.28 165.57 1.61 2456.89 S 818.82 E 4760.00 3549.95 3468.3 54.08 165.68 0.86 2476.52 S 823.85 E 4785.00 3564.62 3482.9 54.09 . 165.72 0.13 2496.14 S 828.85 E 4810.00 3579.34 3497.6 53.75 165.87 1.43 2515.73 S 833.81 E 4835.00 3594.14 3512.4 53.67 165.88 0.30 2535.27 S 838.72 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-l19, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 4860.00 3608.89 3527.2 53.99 165.71 1.37 2554.83 S 843.68 E . 4885.00 3623.55 3541.8 54.25 165.61 1.09 2574.46 S 848.69 E 4910.00 3638.17 3556.5 54.15 165.54 0.44 2594.09 S 853.75 E 4935.00 3652.83 3571.1 54.05 165.60 0.42 2613.71 S 858.79 E 4960.00 3667.56 3585.9 53.76 165.73 1.26 2633.28 S 863.79 E 4985.00 3682.42 3600.7 53.28 165.87 1.95 2652.77 S 868.72 E 5010.00 3697.41 3615.7 53.02 165.94 1.08 2672.17 S 873.60 E 5035.00 3712.42 3630.7 53.21 165.88 0.80 2691.57 S 878.47 E 5060.00 3727.33 3645.6 53.58 165.84 1.47 2711.03 S 883.37 E 5085.00 3742.12 3660.4 53.85 165.83 1.10 2730.57 S 888.30 E 5110.00 3756.81 3675.1 54.16 165.84 1.24 2750.18 S 893.25 E 5135.00 3771.38 3689.7 54.58 165.77 1.68 2769.88 S 898.23 E 5160.00 3785.73 3704.0 55.31 165.56 3.02 2789.71 S 903.30 E 5185.00 3799.91 3718.2 55.62 165.47 1.28 2809.65 S 908.45 E 5210.00 3814.03 3732.3 55.58 165.42 0.23 2829.61 S 913.64 E . 5235.00 3828.19 3746.5 55.39 165.45 0.76 2849.55 S 918.82 E 5260.00 3842.43 3760.7 55.21 165.42 0.74 2869.44 S 923.99 E 5285.00 3856.74 3775.0 54.91 165.44 1.19 2889.28 S 929.14 E 5310.00 3871.12 3789.4 54.87 165.37 0.29 2909.07 S 934.30 E 5335.00 3885.45 3803.8 55.18 165.16 1.43 2928.88 S 939.51 E 5360.00 3899.67 3818.0 55.51 164.82 1.72 2948.74 S 944.83 E 5385.00 3913.77 3832.1 55.81 164.78 1.21 2968.66 S 950.25 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BA Y Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. . 5410.00 3927.81 3846.1 55.86 164.75 0.21 2988.62 S 955.68 E 5435.00 3941.90 3860.2 55.56 164.97 1.38 3008.56 S 961.08 E 5460.00 3956.06 3874.4 55.43 165.05 0.58 3028.46 S 966.40 E 5485.00 3970.31 3888.6 55.08 165.05 1.39 3048.31 S 971.70 E 5510.00 3984.57 3902.9 55.34 164.92 1.09 3068.14 S 977.02 E 5535.00 3998.77 3917.1 55.44 164.40 1.74 3087.98 S 982.47 E 5560.00 4012.97 3931.3 55.32 164.03 1.34 3107.78 S 988.06 E 5585.00 4027.1 7 3945.5 55.50 163.95 0.76 3127.56 S 993.74 E 5610.00 4041.38 3959.7 55.21 164.05 1.19 3147.33 S 999.41 E 5635.00 4055.66 3974.0 55.11 164.05 0.40 3167.06 S 1005.05 E 5660.00 4069.98 3988.3 55.04 164.12 0.35 3186.77 S 1010.67 E 5685.00 4084.35 4002.7 54.74 164.04 1.20 3206.44 S 1016.28 E 5710.00 4098.74 4017.0 55.02 163.89 1.21 3226.09 S 1021.92 E 5735.00 4113.04 4031.3 55.15 163.23 2.22 3245.75 S 1027.73 E . 5760.00 4127.28 4045.6 55.40 162.56 2.45 3265.39 S 1033.77 E 5785.00 4141.43 4059.7 55.69 162.05 2.03 3285.03 S 1040.04 E 5810.00 4155.49 4073.8 55.84 161.80 1.01 3304.68 S 1046.45 E 5835.00 4169.49 4087.8 56.04 161.71 0.87 3324.35 S 1052.93 E 5860.00 4183.45 4101.8 56.08 161.66 0.21 3344.04 S 1059.45 E 5885.00 4197.35 4115.6 56.40 161.61 1.31 3363.76 S 1066.00 E 5910.00 4211.19 4129.5 56.38 160.81 2.67 3383.47 S 1072.71 E 5935.00 4224.98 4143.3 56.67 160.26 2.15 3403.14 S 1079.66 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G _511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 5960.00 4238.69 4157.0 56.77 159.99 1.00 3422.79 S 1086.76 E . 5985.00 4252.39 4170.7 56.82 159.94 0.27 3442.44 S 1093.93 E 6010.00 4266.11 4184.4 56.56 160.19 1.31 3462.08 S 1101.05 E 6035.00 4279.92 4198.2 56.40 160.19 0.65 3481.69 S 1108.11 E 6060.00 4293.82 4212.1 56.02 160.16 1.52 3501.24 S 1115.16 E 6085.00 4307.84 4226.1 55.76 160.26 1.10 3520.72 S 1122.17 E 6110.00 4321.90 4240.2 55.81 160.28 0.22 3540.18 S 1129.15 E 6135.00 4336.00 4254.3 55.53 160.57 1.49 3559.63 S 1136.07 E 6160.00 4350.12 4268.4 55.66 160.67 0.63 3579.08 S 1142.91 E 6185.00 4364.24 4282.5 55.57 160.89 0.81 3598.57 S 1149.70 E 6210.00 4378.42 4296.7 55.33 161.14 1.26 3618.04 S 1156.40 E 6235.00 4392.62 4310.9 55.41 161.21 0.40 3637.51 S 1163.04 E 6260.00 4406.86 4325.2 55.15 161.41 1.25 3656.98 S 1169.62 E 6285.00 4421.17 4339.5 55.01 161.62 0.86 3676.42 S 1176.12 E . 6310.00 4435.51 4353.8 54.99 161.75 0.45 3695.86 S 1182.56 E 633.5.00 4449.91 4368.2 54.67 161.83 1.30 3715.27S 1188.94 E 6360.00 4464.34 4382.6 54.86 161. 84 0.77 3734.67 S 1195.31 E 6385.00 4478.76 4397.1 54.70 161.86 0.66 3754.08 S 1201.67 E 6410.00 4493.26 4411. 6 54.36 161.83 1.34 3773.43 S 1208.02 E 6435.00 4507.84 4426.1 54.31 161.85 0.22 3792.73 S 1214.35 E 6460.00 4522.49 4440.8 53.93 161.85 1.51 3811.98 S 1220.66 E A Gyrodata Directional Survey RP. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-1l9, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 1 00 ft. 3831.20 S . 6485.00 4537.18 4455.5 54.06 161.88 0.54 1226.95 E 6510.00 4551.87 4470.2 53.95 162.04 0.69 3850.43 S 1233.21 E 6535.00 4566.57 4484.9 54.03 162.08 0.31 3869.67 S 1239.44 E 6560.00 4581.21 4499.5 54.30 162.18 1.14 3888.96 S 1245.66 E 6585.00 4595.74 4514.0 54.62 162.24 1.30 3908.33 S 1251.88 E 6610.00 4610.19 4528.5 54.81 162.42 0.96 3927.77 S 1258.07 E 6635.00 4624.57 4542.9 54.93 162.63 0.85 3947.27 S 1264.21 E 6660.00 4638.97 4557.3 54.76 162.76 0.81 3966.79 S 1270.29 E 6685.00 4653.38 4571.7 54.83 162.78 0.29 3986.30 S 1276.34 E 6710.00 4667.79 4586.1 54.78 162.85 0.29 4005.82 S 1282.37 E 6735.00 4682.23 4600.5 54.67 163.02 0.72 4025.33 S 1288.36 E 6760.00 4696.68 4615.0 54.69 163.15 0.41 4044.85 S 1294.30 E 6785.00 4711.13 4629.4 54.65 163.26 0.40 4064.37 S 1300.19 E 6810.00 4725.58 4643.9 54.77 163.33 0.53 4083.92 S 1306.06 E 6835.00 4740.05 4658.4 54.48 163.43 1.21 4103.45 S 1311.89 E . 6860.00 4754.64 4672.9 54.09 163.50 1.60 4122.91 S 1317.66 E 6885.00 4769.29 4687.6 54.17 163.57 0.41 4142.34 S 1323.41 E 6910.00 4783.97 4702.3 53.89 163.68 1.19 4161.75 S 1329.11 E 6935.00 4798.72 4717.0 53.84 163.64 0.22 4181.13 S 1334.79 E 6960.00 4813.46 4731.8 53.90 163.61 0.25 4200.50 S 1340.48 E 6985.00 4828.19 4746.5 53.87 163.40 0.69 4219.87 S 1346.22 E 7010.00 4842.92 4761.2 53.92 163.23 0.60 4239.21 S 1352.02 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 1 00 ft. - 7035.00 4857.62 4775.9 54.08 163.05 0.87 4258.57 S 1357.88 E 7060.00 4872.20 4790.5 54.59 162.96 2.06 4277.99 S 1363.82 E 7085.00 4886.59 4804.9 55.10 162.88 2.07 4297.53 S 1369.82 E 7110.00 4900.88 4819.2 55.20 162.84 0.43 4317.14 S 1375.87 E 7135.00 4915.14 4833.4 55.22 162.79 0.17 4336.75 S 1381.94 E 7160.00 4929.40 4847.7 55.23 162.85 0.22 4356.37 S 1388.00 E 7185.00 4943.68 4862.0 55.08 163.02 0.80 4375.98 S 1394.02 E 7210.00 4957.96 4876.3 55.26 163.05 0.71 4395.61 S 1400.01 E 7235.00 4972.24 4890.5 55.07 163.10 0.77 4415.24 S 1405.99 E 7260.00 4986.57 4904.9 54.98 163.00 0.46 4434.84 S 1411.96 E 7285.00 5000.95 4919.3 54.79 162.87 0.88 4454.39 S 1417.96 E 7310.00 5015.44 4933.7 54.37 162.63 1.86 4473.85 S 1424.00 E 7335.00 5030.01 4948.3 54.34 162.51 0.39 4493.23 S 1430.08 E 7360.00 5044.62 4962.9 54.10 162.37 1.07 4512.57 S 1436.20 E . 7385.00 5059.32 4977.6 53.87 162.26 1.01 4531.83 S 1442.35 E 7410.00 5074.07 4992.4 53.82 162.19 0.30 4551.05 S 1448.51 E 7435.00 5088.79 5007.1 54.05 161.90 1.29 4570.28 S 1454.74 E 7460.00 5103.46 5021.8 54.08 161.20 2.27 4589.48 S 1461.14 E 7485.00 5118.11 5036.4 54.22 161.12 0.64 4608.66 S 1467.69 E 7510.00 5132.75 5051.1 54.04 161.07 0.75 4627.82 S 1474.25 E 7535.00 5147.47 5065.8 53.82 160.92 1.02 4646.93 S 1480.83 E 7560.00 5162.26 5080.6 53.63 160.89 0.73 4665.98 S 1487.42 E . A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G_511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. . 7585.00 5177.14 5095.4 53.36 160.78 1.16 4684.96 S 1494.02 E 7610.00 5192.02 5110.3 53.55 160.60 0.96 4703.91 S 1500.66 E 7635.00 5206.79 5125.1 54.05 160.61 2.00 4722.94 S 1507.36 E 7660.00 5221.39 5139.7 54.48 160.45 1.79 4742.08 S 1514.13 E 7685.00 5235.91 5154.2 54.46 160.26 0.63 4761.24 S 1520.97 E 7710.00 5250.40 5168.7 54.69 160.08 1.09 4780.40 S 1527.88 E 7735.00 5264.76 5183.1 55.19 160.03 1.98 4799.64 S 1534.86 E 7760.00 5278.99 5197.3 55.46 159.90 1.19 4818.95 S 1541.91 E 7785.00 5293.17 5211.5 55.42 159.91 0.17 4838.29 S 1548.98 E 7810.00 5307.36 5225.7 55.39 159.83 0.27 4857.61 S 1556.06 E 7835.00 5321.59 5239.9 55.26 159.84 0.53 4876.91 S 1563.15 E 7860.00 5335.86 5254.2 55.11 159.88 0.59 4896.18 S 1570.22 E 7885.00 5350.17 5268.5 55.02 159.85 0.38 4915.42 S 1577.28 E . 7910.00 5364.55 5282.9 54.78 159.82 0.98 4934.62 S 1584.33 E 7935.00 5378.98 5297.3 54.68 159.85 0.40 4953.78 S 1591.36 E 7960.00 5393.46 5311.8 54.53 159.82 0.60 4972.91 S 1598.39 E 7985.00 5407.99 5326.3 54.43 159.78 0.42 4992.01 S 1605.41 E 8010.00 5422.54 5340.8 54.35 159.79 0.35 5011.08 S 1612.44 E 8035.00 5437.14 5355.4 54.21 159.69 0.65 5030.13 S 1619.46 E 8060.00 5451.76 5370.1 54.22 159.73 0.15 5049.15 S 1626.50 E 8085.00 5466.40 5384.7 54.09 159.72 0.52 5068.16 S 1633.52 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 8110.00 5481.07 5399.4 54.02 159.80 0.38 5087.15 S 1640.52 E . 8135.00 5495.81 5414.1 53.70 159.78 1.30 5106.09 S 1647.50 E 8160.00 5510.66 5429.0 53.47 159.82 0.92 5124.97 S 1654.45 E 8185.00 5525.49 5443.8 53.72 159.78 1.01 5143.86 S 1661.39 E 8210.00 5540.17 5458.5 54.40 159.78 2.73 5162.85 S 1668.39 E 8235.00 5554.60 5472.9 55.09 159.71 2.75 5182.00 S 1675.46 E 8260.00 5568.87 5487.2 55.29 159.69 0.81 5201.26 S 1682.58 E 8285.00 5583.12 5501.4 55.20 159.67 0.35 5220.52 S 1689.71 E 8310.00 5597.39 5515.7 55.19 159.64 0.12 5239.76 S 1696.85 E 8335.00 5611.71 5530.0 54.92 159.45 1.22 5258.96 S 1704.01 E 8360.00 5626.09 5544.4 54.86 159.38 0.36 5278.11 S 1711.20 E 8385.00 5640.49 5558.8 54.78 159.33 0.34 5297.23 S 1718.41 E 8410.00 5654.92 5573.2 54.74 159.26 0.29 5316.33 S 1725.63 E 8435.00 5669.37 5587.7 54.61 159.24 0.51 5335.40 S 1732.86 E 8460.00 5683.91 5602.2 54.29 159.16 1.30 5354.42 S 1740.08 E . 8485.00 5698.48 5616.8 54.38 159.07 0.44 5373.39 S 1747.32 E 8510.00 5713.14 5631.4 53.80 158.99 2.30 5392.30 S 1754.57 E 8535.00 5727.83 5646.1 54.26 158.92 1.86 5411.19 S 1761.83 E 8560.00 5742.34 5660.6 54.78 159.18 2.24 5430.20 S 1769.11 E 8585.00 5756.65 5674.9 55.38 159.55 2.67 5449.38 S 1776.33 E 8610.00 5770.77 5689.1 55.83 159.82 2.03 5468.73 S 1783.50 E 8635.00 5784.77 5703.1 56.05 159.98 1.02 5488.18 S 1790.62 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V -P AD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 56.15 5507.68 S . 8660.00 5798.71 5717.0 160.03 0.43 1797.71 E 8685.00 5812.62 5730.9 56.26 160.03 0.43 5527.20 S 1804.81 E 8710.00 5826.49 5744.8 56.33 160.03 0.31 5546.75 S 1811.91 E 8735.00 5840.35 5758.6 56.36 160.28 0.81 5566.33 S 1818.97 E 8760.00 5854.18 5772.5 56.43 160.82 1.83 5585.96 S 1825.91 E 8785.00 5868.02 5786.3 56.37 161.75 3.11 5605.68 S 1832.59 E 8810.00 5881.87 5800.2 56.35 162.14 1.29 5625.47 S 1839.04 E 8835.00 5895.78 5814.1 56.04 162.24 1.31 5645.25 S 1845.40 E 8860.00 5909.78 5828.1 55.81 162.17 0.96 5664.96 S 1851.72 E 8885.00 5923.88 5842.2 55.56 162.32 1.11 5684.63 S 1858.02 E 8910.00 5938.08 5856.4 55.24 162.40 1.29 5704.24 S 1864.25 E 8935.00 5952.32 5870.6 55.28 162.43 0.19 5723.82 S 1870.46 E 8960.00 5966.59 5884.9 55.10 162.36 0.75 5743.39 S 1876.67 E 8985.00 5980.94 5899.2 54.85 162.29 1.02 5762.90 S 1882.88 E . 9010.00 5995.39 5913.7 54.53 162.21 1.32 5782.33 S 1889.10 E 9035.00 6009.98 5928.3 54.05 162.27 1.94 5801.66 S 1895.29 E 9060.00 6024.72 5943.0 53.72 162.34 1.33 5820.90 S 1901.43 E 9085.00 6039.61 5957.9 53.13 162.42 2.35 5840.03 S 1907.51 E 9110.00 6054.72 5973.0 52.54 162.31 2.41 5859.02 S 1913.54 E 9135.00 6069.95 5988.3 52.40 162.23 0.62 5877.90 S 1919.58 E 9160.00 6085.15 6003.4 52.70 162.05 1.34 5896.79 S 1925.67 E 9185.00 6100.23 6018.5 53.11 162.09 1.63 5915.76 S 1931.81 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZIMUTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. e 9210.00 6115.23 6033.5 53.15 162.03 0.28 5934.79 S 1937.97 E 9235.00 6130.11 6048.4 53.81 161.77 2.73 5953.89 S 1944.21 E 9260.00 6144.70 6063.0 54.74 161.50 3.85 5973.15 S 1950.60 E 9285.00 6158.96 6077 .3 55.72 161.31 3.95 5992.61 S 1957.15 E 9310.00 6172.98 6091.3 56.06 161.27 1.40 6012.22 S 1963.79 E 9335.00 6186.91 6105.2 56.20 161.05 0.91 6031.87 S 1970.49 E 9360.00 6200.83 6119.1 56.13 160.96 0.41 6051.50 S 1977.25 E 9385.00 6214.74 6133.0 56.26 160.83 0.67 6071.13 S 1984.05 E 9410.00 6228.66 6147.0 56.06 160.75 0.84 6090.74 S 1990.88 E 9435.00 6242.57 6160.9 56.34 161.09 1.62 6110.37 S 1997.67 E 9460.00 6256.34 6174.6 56.85 161.64 2.71 6130.15 S 2004.34 E 9485.00 6269.96 6188.3 57.12 161.95 1.52 6150.06 S 2010.89 E 9510.00 6283.49 6201.8 57.33 162.01 0.84 6170.05 S 2017.40 E 9535.00 6297.00 6215.3 57.25 161.86 0.59 6190.05 S 2023.92 E . 9560.00 6310.56 6228.9 57.06 161.89 0.73 6210.01 S 2030.46 E 9585.00 6324.17 6242.5 56.99 161.85 0.32 6229.94 S 2036.98 E 9610.00 6337.80 6256.1 56.92 162.05 0.73 6249.86 S 2043.47 E 9635.00 6351.49 6269.8 56.66 162.57 2.01 6269.79 S 2049.83 E 9660.00 6365.33 6283.6 56.12 163.43 3.61 6289.70 S 2055.92 E 9685.00 6379.30 6297.6 55.94 163.90 1.70 6309.60 S 2061.75 E 9710.00 6393.30 6311.6 55.92 163.93 0.13 6329.50 S 2067.49 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL SUBSEA INCL AZThillTH DOGLEG HORIZONTAL DEPTH DEPTH DEPTH SEVERITY COORDINATES feet feet feet deg. deg. deg./ feet 100 ft. 9735.00 6407.36 6325.7 55.67 163.82 1.09 6349.36 S 2073.23 E . 9760.00 6421.49 6339.8 55.51 163.70 0.74 6369.16 S 2079.00 E 9785.00 6435.70 6354.0 55.19 163.49 1.43 6388.89 S 2084.81 E 9810.00 6450.04 6368.3 54.80 163.72 1.74 6408.54 S 2090.59 E 9835.00 6464.60 6382.9 53.98 164.14 3.57 6428.07 S 2096.21 E 9860.00 6479.41 6397.7 53.35 164.38 2.60 6447.45 S 2101.67 E 9885.00 6494.39 6412.7 53.04 164.35 1.28 6466.73 S 2107.07 E 9910.00 6509.42 6427.7 53.03 164.13 0.70 6485.95 S 2112.49 E 9935.00 6524.52 6442.8 52.69 163.95 1.46 6505.11 S 2117.97 E 9960.00 6539.69 6458.0 52.56 163.70 0.95 6524.19 S 2123.51 E 9985.00 6554.86 6473.2 52.74 163.58 0.83 6543.26 S 2129.11 E 10010.00 6570.05 6488.4 52.43 163.51 1.28 6562.30 S 2134.73 E 10035.00 6585.30 6503.6 52.40 163.50 0.11 6581.30 S 2140.36 E 10060.00 6600.55 6518.9 52.36 163.17 1.05 6600.27 S 2146.04 E 10085.00 6615.83 6534.1 52.30 163.08 0.39 6619.21 S 2151.78 E . 10110.00 6631.15 6549.4 52.11 163.13 0.77 6638.11 S 2157.52 E 10135.00 6646.49 6564.8 52.19 163.29 0.60 6657.01 S 2163.23 E 10160.00 6661.88 6580.2 51.83 163.33 1.44 6675.89 S 2168.88 E 10185.00 6677.33 6595.6 51.82 163.25 0.25 6694.71 S 2174.54 E 10210.00 6692.77 6611.1 51.86 163.11 0.44 6713.53 S 2180.22 E 10235.00 6708.18 6626.5 52.06 162.86 1.15 6732.35 S 2185.99 E 10260.00 6723.55 6641.9 52.05 162.62 0.77 6751.18 S 2191.84 E A Gyrodata Directional Survey B.P. EXPLORATION Location: MAST TRUCK, PRUDHOE BAY Lease: V-PAD Well: V-119, TUBING Job Number: AK0604G 511 MEASURED VERTICAL DEPTH DEPTH feet feet SUBSEA DEPTH feet IN C L AZIMUTH DOGLEG SEVERITY deg. deg. deg./ 100 ft. HORIZONTAL COORDINATES feet 10285.00 6738.90 6657.2 52.19 162.53 0.61 6770.01 S 2197.75 E . 10310.00 6754.18 6672.5 52.49 162.50 1.21 6788.88 S 2203.69 E 10335.00 6769.37 6687.7 52.68 162.71 1.02 6807.83 S 2209.63 E 10360.00 6784.51 6702.8 52.75 162.66 0.31 6826.82 S 2215.55 E 10385.00 6799.64 6717.9 52.73 162.56 0.34 6845.81 S 2221.50 E 10399.41 6808.37 6726.7 52.73 162.48 0.41 6856.75 S 2224.94 E Final Station Closure: Distance: 7208.70 ft Az: 162.02 deg. . B.P. EXPLORATION Well: V-PAD V-119 TUBING Location: MAST TRUCK, PRUDHOE BAY 60 Gyrodata AK0604G_5ll DEFINITIVE 50 - - - .- - -- - - ~ ~ - - - - - - - - ,- ,- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - --------- --------~------- ~A~----------------- - ~B0Tf10M HOLE -~--------,----~{)GArl~~------ MD: 10399.41 55 A 45 ----------------- --i-- - --- - ------------- -- --,-------- J _ _,A- _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ - _ _ _ - - - - - - - - - - - - _ - - - - - -.- - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - t " , ... -------------------------------------------------------- i " . 40 --------- - - 35 II. -- - - - - - - - - - - -,¡,- -- - - - - - - - ~ -- - - - - - - -, - - - - - - - - - ~ - - - - - - -- - -, - - - - - - - - - ~ - - - - - - - - -' - - - - - - - - - '- - - - - - - - - ~ - - - - - -- - - - .- - - - - - -. - - -- pc_nj___ . _____ .n__n nn _L. ___ n _____~____ c__ __n~ __ mC_____ n __ _ z o ~ « 30 z ....... -.J U ~ 25 . 15 - - - - - - - - - - - - - _Å - - -!- - - - - - - - - _ - - - - - - - - -,- - - - - - - - - ~ - - - - - - - - -, - - - - - - - - - r - - - - - - - - -, - - - - - - - - - ~ - - - - - - - - -t - - - - - - - - - :- - - - - - - - - - I ! I , - - - - - - - - - - -1- - -- -- - - - - - - - - ~ - - - - - - - - -:- - - - - - - - - - - - - - - - - - -, - - - - - - - - - - - - - - - - - - -, - - - - - - - - - ~ ~ - - - - - - - ~ - - - - - - - - - r - - - - - - - - - Â ! Â . - -- _ - t_ - -'- - - - - -- - - - - - - - - - - - - - - - - - - .- - - - _ - - - - - - - - -, - - - - - - - - - ,- - - - - - - - - -, - - - - - - - - - r - - - - - - - - , - - - - - - - - - , - - - - - - - - - '. A . '. ' -----lA--------'--------l------------------r------------------,--------,---------,--------,---------r--------- Â ! j. 20 10 5 ------- ----- -------- ---------------- , , ------------------- -------------------------------------- o i ' o 1000 2000 3000 4000 5000 6000 7000 MEASURED DEPTH (ft) 8000 9000 10000 11000 12000 B.P. EXPLORATION Well: V-PAD V-119 TUBING Location: MAST TRUCK, PRUDHOE BAY Gyrodata AK0604G 511 DEFINITIVE 350 --..---.---- - - .- -- -- -- .- - -- -- ~ - -- -- -- - .- - -- -- -- - -- -- -- - - - -- - -- - - - -- - -- - - - -- -- -- - - - -- -- -- - - - -- -- -- - - - -- -- -- -- - - - -- -- -- - - - - - -- -- - -- - - -- -- -- - - - - -- -- -- -- 300 ----.--------- , - - -- -- -- - - -- -. -- -- -- - - -- -- - ....,.. -- -- - - - -- -- -- -...- -- - - -- ~ -- - - - -- -- -- _. - -- -- -- -. ....,. -- -- - - -- -- - - - -- -- -- - -- ....,. -- -- --. - - - . . , . , ------,---------~--------- . I 250 f- :::> ~ ...... N « ,,------- ---------....,.--------~~--------¡---------~--------~---------!---------~T------- ------__....,._________ .à. 200 ----- -------- , , . ; . ----------------------------------------------- --------- ¡¡I ------------------------------------- .. . 150 ,'- ~¿j-" . "~".. .... :..~. .,' .-".-. -. ... , þ¡,/' "...ti , ' : :~ : ,LI:~: BOí[OM HOLE . -. - - - - - - T - - - - - - - - ~ - - - - - - - - ~ - - - - - - - - -,- - - - - - - - - ~ - - - - - - - - ~ - - - - - - - - -:_ _ _ _ _ _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _LOD) TED_ _ _ _ _ _ .Â MD: :10399.41 '" ... '" ! I I o 1000 2000 3000 4000 5000 6000 7000 MEASURED DEPTH (ft) 8000 90ÓO 10000 11000 12000 B.P. EXPLORATION Well: V-PAD V-119 TUBING Location: MAST TRUCK, PRUDHOE BAY 2.00 1.75 1.50 ....... .¡: lJ"} 1. 25 C'\I ......... CJ') (I) u ........ Ç: ~ 1.00 LU > LU (j) 19 LU <3 0.75 o o 0.50 0.25 0.00 Gyrodata AK0604G_511 DEFINITIVE A .A ----.---- -----.-- _ _ - - - _ _,_ _; - _ _ - - - - - - i- - _ - - - - - - -'- -_ - ~ - - - ~ __ -I _ _ _ _ - _ _ _ - ,-- - _ _ - _ _ __ _ -;-- - _ __ - - _ _ _ ....., - ~ _ _ - - _ _ - ,- - - _ - - - _ - - - - - - - - - - ,. À -- -----------......--"-- ----------------------------------- , ---------------------------------------------- , ... ..... '''' . . ------.- -------, .. ' - -, - - - - - - - - - :- - - - - - - - - -:- - - - - - - - - -, - - - ~ - .- - - -;- - - - - - - - - T - - - - - - - - -: - - - - - - - - -:- - - - - - - - - r - - - - - - - - - ... Â ¡Å ... ... -------- ... ¡í\¡¡ - - ~. -- - -~- - A. ---~---------~À-------~------------------~-----------------~---------,------------------- . , t . A. . .. . "'. . .. .... . ' - If - - - - - -t - - - - - - - - - - - - - - - '- - - - - - - - - ~ - -- - - - -, - ... - - ~ - - - - -: -;- - - - - - - - - ~ -. - - - - - - - - Â ..... .. .... , ------- - - -, - - - ~ - - .. ... ..... ... : :l +* Ä ... .... ~ - - - - -1 -- ~- - - - - - - -, :r --- - - -.,. -- - - - - 4-~ -- - - - - - - - ~-.- *f - ;- -- - - i4 ~ - ~~ - - --....- - -:,- -- - - - - - - ~ - - - - - -- - - ... ..... À ~À' ..'... · '.. ....... ," '..,.... I , ..... "I" _, ,..." '.. ... ... .. ... .. ;&1 '1 .. ~:.... .... ' Ä...~ ... ... .... A. ,~: ......1, ~~ ~,"Ji._~»...~,~...., ... 'I ,......~... ~ ,.~ --. --- - -- -A. A.:..__ -;.. :~.~,¡....·,..~.~..,,;4.1 iI_.,-.".; _', - -..;~. -~:.,.;~.,'~..\...!". .~.....~,!ti¡:~....;. t.... --..... ft,.' ~., :1...i..~ - - B~~~~ H~~E .. A 11, , AÁ",'''' ...' '. ".' .... '.' "i' "."""" '«7:'. "1..' ,..4 ".... , .. ~ ·....1.t\ ~ ~J..1A:.~ i ..... ~lJ;.Jj.'M~i~ ~,~ ,-1 ~ J;." ~¿, :.: 1 ~~i~TOE~9.,4~ .... . o 2000 12000 3000 4000 5000 6000 7000 MEASURED DEPTH Cft) 1000 8000 9000 10000 11000 B.P. EXPLORATION Well: V-PAD V-119 TUBING Location: MAST TRUCK, PRUDHOE BAY 7000 Gyrodata AK0604G_.511 DEFINITIVE , . , ---------- - -- ------------------------------------------- - - - - - - - - .- - - - - - - - - - - - - - - - - - - - '- - - - - - - - - BOTIOM HOLE LOCATED MD: ¡0399.41 6000 ----- ---- ----------- ----------~-----------------~--------------------------- -------------------------- 5000 .......... .¡: ~ 4000 f- a... w £:) -I « u ....... ~ 3000 l!J > 2000 1000 ----- -- - ----- ---------------------- ----~-------------------------------------- . , . - __ - - - - - - - - - - -1- _ __ _ __ _ _ _ _ _ _ _ _ _ _ _ _ ~ _ __ _ __ _ - - -, - .- '- - - - - - -;- -- - - -- - - _. - .... - - __ - - __ - - --I _ _ _ __ _ _ _ _ __!_ _ _ __ _ __ _ _ __ ;- _ _ _ _ _ _. _ __ _ ---- -------.'-- ------ -------------------------- ---------- o o r-----------------~---------:---------~--------~------------------~-- ------- -------I---------~------__~________~_________~________~________~_________i_________L_________ . I --------~---------i---------r--------T--------~---------'---------T--------~---------:---------~--------- 1000 2000 3000 4000 5000 6000 7000 MEASURED DEPTH (ft) 8000 9000 10000 11000 12000 '" B.P. EXPLORATION Well: V-PAD V-119 TUBING Location: MAST TRUCK, PRUDHOE BAY -1000 -2000 ~ -3000 '--' 19 Z ....... I f- er: o -4000 z -5000 . Gyrodata AK0604G_511 DEFINITIVE o I - -- - - .- .. .- -. -- - - -- - - - - - - - - - - - ~ - - - - - .- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - -. -- - - - - - - - - - - - "- - - - - - - - - -- - - - - - - ------.-- - - - - - - ~ - - - - - - - - - - - - - - - - - -- .- - - - - - .- - - - - - - - - - - - - - - - - - - - - - - - - .- - - - - - - - - - - - - - --. - - - - - - - - - -- - - - - --------------- ------.---------- - ----~--_._-_.- ------,-----------------------,-_.- ---------------------------------------- I ------------ . --------- ----------------------------------------------- ------------ -- --- - - - - -. - - -- -. - - - - -.- - - - - - - - - - - - - - - - -- - - - - - - -' - - - - - - - - - - ------------------------- ----~--------------------~---------------------,---------------------~--- -------------------------------~---- . -6000 ---------------------------------------------~---------------- -7000 BOTTOM HOL LOCATED MD: 10399.41 -~---------------------I---------------------~--------____________+____________________ - --~-------_._---_._----- o 500 1000 EASTING (ft) 1500 2000 2500 . . FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V -119 BP Exploration (Alaska) Inc. Permit No: 204-041 Surface Location: 4645' NSL, 1803' WEL, SEC. 11, T11N, RIlE, UM Bottomhole Location: 2231' SNL, 438' EWL, SEe. 13, TIIN, RIlE. UM Dear Mr.Crane: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you fÌom obtaining additional permits or approvals required by law fÌom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to 'tness any required test. Contact the Commission's North Slope petroleum field ins ector 65 -3607 (pager). S' e BY ORDER OF THE COMMISSION DATED thisL day ofF-elmIß'1', 2004 tr¡o.YC V) cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. WG,A- 2-12-7{¿i:>ót.{ '. A STATE OF ALASKA . ALASKA ~ AND GAS CONSERVATION COMlrSSION '\ PERMIT TO DRILL i . .. 20 MC 25.005 FEB 2 5 2004 1a. Type of work II Drill o Redrill 11b. Current Well Class ./ o Expl<;>ratory H D~yeJ()PTe~~r¡'8 f\l4¥iP~¡Z~~\ ORe-Entry o Stratigraphic Test II Service . ':DeYelo!>rrrent . If" 'Slhgle :Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well NãfflÈfâm!/'.'Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU V-119 ~ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10463 TVD 6853 Prudhoe Bay Field I Borealis Pool v 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 028245 4645' NSL, 1803'WEL, SEC. 11, T11N, R11E, UM (Planned) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1923' SNL, 342' EWL, SEC. 13, T11 N, R11 E, UM April 10, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2231' SNL, 438' EWL, SEC. 13, T11N, R11E, UM 2560 3000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-590500 y-5969892 Zone-ASP4 (Height above GL): Plan 81.5 feet Z-10 is 1122' away /' 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Kickoff Depth 400 ft Maximum Hole Angle 56 0 Downhole: 3200 psig Surface: 2539 psig -' 18.Ç~$¡ngprogram SpecifICations S6ttingpepth or Size Too i'" ...... ............ ..... ...... Bottom ..(C;f.· ::ü:ß.in<Þl> Hole Casino Weioht Grade Couolina Lenath MD TVD MD TVD (includin staae data) 42" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' '60 sx Arctic Set Accrox. ) 12-1/4" 9-518" 40# L-80 BTC 3442' Surface Surface 3442' 2771' 545 sx Arcticset Lite, 290 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 10463' Surface Surface 10463' 6853' 342 sx LiteCrete, 166 sx Class 'G' 19, PRESENT WEI..L CONDITION SUMMARY (To be completed fqrRedrillAND Re-entry QperåtioJ1s) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): r;í;I!OIirn'1i. .. 'i' ,. I...erioth, . .····pi~e.. ...... ¡..i··.. > . i.....·... ·...i ·.MD·· .......' ··..·.·.i...·;¡;y;D ........ r.nnrh Ir.tnr I ntAr P I inF!r Perforation Depth MD (ft): perfOration Depth TVD (ft): 20. Attachments 181 Filing Fee o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that~~e foregoing is true and correct to the best of my knowledge. Contact Neil Magee, 564-5119 Printed Name Lovy Crane" Title Senior Drilling Engineer Prepared By Name/Number: Sionature /~ -.,. L/, - Phone 564-4089 Date :2 -:2<.( - OV Terrie Hubble, 564-4628 , 1.":)0 . .. .'i. /i'" ii2' A"';.:' ,i' i ·········i·· ..... ...... ,> "/. ii, . ···i··. .... Permit To Drill I API Number: Permit APproval'?,} } tt-I See cover letter for Number: .20 So' - 0 Ý/ 50- C!J 2.. 9 - .z.. 3 "2. 0/ Date: I other requirements Conditions of Approval: Samples Required o Yes ~NO Mud Log Required o Yes ~No Hydrogen S fide Measures o Yes No Directional Survey Required )í.Yes 0 No Other: T·~~t '"Eo fJ- k If '00 (H. t' . MIT ~ ¡,..1..t!,,<A.J. btU,-L¿~ Ií/~ 'r'-iÕuA r'!.d . ) fA BY ORDER OF a í/4 Aooroved Bv: .---' . .. . A I THE COMMISSION Date Form 10-401 Re~ 12/~ - UK' lj \ \"1 f.\ L Submit (n Duplicate /" --- · . IWell Name: V-119 Drill and Complete Plan Summary I Type of Well (service I producer I injector): Ilnjector /' Surface Location: X = 590,500.17' Y = 5,969,892.04' , As-Built (Slot SF) 4645'FSL, 1803'FEL, Sec. 11,T11N, R11E / Target Location: X = 592,730.00' Y = 5,963,350.00' Kuparuk 3356'FSL,4938'FEL,Sec. 13, T11N,R11E /' Bottom Hole Location: X = 592,830.64' Y = 5,963,044.01' ,-/ 3049'FSL,4842'FEL, Sec. 13, T11N,R11E I AFE Number: I BRD5M4150 I I Estimated Start Date: 14/10/2004 I Rig: I Nabors 7ES / I Operating days to complete: 114.9 [M[] 10463' I I TVD: 16853' I I RT/GL: 128.5' I I RKB: 181.5' I Well Design (conventional, slim hole, etc.): I Ultra Slimhole Injector I Objective: I Kuparuk injector. / I ßqm. I ,/ The injection interval is 1122' MD away from the nearest well bore Z-10 producer. /' /t- 7A/V-1I7) 't:-of The well approaches within 3000' of the nearest Prudhoe Bay property line. 11\;\10 1-0"> 0'10 Vi, ~ c IT b- p aSln gJ U Ing rogram: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. / / MDfTVD MD/TVD bkb 42" 20" Insulated 91.5# H-40 WLD 80' GL 110/110 12 %" 9 5/8" 40# L-80 BTC 3442' GL 3442/2771 ' 8%" 7" 26# L-80 BTC-m 10463' GL 10,463/6853' Tubing 4~" 12.6# L-80 TC-II 9995' GL 9995'/6581 ' 9-5/8" burst 5750 psi, collapse 3,090 psi 7" burst 7,240 psi, collapse 5,410 psi 4-1/2" burst 8,430 psi, collapse 7,500 psi V-119 Drilling Program- AOGCC Page 1 . . Mud Program: Initial Base PF to to SV SV toTO 9.0- 9.5 9.0-9.5 9.0-9.5 8 3,4" Production Hole Interval Density (pp ) Upper 9.5 Interval Top of HRZ toTO 3442' -10463' : YP PV LSND 25-35 10-15 pH 9.0-9.5 API Filtrate 6-8 22-32 10-15 9.0-9.5 4-5.5 Hydraulics: Surface Hole: 12-114" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1863' 600 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 1863' -3442' 680 4" 15.7# 110 3200 10.2 N/A 18,18,18,16 .942 Production Hole: 8 3/4" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3442' - 10463' 540 4" 15.7# 209 4200 11.2 N/A 3x14,3x15 .969 Directional: Ver. I Anadrill(P3)(Slot SF) KOP: 1400' Maximum Hole Angle: 56 dea at 2,460' MD Close Approach Wells: All wells pass major risk criteria. /,' V-109 -19' @ 800' V-114A...:..13' @ 500' Gyro service on standby during kick-off due to well proximity. IFR-MS corrected surveys will be used for survev validation. V-119 Drilling Program- AOGCC Page 2 -. . . Lo Drilling: Open Hole: Cased Hole: Drilling: Open Hole: MWD I GR None None MWD/GR/PWD PEX- Triple Combo. (BHC sonic across Kuparuk) Surface Production Hole Cased Hole: Formation Markers: Formation Tops TVDss Estimated pore pressure, PPG SV6 885 SV5 1545 SV4 1675 Base Permafrost 1720 SV3 2070 SV2 2240 SV1 2590 UG4A 2890 UG3 3250 UG1 3715 Not hydrocarbon bearing Ma 4020 Hvdrocarbon bearinQ, 8.5 PPQ EMW WS2 Na 4270 Hvdrocarbon bearinQ, 8.5 PPQ EMW WS10a 4479 Hydrocarbon bearinQ, 8.5 PPQ EMW Obf Base 4745 Not hydrocarbon bearing CM2 (Colville) 5160 CM1 5765 THRZ 6275 BHRZ (Kalubik) 6455 K-1 6500 TKUP 6520 Kuparuk C 6520 Hydrocarbon BearinQ, 3000 psi, 8.7 PPQ EMW LCU (Kuparuk B) 6570 Kuparuk A 6610 Hydrocarbon Bearing, 3200 psi 9.2 PPQ EMW Miluveach 6685 TD Criteria 150' MD below top of Miluveach ~,1 V -119 Drilling Program- AOGCC Page 3 . . Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT 11.1 ppg EMW Target surface shoe Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casin Size 9-5/8" Surface Basis: Lead: Based on conductor set at 110', 1753' of annulus in the permafrost @ 250% excess and 829' of open hole from top of tail slurry to base permafrost @ 30% excess. . Lead TOC: To surface /' Tail: Based on 750' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2692' MD Total Cement Volume: Lead 432 bbl / 2423 f j 10.7 and. Tail 60 bbl / 33 and sks of Dowell ARTICSET Lite at k. sks of Dowell Premium 'G' at 15.8 Tail V-119 Drilling Program- AOGCC Page 4 " { . . Well Control: /' Surface hole will be drilled with a diverter. The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 4000 psi for MI service considerations, the BOP equipment will be tested to 4000 psi. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: 3200 psi @ 6610' TVDss - Kuparuk A · Maximum surface pressure: 2539 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi) / · Planned completion fluid: 8.4 ppg filtered brine / 6.8 ppg diesel Disposal: · No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-119 Drilling Program- AOGCC Page 5 i . . DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is scheduled to be installed in March 2004. (Slot SF) 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: / 1. MIRU Nabors 7ES. / 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 W' drilling assembly with MWD/LWD (page 5) and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiper/bit trip to surface for a bit wíll be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# surface casing back to surface. Bump plug with 3500 psi and ,,- hold/chart for 30 minutes. Note - A Tam port collar will be run as a contingency if surface drilling is problematic. 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. /" 6. MU 8-3/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. 7. Drill out shoe joints and displace weill to 9.5 ppg drilling fluid. Drill new formation to 20' below 9-5/8" /' shoe and perform Leak Off Test. 8. Drill to +/-100' above the HRZ, ensure mud is in condition to 9.7 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 9. Drill ahead to intermediate TD at approximately 150' MD' below top Miluveach in order to evaluate / entire Kuparuk interval. (TD estimated at 10,463' MD). 10. Run PEX/BHC Sonic from TD to surface casing shoe. /" 11. Run and cement the 7" production casing. Test casing to 4000 psi. 12. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 13. RIH with bit and scrapper and displace well over to seawater. POOH LDDP. 14. Run USIT from FC to TOC. f"'" 15. Run a 3-1/2", 9.2#, TC-II, L-80 completion assembly. Set packer and test the tubing to 4000 psi and /" annulus to 4000 psi for 30 minutes. 16. Shear DCR valve and install TWC. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect wE311 by pumping diesel to GLM with DCR valve, shear, and allow to equalize. 19. Rig down and move off. V-119 Drilling Program- AOGCC Page 6 . . V-119 Drilling Program Job 1: MIRU Hazards and Contingencies > V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. > The cellar area surrounding V-119 (Slot SF) should be checked to insure level prior to move in. > Check the landing ring height on V-119. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drillina Surface Hole > There are two close approach issues in the surface hole. V-114 approaches with a center to center distance of 13' at 500' and V-109 approaches within 19' at 800'. > Hydrates have been observed in wells drilled on V-Pad. These were encountered near the base of permafrost to the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations (during gyro use) V-119 Drilling Program- AOGCC Page 7 . . Job 3: Install Surface Casina 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. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1 OOO'MD to allow remedial cementing. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" Job 7: Drillina Production Hole Hazards and Contingencies » V -119 is expected to cross two faults in the intermediate hole section. The approximate location of the first fault is in the Colville at 4955'TVD ss (+/- 200') and has an estimated throw of 90'. Lost circulation is considered a risk. The second fault is at 6175'TVD ss (+/- 100') in the lower Colville and has an estimated throw of 50'. Lost circulation is considered a minimum risk however significant losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. ~ KICK TOLERANCE: In the case scenario of 9.3 ppg pore pressure at the Kuparuk A target depth, gauge hole, a fractu. r~!iir dient of 11.1 ppg at the surface casing shoe, 9.7 ppg mud in the hole the kick tolerance ist25 . Is. LOT on V-Pad have ranged from 12.5 ppg to 15.5 ppg in the SV-1 formation. Contact iR· Drilling Manager if LOT is less than 11.1 ppg. ~ There are no "close approach" issues with the production hole interval of V-119. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. ERD Recommended Practice Section 5.2 " Operating Practices" .:. "Shale Drilling- Kingak & HrZ" V-119 Drilling Program- AOGCC Page 8 . . Job 8: Loa Production Hole Hazards and Contingencies ~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant piff across logging interval. ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" .:. Wireline Pressure Control Job 9: Case & Cement Production Hole/Run USIT Hazards and Contingencies ~ The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the Kuparuk to 500' above the Schrader Ma and the tail wiff cover from the shoe to 500' above the top of Kuparuk interval. ~ A casing running program wiff be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "G Seal" may be placed across the Schrader and Ugnu to help arrest mud dehydration if losses were experienced while drilling this interval. ~ Ensure a minimum hydrostatic equivalent of 9.7 ppg on the HRZ during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. Pump approximately Y2 volume of casing-casing annulus prior to freeze. After freeze protecting the 7" x 9-5/8" casing outer annulus with 55 bbls of dead crude (2100' MD, 1984'TVD), the hydrostatic pressure will be 7.9 ppg vs 8.6 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. (Approximately 25 bbls of 12.5 ppg mud ahead of the diesel would be required to balance this pressure.) ~ A cement bond log (USIT) wiff be run to confirm injection zone isolation. This wiff be done with the rig prior to running the completion. Send results of USIT log into Anchorage office as soon as possible for evaluation. Notify Bruce Smith (home 345-2948, W 564-5093) upon obtaining results for review for possible remedial cement work. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" V-119 Drilling Program- AOGCC Page 9 . . Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill while running the completion and verify proper safety valves are on the rig floor. The well will be underbalanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus V-119 Drilling Program- AOGCC Page 10 . . V-119 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1860' 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. Intermediate Hole Section: · A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The intermediate hole section will be drilled with a recommended mud weight of 9.7 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk A 9.2 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. · V-119 is expected to cross two faults in the intermediate hole section. The approximate location of the fault is 7250' (6520' TVD ss) +/- 200' and has an estimated throw of 90'. The second fault at 9300' (6175' TVD ss) +/-100' has a throw of 30' and a lower likelihood of occurring. Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. Production Hole Section: · Mud losses of 10-80 bph have been encountered in offset horizontal sections. In particular V-117 lost 5400 barrels of mud while drilling this interval. Contingency LCM material and mud product should be available at the rigsite/mud plant. HYDROGEN SULFIDE - H2S / · This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies ·-,·"w.....·.·~.-.w.',.'______,w,w,_·__" BF. ELEV = 29.0' ,·'w~c.~··~,.,,,"~=,_~~~~·.w_ KOP= 1400' ~=~....Hm"..W'_"-"-h~ ~!<_~gle~~_~__^..mm~~_~eg. Datum MD = .w,,'~~.w~,...._-,~~~~-.-..w=-......y~~~'m~_"'~· Datum TVD = . V-119 9-5/8" CSG, 40#, L-80, ID = 8.835" I 14-1/2" XN NIPPLE 3.750" 4-1/2" TBG, 12.6#, L-80, Tell, .01522 bpf, ID - 3.958" 4-1/2" TBG, 12.6#, L-80, TC-II, .0152 bpf, ID = 3.958" ÆRFORA TlON SUMMARY REF LOG: TCP ÆRF ANGLEATTOPÆRF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I PBTD H 10383' 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I 10463' 1 021131041 NM 1 "'op" "" """".ÜOo (P3) i I I ST MD 1 2 3 4 5 6 . / 2200' H 4-1/2" HES X NIP, ID = 3.813" I TVD btm 5700 5100 4200 3300 2600 DEV 1YÆ KBG KBG KBG KBG KBG KBG VLV LATCH PORT Dummy BTM 4.5x1 Dummy BTM 4.5X1 DCK BTM 4.5X1 Dummy BTM 4.5X1 Dummy BTM 4.5x1 Dummy BTM 4.5x1 DATE 9650' H4-1/2" HES X NIP, ID = 3.813" I 7" X 4-1/2" BKR PREMIER A<R, xxxx' -i 4-1/2" HESX NIP, ID= 3.813" I xxxx' H 4-1/2" HES XN, ID = 3.750" I xxxx' -i 4-1/2" WLEG, ID = 3.992" I Pip in collar Pip in collar ÆRMfT No: API No: 50-029 203 BP Exploration (Alaska) V-119 (P3) Proposal Schlumberger 700.00 1.50 0.00 699.83 618.33 -8.71 9.16 9.16 0.00 1.50 -1.50 0.00 180.00M 5969901.20 590500.06 N 70.32750764 W 149.26605359 800.00 0.00 180.00 799.82 718.32 -9.95 10.47 10.47 0.00 1.50 -1.50 0.00 180.00M 5969902.51 590500.04 N 70.32751122 W 149.26605359 900.00 1.50 180.00 899.81 818.31 -8.71 11.78 9.16 0.00 1.50 1.50 0.00 167.01 M 5969901.20 590500.06 N 70.32750764 W 149.26605359 966.77 3.77 167.01 966.50 885.00 -5.69 14.84 6.15 0.49 3.50 3.41 -19.45 165.06M 5969898.19 590500.59 N 70.32749940 W 149.26604958 1000.00 4.93 165.06 999.63 918.13 -3.17 17.36 3.70 1.11 3.50 3.47 -5.88 162.41M 5969895.75 590501.23 N 70.32749272 W 149.26604461 1100.00 8.42 162.41 1098.94 1017.44 8.44 28.97 -7.43 4.43 3.50 3.49 -2.64 -3.72G 5969884.67 590504.69 N 70.32746232 W 149.26601769 1200.00 11.91 161.31 1197.36 1115.86 26.08 46.62 -24.18 9.95 3.50 3.49 -1.10 -2.64G 5969867.98 590510.41 N 70.32741655 W 149.26597294 1300.00 15.41 160.71 1294.52 1213.02 49.68 70.23 -46.50 17.64 3.50 3.50 -0.61 -2.05G 5969845.76 590518.37 N 70.32735557 W 149.2659. 1400.00 18.91 160.32 1390.05 1308.55 79.17 99.72 -74.30 27.49 3.50 3.50 -0.39 -1.68G 5969818.08 590528.55 N 70.32727962 W 149.2658 1500.00 22.40 160.05 1483.61 1402.11 114.42 134.99 -107.48 39.45 3.50 3.50 -0.27 -1.43G 5969785.05 590540.91 N 70.32718898 W 149.2657 1600.00 25.90 159.85 1574.84 1493.34 155.31 175.90 -145.91 53.48 3.50 3.50 -0.20 -1.25G 5969746.79 590555.40 N 70.32708399 W 149.26561995 1657.94 27.93 159.76 1626.50 1545.00 181.52 202.13 -170.53 62.53 3.50 3.50 -0.16 -1.16G 5969722.29 590564.75 N 70.32701674 W 149.26554653 1700.00 29.40 159.70 1663.40 1581.90 201.68 222.30 -189.46 69.52 3.50 3.50 -0.14 -1.11G 5969703.45 590571.97 N 70.32696504 W 149.26548985 1800.00 32.90 159.57 1748.97 1667.47 253.36 274.03 -237.95 87.52 3.50 3.50 -0.12 -1.00G 5969655.19 590590.55 N 70.32683257 W 149.26534389 1808.98 33.22 159.56 1756.50 1675.00 258.26 278.93 -242.54 89.24 3.50 3.50 -0.11 -0.99G 5969650.62 590592.32 N 70.32682002 W149.26533001 1863.37 35.12 159.51 1801.50 1720.00 288.78 309.47 -271.16 99.92 3.50 3.50 -0.11 -0.95G 5969622.13 590603.34 N 70.32674184 W149.26524342 1900.00 36.40 159.47 1831.22 1749.72 310.16 330.88 -291.20 107.41 3.50 3.50 -0.10 -0.92G 5969602.18 590611.08 N 70.32668707 W 149.26518261 2000.00 39.90 159.38 1909.85 1828.35 371.87 392.64 -349.03 129.12 3.50 3.50 -0.09 -0.85G 5969544.63 590633.48 N 70.32652910 W 149.26500662 2100.00 43.40 159.31 1984.56 1903.06 438.25 459.09 -411.20 152.56 3.50 3.50 -0.08 -0.79G 5969482.74 590657.66 N 70,32635924 W 149.26481657 2200.00 46.90 159.24 2055.07 1973.57 509.06 529.97 -477.50 177.65 3.50 3.50 -0.07 -0.75G 5969416.76 590683.54 N 70.32617811 W149.26461318 Report Date: February 11, 2004 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad I Plan V Slot (S-F) _I_ ty Well: PlanV-119(S-F)F S-Ib. I Borehole: PlanV-119 ._ UWIJAPI#: 50029 Survey Name I Date: V-119 (P3) I February 11, 2004 Torti AHD/DDII ERD ratio: 65.284'17256.55 1t/5.859/1.059 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70.32748261, W 149.26605359 Location Grid NIE Y/x: N 5969892.040 ItUS, E 590500,170 ItUS Grid Convergence Angle: ..0.69111181' Grid Scale Factor: 0.99990930 Comments RTE Base Gubik Ndg Bid 1.5/100 Drp 1.5/100 Bid 1.5/100 Cry 3.5/100 SV6 SV5 SV4 Base Perm WeIlDesign Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 161.900' st dy Vertical Section Origin: N 0.000 It, E 0.000 It 1VO Reference Datum: Rotary Table 1VO Reference Elevation: 81.50 It relative to MSL Sea Bed I Ground Level Elevation: 53.00 It relative to MSL Magnetic Declination: 25.022' Total Field Strength: 57562.176 nT Magnetic Dip: 80.814' Declination Dste: April 09, 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North .> True North: +25.022' Local Coordinates Referenced To: Well Head . Plan V Slot (S-F)\Plan V-119 (S-F)\Plan V-119\V-119 (P3) Generated 2/11/2004 10: 12 AM Page 1 of 2 Comments SV3 End Cry SV2 Cry 3/100 3160.01 56.00 159.10 2608.37 2526.87 1291.60 1313.43 -1209.50 456.91 0.00 0.00 0.00 120.10G 5968688.25 590971.60 N 70.32417833 W 149.26234912 3200.00 55.40 160.36 2630.91 2549.41 1324.61 1346.47 -1240.48 468.36 3.00 -1.49 3.15 119.39G 5968657.41 590983.41 N 70.32409368 W 149.26225634 End Cry 3266.14 54.45 162.49 2668.91 2587.41 1378.73 1400.59 -1291.79 485.61 3.00 -1.44 3.21 O.OOG 5968606.32 591001.28 N 70.32395352 W 149.26211653 SV1 3270.59 54.45 162.49 2671.50 2590.00 1382.35 1404.21 -1295.24 486.70 0.00 0.00 0.00 O.OOG 5968602.89 591002.41 N 70.32394409 W 149.26210770 10-314" Csg pt 3442.58 54.45 162.49 2771.50 2690.00 1522.28 1544.15 -1428.69 528.81 0.00 0.00 0.00 O.OOG 5968469.97 591046.12 N 70.32357951 W 149.26176635 UG4a 3786.57 54.45 162.49 2971.50 2890.00 1802.13 1824.02 -1695.58 613.03 0.00 0.00 0.00 O,OOG 5968204.13 591133.55 N 70.32285036 W149.26108370 UG3 4405.74 54.45 162.49 3331.50 3250.00 2305.87 2327.78 -2175.99 764.64 0.00 0.00 0.00 O.OOG 5967725.63 591290.92 N 70.32153789 W149.2598. UG1 5205.51 54.45 162.49 3796.50 3715.00 2956.53 2978.47 -2796.52 960.46 0.00 0.00 0.00 O.OOG 5967107.57 591494.19 N 70.31984259 W 149.2582 Ma 5730.09 54.45 162.49 4101.50 4020.00 3383.30 3405.27 -3203.53 1088.90 0.00 0.00 0.00 O.OOG 5966702.17 591627.52 N 70.31873062 W 149.25722761 Na 6160.07 54.45 162.49 4351.50 4270.00 3733. 12 3755.11 -3537. 15 1194.18 0.00 0.00 0.00 O.OOG 5966369.88 591736.81 N 70.31781916 W 149.25637470 OA 6519.53 54.45 162.49 4560.50 4479.00 4025.57 4047.57 -3816.06 1282.19 0.00 0.00 0.00 O.OOG 5966092.08 591828.17 N 70.31705717 W149.25566172 OSf Sase 6977.03 54.45 162.49 4826.50 4745.00 4397.77 4419.79 -4171.02 1394.21 0.00 0.00 0.00 O.OOG 5965738.52 591944.45 N 70.31608737 W149.25475438 CM2 7690.80 54.45 162.49 5241.50 5160.00 4978.47 5000.52 -4724.83 1568.97 0.00 0.00 0.00 O.OOG 5965186.91 592125.87 N 70.31457433 W 149.25333896 CM1 8731.36 54.45 162.49 5846.50 5765.00 5825.02 5847.12 -5532.18 1823.75 0.00 0.00 0.00 O.OOG 5964382.77 592390.34 N 70.31236854 W 149.25127588 Top HRZ 9608.53 54.45 162.49 6356.50 6275.00 6538.65 6560.78 -6212.77 2038.52 0.00 0.00 0.00 O.OOG 5963704.89 592613.28 N 70.31050910 W 149.24953711 Sase HRZ 9918.11 54.45 162.49 6536.50 6455.00 6790.52 6812.67 -6452.97 2114.32 0.00 0.00 0.00 O.OOG 5963465.64 592691.97 N 70.30985283 W149.24892350 K-1 9995.51 54.45 162.49 6581.50 6500.00 6853.49 6875.64 -6513.02 2133.27 0.00 0.00 0.00 O.OOG 5963405.83 592711.64 N 70.30968876 W 149.24877010 TopKup/C 10029.91 54.45 162.49 6601.50 6520.00 6881.47 6903.62 -6539.71 2141.69 0.00 0.00 0.00 O.OOG 5963379.24 592720.38 N 70.30961584 W149.24870192 V-119 Tgt 10067.75 54.45 162.49 6623.50 6542.00 6912.26 6934.41 -6569.07 2150.96 0.00 0.00 0.00 O.OOG 5963350.00 592730.00 N 70.30953563 W 149.24862693 LCU/KupS 10115.90 54.45 162.49 6651.50 6570.00 6951.43 6973.59 -6606.43 2162.75 0.00 0.00 0.00 O.OOG 5963312.78 592742.24 N 70.30943354 W 149.24853149 KupA 10184.70 54.45 162.49 6691.50 6610.00 7007.41 7029.56 -6659.81 2179.59 0.00 0.00 0.00 O.OOG 5963259.62 592759.73 N 70.30928770 W 149.24839514 10313.70 54.45 162.49 6766.50 6685.00 7112.35 7134.51 -6759.90 2211.18 0.00 0.00 0.00 O.OOG 5963159.93 592792.51 N 70.30901425 W 149.24813949 TMLV 10313.71 54.45 162.49 6766.51 6685.01 7112.36 7134.53 -6759.91 2211.18 0.00 0.00 0.00 O.OOG 5963159.92 592792.52 N 70.30901421 W 149.24813946 TO / 7" Csg pt 10463.70 ../' 54.45 162.49 6853.71 6772.21 7234.38 7256.55 -6876.28 2247.90 0.00 0.00 0.00 O.OOG 5963044.01 592830.64 N 70.30869627 W 149.24784223 LeQal Description: NorthinQ /YI IftUSI EastinQ (XI IftUSI e Surface: 4645 FSL 1803 FEL 511 T11N R11E UM 5969892.04 590500.17 V-119 Tgt: 3356 FSL 4938 FEL 513 T11N R11E UM 5963350.00 592730.00 BHL: 3049 FSL4842 FEL 513 T11N R11E UM 5963044.01 592830.64 WellDesign Ver 3.1 RT-5P3.03-HF4.00 Bld( d031 rt-546 ) Plan V Slot (S-F)\Plan V-119 (S-F)\Plan V-119\V-119 (P3) Generated 2/11/2004 10:12 AM Page 2 of 2 I WE~ . . Schlumberuer V-119 (P3) ~netk:Paramet&r$ Model: BGGM2003 =- 0' 0 C\I ..... 3600 ....... ~ ..... II CD ~ en 0 > I- 4800 I FIELD STR\JC:TU<E V _ Pa d Prudhoe Bay Unit - WOA ~: 80.814' Mag Dee: +25.022" Surface Location Lat N701938.937 Lon: W1491557.793 1VDRef; RotIIryTable(81.50ftlboVeMSL) SrvyDate: FebnMry11,2004 NAD27 Alaska S. Planes, Zone 04, US ÑItt Northing: 5969892.04 ftUS Grid Conv: +0.69111181' Easting: 5905OO.17ftUS Scl!lIeFactD.999909304 Mi$ÇekltneOU$ Slot PlaI1VSlot(S-F) Plan: V·119(P3} Dat8: ApriI09,2004 FS: 57562.2 nT o 1200 2400 3600 4800 6000 7200 RTE o 1200 . . ..··......·..................·..r..··......·....·..·....·.........T....·..............................I..·..·..·........................·..t.....·.......·.....··....·..........r........·....··.........·........l........·· u·...ëë:fúþik'...··-..-··...··...··...y...··...··_u...··...··...··...··...··-··r··.......··...··...··...··...··...··...··1·...··...u...··.....-··-··...··...··...·i-··-··...··-··...··...··...··...··...··T··...··-··...··...··...··...··...··-··-r....,-..- Ndg Bid 1.51100 ¡ ¡ 1 ¡ 1 1 Dt!I.51100 ¡ : ¡ : : ¡ Bid 1.51100 ¡ ¡ ¡ ¡ _~OO ¡ ¡ ¡ . . ¡ :-:::::f::::::::-F:::::::::l::::~::::::T::::-::::-F::-::-::-:::i:::: .ìlS·"·"-"·"·"·"·Ý·"·"·"·"·"-"·"·"·"r..·..·..·..·..·..·..·..·..-t··..·..-..·..·..·..·..·..··¡·..·..·..·..·..·..·..·..·..t..·..·..·..·..·..·..·......¡........ ::r:::: . .'~::fj.::rii,::::::~:::~::::::::::=:::::::::::::::::::::=r::::::::::::::::::::::::::::::::::1::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::1':::::::: ::::::::::::::::...:.:·::·:::¡:::::··~~:~~?€::::::::::L::::::::::::::::::::::::J::::::::::::::::::::::::::C:::::::::::::::::::::::::r:::::::::::::::::::::::::::¡:::::::: ".~'::::~.""~'.'.'~'.'.'~'....~...'~'.'.'~'.'.'.......'~'~:~::.'~"" ·......·íiñíïë;ÿ....·...¡..··..... ......... ............·....'1"...........·....·...............·T....·..·.. ................ ..·.....T........·.... .......................1"......... -..-1~~ëšg1..·······..·..·..·..·..·..l·..·..·..·..·..·..·.._..·r···..·..·.._..·..·.._..·..~..·..·..·..·..·..·.._..·..·r·..·..· .. r·"·" ...-... .....-... 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Schlumberger ""'Ll V-119 (P3) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Magnetic Pal1l1neters Modet BGGM 2003 Dip: 80.81"" Mag Dee; +25.022" DIt8: AprH 09, 2004 FS; 57562.2n1 Surface location lit N70 19 38.937 Lon: W1491551.793 NA027 AIa$ka state Planes, Zone 04, US Feet Northing: 5969892.04ftUS GrldConv: +<1.68111181· Easting: 5905OO.171tUS ScaIeFaet 0.999909304 Miseelaneous Slot: PlanVSlot(S-F) Plan: V-119{P3) TVD Ref: Rotary Table (81.50ftaboYe MSl) SNyDate: Fel:ifuafy11,2004 -1000 o 1000 2000 3000 RTE Bid 1.5/100 o o -1000 -1000 -2000 -2000 ^ ^ ^ Z =- -3000 -3000 0' 0 0 .... §: .... II (,) ëã u CJ) CJ) -4000 -4000 V V V -5000 -5000 -6000 -6000 -7000 -7000 -1000 o 1000 2000 <<< W Scale = 1 (in):1000(ft) E >>> 3000 . . BPX AK Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 10463.70 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Suñace: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/11/2004 Validated: No Planned From To Survey ft ft 28.50 10463.70 Planned: Plan #3 V1 Version: 8 Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station Casing Points PB V Pad Plan V-01 (S-N) Plan V-01 V10 Plan: PI 3388.44 3250.00 106.85 92.07 14.78 Pass: Major Risk PB V Pad Plan V-02 (N-I) Plan V-02 V5 Plan: Pia 1033.64 1050.00 123.25 13.29 109.96 Pass: Major Risk PB V Pad Plan V-110 (N-X) Plan V-11 0 V7 Plan: PI 349.40 350.00 358.88 6.15 352.72 Pass: Major Risk PB V Pad Plan V-110 (N-X) Plan V-110PB1 V1 Plan: 349.40 350.00 358.88 6.05 352.83 Pass: Major Risk PB V Pad Plan V-112 (S-A) Plan V-112 V1 Plan: PI 349.00 350.00 75.29 6.43 68.86 Pass: Major Risk PB V Pad Plan V-115 (S-X) Plan V-115PB1 V1 Plan: 602.25 600.00 309.61 10.25 299.36 Pass: Major Risk PB V Pad Plan V-116 (S-L) Plan V-116 V1 Plan: PI 1648.46 1650.00 30.89 21.73 9.15 Pass: Major Risk PB V Pad Plan V-116 (S-L) Plan V-116PB1 V3 Plan: 1648.46 1650.00 30.89 21.73 9.15 Pass: Major Risk PB V Pad Plan V-2-08i (N-C) Plan V-208i V1 Plan: V 349.50 350.00 185.85 7.64 178.21 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 349.50 350.00 195.43 7.58 187.84 Pass: Major Risk PB V Pad Plan V-204 (S-O) Plan V (2-04HAW) VO PI 551.27 550.00 177. 73 11.31 166.42 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 791.74 800.00 175.03 11.62 163.41 Pass: Major Risk PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 695.85 700.00 232.69 12.42 220.27 Pass: Major Risk PB V Pad Plan V-207i (N-E) Plan V-207i V1 Plan: V 349.50 350.00 180.95 7.64 173.31 Pass: Major Risk PB V Pad Plan V-21 0 (N-O) Plan V-21 0 V1 Plan: PI 349.00 350.00 250.97 6.04 244.93 Pass: Major Risk PB V Pad Plan V-211 i (S-Q) Plan V-211 i V1 Plan: P 398.98 400.00 206.03 7.24 198.78 Pass: Major Risk PB V Pad Plan V-212i (S-D) Plan V-212i VO Plan: V 1049.75 1050.00 32.24 17.71 14.53 Pass: Major Risk PB V Pad Plan V-213i (S-W) Plan V-213i V1 Plan: P 600.00 600.00 296.45 10.95 285.50 Pass: Major Risk PB V Pad Plan V-214i (N-R) Plan V-214i V3 Plan: V 846.79 850.00 265.32 13.87 251 .45 Pass: Major Risk PB V Pad Plan V-216i (N-T) Plan V-216i V1 Plan: V 349.50 350.00 308.41 7.63 300.78 Pass: Major Risk PB V Pad Plan V-2a06i (N-M) Plan V-2a06i VO Plan: 399.49 400.00 232.04 8.79 223.25 Pass: Major Risk PB V Pad Plan V-2a09i (N-G) Plan V-209i V1 Plan: V 349.50 350.00 180.95 7.64 173.31 Pass: Major Risk PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 399.49 400.00 266.03 8.55 257.48 Pass: Major Risk PB V Pad V-03 V-03 V7 800.00 800.00 345.65 11.28 334.37 Pass: Major Risk PB V Pad V-100 V-100 V7 1299.11 1300.00 276.12 15.49 260.63 Pass: Major Risk PB V Pad V-101 V-101 V7 349.18 350.00 183.12 5.81 177.32 Pass: Major Risk PB V Pad V-102 V-102 V5 609.01 600.00 199.20 11.01 188.19 Pass: Major Risk PB V Pad V-103 V-103 V6 298.99 300.00 297.88 5.04 292.85 Pass: Major Risk PB V Pad V-104 V-104 V13 800.00 800.00 175.83 11.87 163.95 Pass: Major Risk PB V Pad V-105 V-105 V13 941.00 950.00 211.73 12.99 198.73 Pass: Major Risk PB V Pad V-106 Plan V-106A V2 Plan: P 704.23 700.00 273.47 10.36 263.12 Pass: Major Risk PB V Pad V-106 V-106 V10 704.23 700.00 273.47 10.36 263.12 Pass: Major Risk PB V Pad V-107 V-107 V5 941.36 950.00 151.80 12.46 139.34 Pass: Major Risk PB V Pad V-108 V-108 V7 606.94 600.00 196.14 10.11 186.02 Pass: Major Risk PB V Pad V-109 V-109 V2 799.90 800.00 19.05 11.01 8.04 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 799.90 800.00 19.05 11.01 8.04 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 799.90 800.00 19.05 11.01 8.04 Pass: Major Risk PB V Pad V-111 V-111 V25 752.56 750.00 320.41 12.55 307.86 Pass: Major Risk PB V Pad V-111 V-111PB1 V8 752.56 750.00 320.41 12.55 307.86 Pass: Major Risk PB V Pad V-111 V-111PB2 V2 752.56 750.00 320.41 12.55 307.86 Pass: Major Risk PB V Pad V-111 V-111PB3V6 752.56 750.00 320.41 12.55 307.86 Pass: Major Risk PB V Pad V-113 V-113 V6 449.35 450.00 46.93 6.73 40.20 Pass: Major Risk PB V Pad V-114 V-114 V5 499.15 500.00 12.82 8.29 4.53 Pass: Major Risk PB V Pad V-114 V-114A V4 499.15 500.00 12.82 8.29 4.53 Pass: Major Risk . . BPX AK Anticollision Report PB V Pad V-114 V-114APB1 V4 499.15 500.00 12.82 8.29 4.53 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 499.15 500.00 12.82 8.29 4.53 Pass: Major Risk PB V Pad V-117 V-117V9 397.67 400.00 249.67 6.64 243.03 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 397.67 400.00 249.67 6.64 243.03 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 397.67 400.00 249.67 6.64 243.03 Pass: Major Risk PB V Pad V-201 V-201 V8 655.16 650.00 197.19 10.32 186.87 Pass: Major Risk PB V Pad V-202 V-202 V9 847.19 850.00 151.67 12.36 139.31 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 847.19 850.00 151.67 12.31 139.36 Pass: Major Risk PB V Pad V-202 V-202L2 V5 847.19 850.00 151.67 12.31 139.36 Pass: Major Risk ,----- I I Field: Prudhoe Bay Site: PB V Pad Well: Plan V-119 (S-F) Wellpath: Plan V-119 294 pfW-ßi~-1091) PlanV-207i(AAJ~~~ ..:\ Plan V-212i (s-m¡PIan V-212i) ~~ V-1O (Y-IOI) .... ...- ¡_ Pian V-2-QSi (N-C) (Plan V-20Si) 3~ 10 I ~f\ /' Plan V-203 (N-A) (Plan V-203)Á- ~ V:llP.J!&:l~, ~,:117,'" '-~ Xi,,' , -, .~~~/\~' Y~_IOO~:I~~:I¡(S-Q)(PlanV_211i) ~ Ã Þ'1 'þ ~ 13 "~ PlanV-OI(S_N)(PlanY-QI)30~": '\ \',1 I ~ ~ ::X 13 :\ 2 4 PIanPi\¡¡J'6.IS~IDMPf.¡dl\6ßl') 1"'\44 Äc-~4' ~ fl'N ,Í5 ~ I l)' i fb8~j¿;~ i~~ ,'~ ~,',I'~=,,\~ · "".,-,~(~,_,"~, f1/Y/. i'\::> ~F;I/ 2 ~ ~ ~'/I ~i\...-¿ " 1 Y~4 .'6 ~ 27 ~ .,.-- l Y' ,/ i \ ~ VI¡ I . 7,''- 17) '\;;\... /' J ..,&ð'13 ~jj ~ 'lX>t 9 ",,\:\:~~"~? \\ I Ki::: I /"""'ik 0 1'--~í', ~ / y +--f(" ?: [:) Ú( 10 J~ ~ cAy Æ' "\ = toOl 1-c:.1'\ ,\::,~ ':"- 12 \~ >-/~,:7' "', -/ þ./'" I~ ca5f1%1 ~ l 1r ~/'S P ""~'\ -:t::tií' II L< K 262) 20 ~~ Vf; ~ :)~'J/Î',< ...~ ~-'7" "It!.§: ! ,.V ~ 200 f2Y"'~ ~ 1~¡(\3 J\ I "-...\( ~ '0:'" X21! "~ ~-205 (S-P) (Plan Y-205) V-I02 (V-102) 4 \J ~Plan~-fó'5!WI¡MV (Plan V-2a06i) ,(~~~~~%;~è4HAW)) '10)< t7'Lf'" 7 9 P21an Y-214i (N-R) (Plan V-214i) '''''200 '''' 100 Y-ll7 (V-ll7rB1) 100 Plan V-1I2 (S-A) (Plan V-1I2) . 24 , " 200 , 14 " OS) (Plan V-206) V-I~IIIII) , 21 294 ISO ,,- Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [IOOMn] p055224 DATE 1/6/2004 CHECK NO. 055224 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 1/6/2004 PR010504H PERMIT TO DRILL V;\,q H . THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No.P 055224 CONSOLIDATED COMMERCIAL ACCOUNT PAY: 8i.. < P. . r:,' -J'" 1'lIh, '. . ..1; .Jf.. f,.".. . TO THE ORDER OF: STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE ANCHORAGE, AK 99501-3539 DATE AMOUNT January 6,20041 ***77~*$100.00****** NOT)'~ '.. .. .. ... ..... . ...,-.....~,. f."::·:::.:.~q:q: ~...~::: ::::~~:::;::.;:~: ~:~~Ii!~~j~*f~:\·~;;.~~ )<t,,¡t~~ffj¡~(;{::i0;;::7t t.:..:".".,.:;,:~,,:...;~\_,:"" :Or" -. .::",' 1·..;.....:;.. ";,. ;'. . .~\";...,_:'..' II' 0 5 5 2 2 L.II' I: 0 L. 1 2 0 ~ B c:¡ 5 I: 0 1 2 ? B c:¡ b II' . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~ga (/-~ / / I PTD# ¿oy - dc¡ J Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlbore segment of LATERAL existing weD . Permit No, API No. . (If API num ber Production. sbould continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), aJI (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (SO - 70/80) from records, data and logs acquired for weJl (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacinge:Jception tbat may occur. DRY DITCH An dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample intervals tbrough target zones. . . Well bore seg 0 Annular Disposal 0 Program SER On/Off Shore On PRUDHOE BAY, BOREALIS OIL - 640130 Well Name: V-119 TION (ALASKA) INC Initial Class/Type SER LWAGIN GeoArea Unit - Administration pj;¡rmit fee attaçheø_ - - - - _ Yj;¡s 2 Leasßnumberappropriate _ - - - - - _ Yes - - - - 3 _U_nlque well_n_amj;¡_and lJumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs - - - - - - - - -- - - - 4 WellJocatßd in_aciefined_pool_ _ _ Yes 5 Well Jocated proper distance_ from driJIing unitbÞund_a[y - - - - - ~ _ Yßs 6 Well Jocated proper distance_ from otlJer wells _ _ _ Yes - ~ - - - - 7 _S_uffiçient _acreage_aYailable in_drilJiog unjt _ _ - - - - - - Yßs 8 Kdeviated, is weJlbore pl<lUl)cJuded _ Yj;¡s 9 Operator onl)' affeçted party _ - - - - Yes 10 _Operator lJas_appropriate-'~ond inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - -- - - - 11 Pe(n)it can be issued witlJout cOMervatiOI) order_ Yes - - -- Appr Date 12 pj;¡rmit can be issued wJtlJout ad_mil);stratille_approvaJ _ _ - - - - - _ _ Yes RPC 2/26/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocatj;¡d within area al1d_str<lta _authorized by_lnjectiol) Ordj;¡r #: (puUO# in_COO1rnents)_(For Yes aio24 _ _ _ _ _ 15 AJlwßl1sJ.vithin1(4)1)ite_are_a_ofreyiew ideotified (Forservjce_well çm,>,>_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes 2-:1 Q,2-7~,Y~t17,l:OS - -- 16 Pre-produçecl injector; _duration_of pre-proøuctiol) les~ thal13 months_(For_serviçe well only) _ _ No_ - - - -- 17 ACMP_ finding of Con_si,StenCY h_as been js_sued_ for tlJis pr_oiect _ NA - - - - -- ~ Engineering 18 _C_ondu_ctor string provided _ _ - - -- Yes 19 S_urface _casing pJotects alLklloWIl USQWs _ Yes - - - -- 20 CMTvotadequateJo circutate_on_col)d_uctor& SUJtC,Sg _ _ _ _ _ _ Yes Ade!'uate excess, _ _ 21 _CMT v_ot adequate_ to tie-inJongstrillg tOSIJrf Ç&Q_ _ _ _ _ No 22 CMTwill coyerallkl)ownpro_ductiye lJorilon_s_ _ _ _ _Yes - - - - -- 23 C_asing designs adeQuate for C,T, B _& permafrost _ _ Yes - - - - 24 AøequateJank<lgeoJ re_serve pit - - - - - _ Yes lIJabÞrs_7_ES, _ _ _ 25 JfaJe-drilL has a to-40;3 for abandonment been aPPJoved _ _ _ _NA lIJew well, _ 26 _AØequate_wellbore separatjo_n_proP9sed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es - - - - - - - - - - - -- - -- 27 JtdJverter JeqIJired, does ¡t meet reguJatiol)s_ _ _ _ Yes - - - - - - - - - Appr Date 28 JJriIJiog fluid program schematic_& equip listaØequate _ _ Yj;¡s MaxMW9~Ippg, _ _ WGA 2/27/2004 29 BQPf:s, do Jhey meet reguJatiol) _ _ _ _ _ - - - -- Yes - - -- 30 ßOPf:press ratil'19 appropriate; test to_(put psig in_commeots) _ Yes Test to AOQO_ psi.MSP 25_39 psi._ 31 C_hoke_manifold compJies w/APt RP-53 (May 84) _ - - - - - - Yj;¡s - - - - - - - - - 32 Worls will occur withouLoperationshutdown_ _ _ _ - - - - - Yes - - - - - - - - 33 J!i pre!ience_ of H2S gas Rrobable _ No_ - - - - - 34 Mechanicalcoodition of wells withil) ~Oß verified (for_s_ervice ..vel) only). Yes Ceroentil)g recoJds. of <Ill AQR wells jndicate ML Geology 35 Pe(lT)it cao be issued wlo hydrogen_ sulfide meas_ures _ - - -- Yes 36 _D_ata_PJeSeoted 011 pote_ntial pveJpres_sure _zOl1es _ _ _NA Appr Date 37 _Sei'smic_allalysjs of shaJlow gasz_ooes_ NA - - - -- RPC 2/26/2004 38 _Seabed _col)d¡tipo survey -Of oft-sh_ore) _ _ . NA 39 . Contact l)arnelphOl1eJorweelsly progress_reRorls [explorato[yolllyl NA - - Geologic Date: EnQineering Date Public Date Commissioner: Commissioner Commissioner DTs G) ¿) } 4-