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Home My WebLink About197-1701a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 37 BF: NA Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 NA (ft MSL) 22.Logs Obtained: MWD, GR & RES 23. BOTTOM 20" H-40 112' 7" L-80 4,439' 3-1/2" L-80 4070' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Choke Size: Sr Res EngSr Pet GeoSr Pet Eng SCHRADER BLUFF OIL NA Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST 3/9/1998 Date of Test: Oil-Bbl: Flow Tubing Jet Pump Gas-Oil Ratio: 30' Surface Per 20 AAC 25.283 (i)(2) attach electronic information 9.2 Surface 91.1 26 112' Surface 7864' CASING WT. PER FT.GRADE 9/20/1997 CEMENTING RECORD 6008267 1800' SETTING DEPTH TVD 6008155 TOP HOLE SIZE AMOUNT PULLED 562051 562327 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. 50-029-22807-00-00 MILNE PT UNIT H-12 ADL0025518, ADL0025906 2388 FNL, 4150 FEL SEC 34, T13N, R10E, UM 4322 FNL, 3615 FEL, Sec 35, T13N, R10E, UM NA 9/15/1997 8365' 8259' 3800 Centerpoint Dr., Suite 1400, Anchorage, AK 99503 556495 6010042 4207 FNL, 3890 FEL, Sec 35, T13N, R10E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 1/2/2023 197-170 / 322-519 SIZE DEPTH SET (MD) 7836' PACKER SET (MD/TVD) 24" BOTTOM 8-1/2" 250 sx Arctic Set I (Approx) 30'450sx PF E, 130sx G, 873sx PF E, 100sx PF C Surface 8,343' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 327 bbls 14.8 ppg Class G 7864'3-1/2"/9.2#/L-80 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks on 1/19/2023 at 1:55 PM Abandoned 1/2/2023 JSB RBDMS JSB 020723 xGMGR28JULY2023DSR-2/8/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 7,898' 4,096 7,855' 4,064' 7,894' 4,093' 7,938' 4,126' 7,962' 4,145' 8,028' 4,195' TSBD-OA 8,071' 4,228' TSBB-OB 8,151' 4,289' 8,188' 4,318' Formation Name at TD:SBA5 8,188' 4,318' 31. List of Attachments: Daily operations, wellbore schematic and photographs 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jerimiah Galloway Digital Signature with Date:Contact Email:jerimiah.galloway@hilcorp.com Contact Phone: 907-564-5005 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: SBE4-NC If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. SBE2-NE SBF2-NA SBE1-NF Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. SBA5 SBF1-NB TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Authorized Title: Operations Manager 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.01.15 19:34:09 -09'00' David Haakinson (3533) Well Name Rig API Number Well Permit Number Start Date End Date MPU H-12 Well Support 50-029-22807-00-00 197-170 12/19/2022 1/2/2023 WELD MARKER PLATE FOR P&A: AUSTIN MCLEOD WITH AOGCC ON LOCATION FOR WITNESS. VERIFIED CUT AT 7' BELOW TUNDRA LEVEL. TAKE PICTURES. VERIFIED MARKER PLATE IS CORRECT. WITNESSED PLACEMENT OF MARKER. WELD MARKER PLATE. TAKE PICTURES. BACKFILL EXCAVATION. *** JOB COMPLETE. *** EXCAVATE FOR P&A: R/U JACKHAMMER AND CONTINUE TO CHISEL CEMENT SHEATH AND CEMENT BLOCK AWAY FROM CONDUCTOR. ALL CEMENT REMOVED. R/U CRANE AND REMOVE CEMENT BLOCKS FROM EXCAVATION. RIG DOWN FOR THE NIGHT. 12/22/2022 - Thursday CUT CONDUCTOR/CASING/TUBING FOR P&A: R/U WORLEY GUILLIOTINE SAW. R/U CRANE TO WELLHEAD AND PULL 3K-LBS. CUT CONDUCTOR 7' BELOW TUNDRA LEVEL. BROKE TWO BLADES WHILE CUTTING. L/D WELLHEAD AND CONDUCTOR/CASING/TUBING. CEMENT IS TO SURFACE IN ALL ANNULI ALTHOUGH IT IS NOT SMOOTH IN THE TUBING. TOP OFF TUBING AND IA WITH ~ 1 GALLON OF CEMENT AND SMOOTH OUT FOR MARKER PLATE. RD SAW. 1/2/2023 - Monday 12/24/2022 - Saturday EXACAVATE FOR P&A: CONTINUE EXCAVATION. REPLACE BROKEN TEETH ON EXCAVATOR. CONTINUE EXCAVATION. EXCAVATION COMPLETE. BOTTOM OF EXCAVATION AT 10' BELOW TUNDRA LEVEL. RDMO EXCAVATOR. 1/1/2023 - Sunday 12/21/2022 - Wednesday EXCAVATE FOR P&A: R/U JACKHAMMER AND CONTINUE TO CHISEL CEMENT SHEATH AND CEMENT BLOCK AWAY FROM CONDUCTOR. REMOVED APPROXIMATELY 75% OF CEMENT. RIG DOWN FOR THE NIGHT. 12/19/2022Monday Hilcorp Alaska, LLC Weekly Operations Summary EXCAVATE FOR P&A: BEGIN EXCAVATION. REPLACE BROKEN TEETH ON EXCAVATOR. ENCOUNTER LARGE CEMENT SHEATH AND CEMENT BLOCK (6' X 6'). CEMENT WILL REQUIRE JACKHAMMER TO REMOVE. RIG DOWN FOR THE NIGHT. 12/20/2022 - Tuesday EXCAVATE FOR P&A: R/U JACKHAMMER AND BEGIN TO CHISEL CEMENT SHEATH AND CEMENT BLOCK AWAY FROM CONDUCTOR. REMOVED APPROXIMATELY 25% OF CEMENT. RIG DOWN FOR THE NIGHT. Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11”x 2-7/8” WKM tubing hanger, 2-7/8” 8rd EUE threads T&B, 2.5” CIW BPV profile. DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29’ (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) Hilcorp Alaska LLC 7" float collar KOP @ 300’ Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5” Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7”, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7” “ES” Cementer 2270’ 7” landing collar O 9/22/97 JBF Drilled and Cased by 22-E Two 7”x20’ marker joints from 7652’ to 7692’. 3.5” WLEG 7” PLS mech set Packer w/ 2.885” ID. 3.5” X nipple w/ 2.75” ID. 3.5” Camco KBUGM w/ 1” pocket.2231’ 3.5” HES XD Durasleeve w/ 2.75” ID.7829’ 7836’ 7852’ 7864’ 3.5”, 9.3#, L-80, NSCT tubing (ID =2.992”, cap. = .0087 bpf) 8259’ 8299’ 8342’ 02/01/98 M.Linder Initial completion 4-ES 4.5”5 7898’-7923’ 4096’-4114’ “SO” safety shear out sub 7833’ 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2“ 6 8072‘ - 8112’ 4230‘ - 4259’ 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890‘ - 7998’ w/ a 2.72“ OD mill. There is a cement sheath coating the tbg wall starting @ 6260‘. The largest mill run through the cement was 2.730“. 7/10/08. PBTD= 7,998' Cement top at 7,864' SCHEMATIC Proposed Plug 8/17/2022 T. Fouts Well Suspension OOO Tbg Punch 7770' - 7775' 6/20/22 Tbg Punch 7825' - 7830' 6/20/22 Set Northern Solutions 2.281" CIBP at 7850' 6/19/22 Wellhead removed. Con- ductor, casing and tubing cut off 7' below tundra grade. Plugged and abandoned 1/2/2023. Plugged and abandonedDH1/2/2023 2023-0102_Surface_Abandon_MPU_H-12_am Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/2/2023 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandonment Petroleum Inspector Milne Point Unit H-12 Hilcorp Alaska LLC PTD 1971700; Sundry 322-519 1/2/2023: I traveled to location and met with Josh McNeal of Hilcorp Alaska to witness the surface abandonment of the well. The wellhead had been cut off thirteen feet below pad grade. This puts the cutoff depth seven feet below tundra grade (pad built up six feet). All annuli had cured cement to surface. I used a hammer to verify cement integrity. Marker plate was of proper thickness and had proper information bead welded onto it. I found no issues with this inspection and informed Josh he could weld the marker plate on. Attachments: Photos (4) 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.05 16:14:36 -08'00' 2023-0102_Surface_Abandon_MPU_H-12_am Page 2 of 3 Surface Abandonment – MPU H-12 (PTD 1971700) Photos by AOGCC Inspector A. 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Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: MWD, GR & RES 23. BOTTOM 20" H-40 112' 7" L-80 4,439' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate N/A TUBING RECORD September 15, 1997 197-170 / 321-619 50-029-22807-00-00 MILNE PT UNIT H-12 MILNE POINT / SCHRADER BLUFF OIL ADL0025518 & ADL0025906 GL: 37' BF: ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 3-1/2"/ 9.2#/ L-80 SIZE DEPTH SET (MD) 7,836 PACKER SET (MD/TVD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd):7,864 BOTTOM AMOUNT PULLED 30'8,343' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 2388 FNL, 4150 FEL SEC 34, T13N, R10E, UM 4322 FNL, 3615 FEL, Sec 35, T13N, R10E, UM 65.9 HOLE SIZETOP 8259 September 20, 1997 N/A 4207 FNL, 3890 FEL, Sec 35, T13N, R10E, UM 450sx PF E, 130sx G, 873sx PF E, 100sx PF C CEMENTING RECORD 6008267 SETTING DEPTH TVD 6008155 8-1/2" 250 sx Arctic Set I (Approx) N/A 1,800' (Approx) WT. PER FT.GRADE 24" 30' 556495 6010042 8365 N/A 562051 562327 TOP SETTING DEPTH MD Surface 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 Surface CASING 91.1 26 112' PRODUCTION TEST March 9th 1998 Date of Test: Oil-Bbl: Jet Pump Per 20 AAC 25.283 (i)(2) attach electronic information Flow Tubing Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet Geo Water-Bbl: Sr Pet Eng Oil-Bbl: Water-Bbl: Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By James Brooks at 9:03 am, Aug 31, 2022 8/17/2022 JSB Suspended 8/17/2022 JSB RBDMS JSB 091622 xGMGR12NOV2022DSR-9/19/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 7,898' 4,096 7,855' 4,064' 7,894' 4,093' 7,938' 4,126' 7,962' 4,145' 8,028' 4,195' TSBD-OA 8,071' 4,228' TSBB-OB 8,151' 4,289' 8,188' 4,318' SBA5 8,188' 4,318' 31. List of Attachments: Daily operations and wellbore schematic. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. David Haakinson Contact Name:Brian Glasheen Operations Manager Contact Email:Brian.Glasheen@hilcorp.com Authorized Contact Phone:907-564-5277 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled 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. 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. 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. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: SBE2-NE SBF2-NA SBE1-NF SBA5 SBF1-NB SBE4-NC If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.08.30 16:59:25 -08'00' David Haakinson (3533) Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11”x 2-7/8” WKM tubing hanger, 2-7/8” 8rd EUE threads T&B, 2.5” CIW BPV profile. DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29’ (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) Hilcorp Alaska LLC 7" float collar KOP @ 300’ Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5” Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7”, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7” “ES” Cementer 2270’ 7” landing collar O 9/22/97 JBF Drilled and Cased by 22-E Two 7”x20’ marker joints from 7652’ to 7692’. 3.5” WLEG 7” PLS mech set Packer w/ 2.885” ID. 3.5” X nipple w/ 2.75” ID. 3.5” Camco KBUGM w/ 1” pocket.2231’ 3.5” HES XD Durasleeve w/ 2.75” ID.7829’ 7836’ 7852’ 7864’ 3.5”, 9.3#, L-80, NSCT tubing (ID =2.992”, cap. = .0087 bpf) 8259’ 8299’ 8342’ 02/01/98 M.Linder Initial completion 4-ES 4.5”5 7898’-7923’ 4096’-4114’ “SO” safety shear out sub 7833’ 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2“ 6 8072‘ - 8112’ 4230‘ - 4259’ 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890‘ - 7998’ w/ a 2.72“ OD mill. There is a cement sheath coating the tbg wall starting @ 6260‘. The largest mill run through the cement was 2.730“. 7/10/08. PBTD= 7,998' Cement top at 7,864' SCHEMATIC Proposed Plug 8/17/2022 T. Fouts Well Suspension OOO Tbg Punch 7770' - 7775' 6/20/22 Tbg Punch 7825' - 7830' 6/20/22 Set Northern Solutions 2.281" CIBP at 7850' 6/19/22 Well Name Rig API Number Well Permit Number Start Date End Date MP H-12 CTU #6 50-029-22807-00-00 197-170 6/18/2022 8/17/2022 No operations to report. MIRU CTU. Perform weekly BOP test pressure test 295 Low/ 4,236 High, pass. Make up Read logging BHA w/ carrier. 6/18/2022 - Saturday RIH w/2nd SLB 1.56" Tbg Puncher (4 spf, 1606M Charge). Tag CIBP & correct depth to bottom shot. Tbg Punch Interval: 7770' - 7775' MD. PUH above cmt sheath. Circulate down tbg taking returns up IA at 3.0 bpm @ 200psi. Circulate T x IA with no issues. Circulate 20 bbls diesel back down IA taking returns up tbg to replace diesel that was circulated out of IA. No issues circulating both ways. Lay in diesel freeze protect on tubing from 3100' (2500' TVD). Confirm all shots fired. RDMO CTU6. 6/21/2022 - Tuesday 6/19/2022 - Sunday MIRU CTU. Perform Weekly BOP Test. Make up Read 2.20" Logging Carrier & 2.50" JSN. RIH w/closed choke. See weight bobbles going through Cmt Sheath starting at 6260'. Tag at 7888' down / 7883' up. Logged from 7886' up to 2190'. Flagged Pipe at 7790'. Pooh. Receive good data ( +7.5' Correction). Corrected Tag depth = 7894'. Correlate to Tbg Tally 1/23/98. RIH w/ Northern Solutions 2.281" Extra Range CIBP. At Flag Corrected EOP = 7,789.02' MD, correct counter to CIBP COE. Set NS CIBP @ 7,850' MD as per sundry. Pooh w/BHA. Test CIBP to 2500 psi, good test. Recovered 3/8" ball in NS setting tool. RIH w/SLB 1.56" tubing puncher (4 SPF, 5ft interval, 1606M Charge). Tagged CIBP @ 7,850' MD. Correct to bottom shot. Shoot tubing punch interval 7,825' - 7,830' MD. Good indication guns fired. Attempt circulation down tubing up IA to flowback tank, unable to circulate. Pressure up tubing to 2000 psi, IA slowly climbing but unable to circulate .2 bpm @ 2000 psi. Possible fill above packer. Pooh w/BHA to inspect. On surface w/tubing punch, confirm all shots fired. Might need to tubing punch higher above packer. 6/20/2022 - Monday 6/17/2022 - Friday No operations to report. 6/15/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/16/2022 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP H-12 Cementers 50-029-22807-00-00 197-170 6/18/2022 8/17/2022 No operations to report. No operations to report. 8/20/2022 - Saturday No operations to report. 8/23/2022 - Tuesday 8/21/2022 - Sunday No operations to report. 8/22/2022 - Monday 8/19/2022 - Friday No operations to report. 8/17/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU HES cementers: PT to 500/4000 psi, Pump 5 bbls FW down TBG, got 5 bbls back to open top tank. Mix up 14.8ppg Class G cement, pump 327 bbls of cement while taking returns 1:1, with cement returns showing up @ 275 bbls (13.7 ppg) adn came up to 14.8 ppg for the last 30 bbls. Wash up and clean up RDMO. Support techs removed upper tree post full-bore P&A. master valve was greased and cycled several times to flush out cement. tree was taken to G&I to be washed out and serviced for future use. 8/18/2022 - Thursday No operations to report. By Samantha Carlisle at 2:01 pm, Aug 22, 2022 Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11x 2-7/8 WKM tubing hanger, 2-7/8 8rd EUE threads T&B, 2.5 CIW BPV profile. DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29 (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) Hil orp Ala a LL 7" float collar KOP @ 300 Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5 Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7 ES Cementer 2270 7 landing collar O 9/22/97 JBF Drilled and Cased by 22-E Two 7x20 marker joints from 7652 to 7692. 3.5 WLEG 7 PLS mech set Packer w/ 2.885 ID. 3.5 X nipple w/ 2.75 ID. 3.5 Camco KBUGM w/ 1 pocket.2231 3.5 HES XD Durasleeve w/ 2.75 ID.7829 7836 7852 7864 3.5, 9.3#, L-80, NSCT tubing (ID =2.992, cap. = .0087 bpf) 8259 8299 8342 02/01/98 M.Linder Initial completion 4-ES 4.55 7898-7923 4096-4114 SO safety shear out sub 7833 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2 6 8072 - 8112 4230 - 4259 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890 - 7998 w/ a 2.72 OD mill. There is a cement sheath coating the tbg wall starting @ 6260. The largest mill run through the cement was 2.730. 7/10/08. PBTD= 7,998' 8/17/2022 T. Fouts Well Suspension OOO Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU H-12 (PTD 197-170) Coil Flag 06/19/2022 Please include current contact information if different from above. 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DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29’ (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) HilForp AlaVNa LL& 7" float collar KOP @ 300’ Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5” Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7”, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7” “ES” Cementer 2270’ 7” landing collar O 9/22/97 JBF Drilled and Cased by 22-E Two 7”x20’ marker joints from 7652’ to 7692’. 3.5” WLEG 7” PLS mech set Packer w/ 2.885” ID. 3.5” X nipple w/ 2.75” ID. 3.5” Camco KBUGM w/ 1” pocket.2231’ 3.5” HES XD Durasleeve w/ 2.75” ID. 7829’ 7836’ 7852’ 7864’ 3.5”, 9.3#, L-80, NSCT tubing (ID =2.992”, cap. = .0087 bpf) 8259’ 8299’ 8342’ 02/01/98 M.Linder Initial completion 4-ES 4.5”5 7898’-7923’ 4096’-4114’ “SO” safety shear out sub 7833’ 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2“ 6 8072‘ - 8112’ 4230‘ - 4259’ 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890‘ - 7998’ w/ a 2.72“ OD mill. There is a cement sheath coating the tbg wall starting @ 6260‘. The largest mill run through the cement was 2.730“. 7/10/08. PBTD= 7,998' 6&+(0$7,& Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11”x 2-7/8” WKM tubing hanger, 2-7/8” 8rd EUE threads T&B, 2.5” CIW BPV profile. DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29’ (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) HilForp AlaVNa LL& 7" float collar KOP @ 300’ Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5” Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7”, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7” “ES” Cementer 2270’ 7” landing collar O 9/22/97 JBF Drilled and Cased by 22-E Two 7”x20’ marker joints from 7652’ to 7692’. 3.5” WLEG 7” PLS mech set Packer w/ 2.885” ID. 3.5” X nipple w/ 2.75” ID. 3.5” Camco KBUGM w/ 1” pocket.2231’ 3.5” HES XD Durasleeve w/ 2.75” ID.7829’ 7836’ 7852’ 7864’ 3.5”, 9.3#, L-80, NSCT tubing (ID =2.992”, cap. = .0087 bpf) 8259’ 8299’ 8342’ 02/01/98 M.Linder Initial completion 4-ES 4.5”5 7898’-7923’ 4096’-4114’ “SO” safety shear out sub 7833’ 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2“ 6 8072‘ - 8112’ 4230‘ - 4259’ 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890‘ - 7998’ w/ a 2.72“ OD mill. There is a cement sheath coating the tbg wall starting @ 6260‘. The largest mill run through the cement was 2.730“. 7/10/08. PBTD= 7,998' 3URSRVHG7XELQJ3XQFK WR &HPHQWWRSDW 352326(' 3URSRVHG3OXJ OOO ! "#$%& ''(# )*& "#$+,-%./#$+0-*&!1 + * 1+%$%!!& 2!*& #$3-) 44 *&! 56 '6 56 '6 -6'-) 0 *&! +%!!& & )7 8#89 ! " # 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,365'N/A Casing Collapse Conductor N/A Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:tkramer@hilcorp.com Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. See Schematic 112'20" 7"8,343'8,342' Authorized Signature: 10/11/2021 3.5" Perforation Depth MD (ft): See Schematic PLS 7" 23-29 Mech Set and N/A 7,836 MD/ 4,049 TVD and N/A 112'112' 9.2# / L-80 / NSCT TVD Burst 7,864' MD N/A 7,240psi4,439' 197-170 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22807-00-00 Hilcorp Alaska LLC MILNE PT UNIT H-12 4,172'1,656 7864 - 8,259' (CMT) MILNE POINT / SCHRADER BLUFF OIL C.O. 477.05 PRESENT WELL CONDITION SUMMARY Length Size 4,456' 7,998' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: Ted Kramer COMMISSION USE ONLY Authorized Name: Authorized Title: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad Helgeson (1517) 2021.09.13 12:25:26 - 08'00' By Meredith Guhl at 12:52 pm, Sep 13, 2021 321-470 DSR-9/13/21 ptiioon Requiredd? Yes No Subsequeent Forrm R COMMMISS pti COMMISS Rption Required? COMMISS R S RBDMS HEW 9/24/2021 Well Name: MPU H-12 API Number: 50-029-22807-00-00 Current Status: SI Jet Pump Producer Pad: H-Pad Estimated Start Date: October 11th, 2021 Rig: Coil / Pump Truck Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-170 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) Second Call Engineer: David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number: Job Type: Down Hole P&A Current Bottom Hole Pressure: 1,840 psi @ 4,060’ TVD SBHP 4/20/18 Maximum Expected BHP: 1,840 psi @ 4,060’ TVD Well has been SI since 7/2014 MPSP: 1,656 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 77.29 @ 3,137’ MD Brief Well Summary: MPU H-12 was drilled and completed in January 1998 as a Schrader Bluff N sand jet pump producer. The well was drilled as a test of a jet pump completion without the use of screens or a frac. The well was produced for a total of 21 days in March and April of 1998 and was then SI for excessive sand production. In 2003, the well was converted to an NB and NA injector. In 2008, the interval from 8,072 -8112’ was added with Coil Tubing. On 5-19-2008, a cement squeeze was laid in from 7,998 – 8,112’. During the CT pullout from the well the coil tubing vendor discovered min wall thickness in the coil so job was shut down after only washing cement down to 6,200’. The result was a long cement drillout. While drilling out this cement plug, CT milled outside of the casing from 7,890’ to 7,998’. The well was SI but in October of 2008, AOGCC gave the operator permission to put the well back on injection as a N sand only injector. The well continued to inject in this interval until July of 2014 when the well was SI permanently. Starting in August of 2014 , a number of gauge ring runs were completed. The latest one in 2014 being a 2.42” centralizer making it to 7,865’ (SLM). In April of 2018, the well was drifted to 6,244’ with a 2.78” centralizer and 1.75” bailer. In August of 2021, this drift was repeated in with a 1.75” bailer below a 2.75” Centralizer which made it to 6,294’. This demonstrates that there is a flow path to that depth. In addition to these drift runs, Caliber logs have been run in this well in 2007, 2011, 2013, and 2019. The purpose of this Sundry is to P&A the downhole portion of this well by pumping a full-bore cement squeeze down the tubing to isolate the formation and then punch holes in the tubing to pump cement down the tubing and up the OA to P&A the upper portion of the well. Notes Regarding Wellbore Condition x 9/3/21 – Passing MIT-IA was conducted to 1,200 psi. x 9/3/21 – Step rate injection test was conducted to confirm injectivity into formation. .33 bpm (957 psi), 0.5 bpm ( 1,029 psi), 1 bpm ( 1,082 psi), 1.5 bpm (1,265 psi) x 8/31/ 2021 a drift was made to 6,294’ with 2.75” centralizer above a 1.75” bailer (OAL = 86”). x 8-28-21 a drift was made to 2,500’ with 10’ X 2.70” GR. (Note: Tight spots were encountered at 108’ to 310’ SLM) x 5/16/19 a caliper log was ran from 2,250’ to surface. Although the tubing seems to have shifted, there is a good flow path down to that depth. Objective: x To P&A the reservoir from the wellbore with a full-bore cement job followed by a diesel push. x To punch the tubing and circulate the tubing and IA with cement, effectively P&A’ing the upper portion of the well. (Note: Per agreement, the wellhead cutoff and surface remediation will be delayed until the entire pad is ready to be plugged.) Procedure Full Bore Reservoir Abandonment 1. MIRU Cementing equipment and pressure test lines. 2. Perform injectivity test to confirm PIR to formation. 3. Pump Stage 1 Cement job: a. 10 bbls Fresh Water Spacer b. F/B 23 bbls of 15.8 ppg cement c. F/B Drop foam ball d. F/B 45 bbls diesel to displace to 5,260’. e. Clean up cementing equipment to tank. SD WOC. Note: Stage 1 is designed to fill the unintentional sidetrack of the wellbore that was done in 2008 plus the tubing up to 5,260’. 4. Pressure test tubing to 2,500 psi. Chart for 30 min. (Notify AOGCC 24 hours in advance to allow them time to witness.) 5. RU wireline. PT Lubricator to 3,000 psi. 6. PU Tubing Punch, RIH and tag TOC @ +/- 5,260’. (Note: Notify AOGCC 24 hours in advance to allow them the opportunity to witness the tag) 7. PU 5’, punch tubing f/ 5,255’ (+/-) up to 5,251’ (+/-) (4 ft.). 8. RU pump truck, pressure up and circulate tubing and IA to tank until fluids clean up. 9. RU Cementers and pressure test lines. 10. Establish PIR. 11. Pump Stage 2 of cement job a. Pump 10 bbls fresh water spacer. b. F/B 186 bbls 15.8 ppg cement. Be prepared to pump some excess cement until good cement returns are seen at surface. Note: Cement should be at ground level both in tubing and in IA at completion of the job. 12. RDMO Cementers. Note: Well surface P&A work will be performed with the other wells when the pad is abandoned. Attachments: 1. As-built Schematic 2. Proposed Schematic Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11”x 2-7/8” WKM tubing hanger, 2-7/8” 8rd EUE threads T&B, 2.5” CIW BPV profile. DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29’ (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) Hilcorp Alaska LLC 7" float collar KOP @ 300’ Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5” Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7”, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7” “ES” Cementer 2270’ 7” landing collar O 9/22/97 JBF Drilled and Cased by 22-E Two 7”x20’ marker joints from 7652’ to 7692’. 3.5” WLEG 7” PLS mech set Packer w/ 2.885” ID. 3.5” X nipple w/ 2.75” ID. 3.5” Camco KBUGM w/ 1” pocket.2231’ 3.5” HES XD Durasleeve w/ 2.75” ID. 7829’ 7836’ 7852’ 7864’ 3.5”, 9.3#, L-80, NSCT tubing (ID =2.992”, cap. = .0087 bpf) 8259’ 8299’ 8342’ 02/01/98 M.Linder Initial completion 4-ES 4.5”5 7898’-7923’ 4096’-4114’ “SO” safety shear out sub 7833’ 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2“ 6 8072‘ - 8112’ 4230‘ - 4259’ 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890‘ - 7998’ w/ a 2.72“ OD mill. There is a cement sheath coating the tbg wall starting @ 6260‘. The largest mill run through the cement was 2.730“. 7/10/08. PBTD= 7,998' SCHEMATIC Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11”x 2-7/8” WKM tubing hanger, 2-7/8” 8rd EUE threads T&B, 2.5” CIW BPV profile. DATE REV. BY COMMENTS Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29’ (N 22E) MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Size SPF Interval (TVD) Hilcorp Alaska LLC 7" float collar KOP @ 300’ Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 7", 26# L-80 float shoe 20" 91.1 ppf, H-40 4.5” Alpha Jet charges @ 135/45 deg. phasing 112' Stimulation Summary 7”, 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf ) MPU H-12i Howco 7” “ES” Cementer 2270’ 7” landing collar (PBTD) O 9/22/97 JBF Drilled and Cased by 22-E Two 7”x20’ marker joints from 7652’ to 7692’. 3.5” WLEG 7” PLS mech set Packer w/ 2.885” ID. 3.5” X nipple w/ 2.75” ID. 3.5” Camco KBUGM w/ 1” pocket.2231’ 3.5” HES XD Durasleeve w/ 2.75” ID. 7829’ 7836’ 7852’ 7864’ 3.5”, 9.3#, L-80, NSCT tubing (ID =2.992”, cap. = .0087 bpf) 8259’ 8299’ 8342’ 02/01/98 M.Linder Initial completion 4-ES 4.5”5 7898’-7923’ 4096’-4114’ “SO” safety shear out sub 7833’ 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing - conversion to Injector 2“ 6 8072‘ - 8112’ 4230‘ - 4259’ 2/1/08 REH Add-Perf SLB CTU 9 While attempting to mill out cement in the casing, CTU milled outside of the casing wall from 7890‘ - 7998’ w/ a 2.72“ OD mill. There is a cement sheath coating the tbg wall starting @ 6260‘. The largest mill run through the cement was 2.730“. 7/10/08. Prior cement top at 7,864' Proposed Tubing Punch +/- 5,251 to +/- 5,255 PROPOSED OOO Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, May 28, 2015 2:13 PM To: Wallace, Chris D (DOA); Alaska NS - Milne - Field Foreman; Alaska NS - Milne - Wel!site Supervisors Cc: Chris Kanyer; Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: Injector MPH-12 (PTD # 1971700) Due for AOGCC MIT-IA Attachments: image002.jpg All, Long term shut-in water injector MPH-12 (PTD# 1971700) is due for an AOGCC MIT-IA on 5/31/15. The well will not be brought online in time for the test and is expected to remain SI for reservoir management. The well will be added to the Quarterly LTSI Injector Report. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ilik. rp %IJ.sk4.. 1.1.I: SCANNED JUN 0 9 2095 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. Iq ~- /170 File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: GmYscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA /~ Diskettes, No. [] Other, No/Type 'OVERSIZED .Logs of various kinds n Other Complete COMMENTS: Scanned 'by~ik~red, Damtha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 SO F B 7 ZO la Mr. Tom Maunder 'f Alaska Oil and Gas Conservation Commission (� I/ / 0 333 West 7 Avenue ` Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH-01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH-02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH-05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH-06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH-08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 ---,lb MPH-12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH-15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH-18 2041740 50029232240000 18.6 NA Need top job MPH-19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 01, 2011 TO: Jim Regg ` / �(? 5I 1( SUBJECT: Mechanical Integrity P.I. Supervisor C g Y Tests BP EXPLORATION (ALASKA) INC H -12 FROM: Bob Noble MILNEPT UNIT SB H -12 Petroleum Inspector Src: Inspector Reviewed By• P.I. Supry NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB H -l2 API Well Number: 50- 029 - 22807 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN110601052338 Permit Number: 197 -170 -0 Inspection Date: 5/31/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i H -12 'Type Inj.) W ' TVD 4049 I IA i 0 1720 ' 1680 � 1670 P.T.D 1971700 ' TypeTest SPT Test psi 1720 OA Interval 4YRT - P/F P , Tubing 970 978 978 978 Notes: Mono bore well. )-( I A . r Cf *L9)- 1 SC3rs • s ; ot- ; JU N 4 Z Wednesday, June 01, 2011 Page 1 of 1 FW: Request to return MPH-12 to injection after attempted cement squeeze Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 1d, 2008 3:26 PM To: 'rosct0@bp.com'; Husain, Rli K.H; 'Preble, Gary B (SAIC)' Subject: RE: Request to return MPH-12 (197-170) to injection after attempted cement squeeze Page 1 of 3 Gentlemen, Steve Davies and I have finally had an opportunity to review the issues raised on the squeeze and apparent subsequent sidetrack out of the casing in the N sands. While unfortunate, Steve and 1 have determined, in agreement with BP, that based on the event history and the information supplied in the July 17 message that the only possible exit point for injected water is into the N sands. It is acceptable to return the well to service. Tom Maunder, PE AOGCC From: under, Thomas E (DOA) Sent: Tue ay, September 30, 2008 8:20 AM To: rosct0@b com Subject: FW: uest to return MPH-12 to injection after attempted cement squeeze From: Maunder, Thomas E OA) Sent: Thursday, September 0 , 008 To: Preble, Gary B (SAIC) Cc: Husain, Ali K.H; Davies, Stephe Subject: RE: Request to return MPH- 9:58 AM (DOA) Ito injection after attempt cement squeeze Gary, Steve Davies and I are looking into this and wi et back to ou. It appears that the ultimate result, although unintentional, was that the original wellbore was ugged nd a new wellbore segment drilled. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) (mailto:Gary.Pr le@bp.com] ~" ~' Sent: Wednesday, September 03, 2008 2: PM To: Maunder, Thomas E (DOA) Cc: Husain, Ali K.H Subject: FW: Request to return M -12 to injection after attempted ent squeeze Hi Tom, Ali wanted to check o this well and the status. I see that you are showing it as a 1 J currently. James Chester sent you this requ back on July 17, 2008 and I am not sure of what was decided, We would a to put the well back on injection as it stands, to provided pport into its original B sand perforations, to support well MPH-13A. A sundry form 4 was filed forth operation on July 15th, but due to the slightly unusual nature of the c rent state of th well we wanted to inform you and request your approval before returrta^i the well 10/14/2008 FW: Request to return MPH-12 to injection after attempted cement squeeze Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, September 04, 2008 9:58 AM To: Preble, Gary B (SAIC) Cc: Husain, Ali K.H; Davies, Stephen F (DOA) Subject: RE: Request to return MPH-12 to injection after attempted cement squeeze Gary, Steve Davies and I are looking into this and will get back to you. It appears that the ultimate result, although unintentional, was that the original wellbore was plugged and a new wellbore segment drilled. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent; Wednesday, September 03, 2008 2:18 PM To: Maunder, Thomas E (DOA) Cc: Husain, Ali K.H Subject: FW: Request to return MPH-12 to injection after attempted cement squeeze Hi Tom, Ali wanted to check on this well and the status. I see that you are showing it as a 1 WIND currently. James Chester sent you this request back on July 17, 2008 and I am not sure of what was decided, We would like to put the well back on injection as it stands, to provided support into its original NB sand perforations, to support well MPH-13A. A sundry form 404 was filed for the operation on July 15th, but due to the slightly unusual nature of the current state of the well we wanted to inform you and request your approval before returning the well to injection service. Please let me know. Thanks From: Husain, Ali K.H Sent: Wednesday, September 03, 2008 1:43 PM To: Preble, Gary B (SAIC) Cc: Boccardo, Giovanna Subject: FW: Request to return MPH-12 to injection after attempted cement squeeze Gary, Any word on this well? can we put it back on injection? Thanks. Ali From: Chesher, James R 10/13/2008 FW: Request to return MPH-12 to injection after attempted cement squeeze Page 2 of 2 Sent: Thursday, July 17, 2008 5:38 PM To: tom.maunder@alas_ka_.gov Cc: Weggeland, Mark C; Bill, Michael L (Natchiq); Husain, Ali K. H; Preble, Gary B (SAIC}; Nyberg, Emilie; Sauve, Mark A; MPU, Well Operations Supervisor Subject: Request to return MPH-12 to injection after attempted cement squeeze Dear Tom, The Milne Point Unit recently undertook a well intervention on well MPH-12, an injector in the Schrader Bluff reservoir. The operation was intended to cement squeeze perforations in the NB sands and to perforate the lower OA sands, in order to provide support to a new offset well drilled in late 2007, MPH-19. Due to operational issues the operation was not successful. It is described in detail in the attached document. The log and wellbore diagram are also attached. «MPH-12.pdf» «MPH-12.jpg» «MPH-12 story.doc» «H-12 to A-1 cross-section.ppt» The resulting state of the well, after coiled tubing milling operations to clean out cement, is that it is likely to have a small unintentional sidetrack, kicking off 8' above the existing NB sand perforations and going for 108' through the N sand intervals. Attempts to log to confirm exactly which sands are penetrated have been unsuccesful, although we know that #hey are all in the intervals approved for injection under AIO 10-B. The kick-off is also 160' below the packer, so there is no concern about water being injected out of approved intervals. Although the mini- /' sidetrack could have gone through the NC, ND and NE sands in addition to the desired NB sands, the pressure depletion due to production in the NB interval wilt mean the virtually all the water will go into that zone. We would like to put the well back on injection as it stands, to provied support into its original NB sand perforations, to support well MPH-1:3A. A sundry form 404 was filed for the operation on July 15th, but due to the slightly unusual nature of the current state of the well we wanted to inform you and request your approval before returning the well to injection service. Please let me know if you have any questions on concerns. Best regards, James ++++++++++++++++++++++ Viscous Oil Team Leader Milne Point team (desk 448C) BP Exploration Alaska Inc. 900 East Benson Blvd Anchorage, Alaska 99508 office:+1 (907) 564 4142 cell: +1 (907) 441 5130 fames. chesher@bpcom 10!13!2008 Timeline L As shown per the map below hydraulic unit #9 northern area consist of Z producers and 2 injectors. MPH-13A is an NB producer only and the recently drilled MPH-19 (drilled using the old MPH-14 slot) is an OA producer only. The injection was primarily in the N sand until we drilled MPH-19. MPG-09 in the past was NB, OA and OB injector but due to the fact the primary offtake it was from the NB though MPH-13A MPG-09 was converted to N-sand only. MPH-12i was converted from JP producer to NB sand injector in 2003 to support MPS-35 in the south of the HU and MPH-13A. MPG °_ IU 4 ~~H 19L 'H-1 'oA M P' ~13 "I 3 /_ Pyr 13A ~ ~b ,H ~l t MP -09 0~ N5 MPF~ " The team decided to add perforations in the OA in MPH-12 in order to resume injection and support the new MPH-19 well that was put on production in January 19th. On January 30th CTU #8 cleaned out the well to bottom (8210' MD) and then added 40' of OA perforations and the well was put on injection in NB and OA. ~ • On February 15`h slickline performed an IPROF to determine the injection splits in MPH- 12. The results indicated that 99% of the water going into the N sand and only 1% going to the OA. ~ ~~ With only MPH-13A NB off-take in the area, MPG-09i NB sand injection was enough to maintain a voidage replacement ratio of around 1.The team decided to proceed with cement squeezing both NB and newly added OA perforations in MPH-12 and reperforate the OA zone only to force water injection in the OA. On May 19`h CTU moved in to MPH-12 to perform the cement squeeze. All the perforations were successfully squeezed and CTU managed to maintain 1300 psi squeeze pressure. CTU began to contaminate and cleanout the cement from the wellbore when the coil thickness alarm went off indicating low pipe thickness in certain spots in the coil tubing. The decision was made on location to abort the job and not continue with the cement cleanout portion leaving 2000' of cement in the hole. The decision was made on site to avoid any potential safety hazards that could have possibly occurred if the coil parted (people injury, potential spill and the risk of losing part the coil downhole). CTU swapped reels and moved back on the well on May 21 S` to mill the column of cement in the tubing/liner. CTU tagged cement at 6260'. The milling operation started but it was difficult to get weight on bit and CTU got stuck several times in the hole. Due to the high deviation of the well as shown in the plot below it was difficult to get returns back to surface with big milling bites. In total, the milling operation took 23 days. 500 1000 1500 2000 C p 2500 3000 3500 4000 4500 5000 Measure Depth (ft) 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 On July 9`h 2008 CTU milled 7988' to 7998' MD when the motor stalled and the coil became stuck. In an attempt to free the coil, CTU started to pump down the backside to pressure up the tubing and surge the well. While pulling the coil it was found out that the pump was able to inject at 1.1 BPM @1035 psi. A sample obtained from the returns tanks contained steel shavings which indicated a likelihood that coil had sidetracked from the casing. CTU encountered trouble at 7880' ~ when pulling out of the hole, making that the suspected side track kick off point. An attempt was made to run with a nozzle and confirm the sidetrack depth. CTU tagged a hard spot at 7890'. CTU attempted to run pass 7890' using several techniques of pumping down the coil and running in hole at different speed but all attempts failed. The initial plan was to use the nozzle run as a drift for an IPROF / GR / CCL run to find out where the water is being injected in that open hole section. The well was left SI and CTU moved off. The suspected length of the open hole section is about 108' (7890' MD to 7998' MD) and several scenarios of different kick off angles are shown in the graphic below: 3015 ft MPH-14 MPH-12 3[e Ite • • Way Forward: Currently in MPH-13 there has only been off-take from the NB which makes the NB the only pressure depleted zone. From the graphic above, the scenarios indicate that we have penetrated the NB in all cases, so the proposed plan is to put the well back on injection at a low pressure to support MPH-13A. The water will enter the depleted zone following the path of least resistance/pressure -the NB sands. The other sands that may have been penetrated (NC, ND and NE) are very thin (<5'), and although oil-bearing are unlikely to be producible due to their small volume, stratigraphic complexity and competition from more prolific sands like the NB and OA. Subsequently, a RWO is planned for MPG-09 to recomplete the well with water flow regulating valves (WFRVs) to allow for selective injection in the OA and NB sands. • • Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Wednesday, June 18, 2008 9:13 AM To: Maunder, Thomas E (DOA) Subject: Emailing: MPH-12i Cement Squeeze (2).doc Attachments: MPH-12i Cement Squeeze (2).ZIP MPH-12i Cement Squeeze (2).ZIP... Tom, It looks like a 10-403 was never done on this job (it was completed 6/12/08). Did anyone contact you about this job? The PE is out of the office today. The message is ready to be sent with the following file or link attachments: MPH-12i Cement Squeeze (2).doc Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «MPH-12i Cement Squeeze {2).ZIP» 1 M#12i Cement Squeeze and Add O~erfs by To: Mark O'Malley MPU Well Ops Supervisors From: Ali Husain Tract 14 PE Subject: MPH-12i Cement Squeeze and add OA perfs MSHPDWL12 Please perform the attached liner squeeze procedure: March 12th 2008 Est. Cost: $350M IOR: 250 BOPD 1 C Drift, Acid wash, Cement squeeze 2 S Drift and Tag 3 C GR/CCL Tie in log and flag. Add OA Perfs w 2" HSD Power Jet Omega (8072'-8112') (40') WELL DATA Current Status: On water inj. 635bwpd @ 926 psi TARGET maximum rate at 1000 psi Max Deviation: 74-77 degrees from 2900' to 6837'. Hole angle thru perfs =41 deg Min ID: 2.75" at 7852' MD (XN Nipple) Last TD tag: January 31 S~ 2008 at 8210' Last downhole ops: 02/15/2008 (PROF Latest SBHP: 1842 psi @ 4000'TVDSS 07/26/06 (SBHP) Tbg/csg size: 3-1/2", 7" Reference Log ROP/DGR/EWR4 Openhole log (Sept 18th 1997) Objective The objective of this procedure is to completely isolate the N and OA perforations in MPH-12i and re-perforate the OA zone to make this injector an OA injector only. Background MPH-12 was a Schrader N sand jet pump producer drilled and cased by 22-E in Sept 1997. MPH-12 was converted to Schrader N sand injector MPH-12i in 2003 because the perforations kept plugging off from sand deposits in the casing. A Few CTU FCOs along with diesel Xylene wash were performed but the well came back with 100% water and then the decision was made to convert MPH-12 to an injector. The last tag on MPH-12 was before it was converted in April 2003 at 7922' (337') from PBTD. MPH-19 is newly drilled OA lateral producer. MPH-19 will need support in the OA and therefore the plan was to perform a RWO on MPH-12i and set WFRV to regulate IV~12i Cement Squeeze and Add C~ierfs the desired amount of water into the N and OA for pressure support and reservoir management. In January 2008 several jobs were done on MPH-12 in preparation for the rig workover. The well passed MIT-IA to 3000 psi. Slickline MTT log was ran and showed promising results of the casing conditions and finally CTU performed FCO to bottom 8210' leaving ~90' of rat hole. CTU perforated the OA interval using 2" PowerJet Omega guns. There was a significant change in injection pressure and rate post the perforation job and an (PROF was performed in Feb 15t~' 2008. Unfortunately the (PROF had confusing results as the spinner was showing hardly any flow going into the OA (1 %) and 99% of the flow going into the old N sand perforations. However, the temperature log was still showing cooling effect pass the N sand perforation and the temperature will climb up back to formation temperature once we pass the bottom OA perforations confirming the minimum injection into the OA zone. Way Forward: After evaluating the total injection volume and the voidage replacement ratio in Hydraulic Unit #1 the team decided to convert MPH-12i from N sand injector to an OA only injector by cement squeezing all the current perforations and re-perforate the OA zone. This plan is to provide MPH-19 with support in the OA. MPG-09i will be the N sand injector in the north side of the Hydraulic Unit #1 supporting MPH-13A. If you have any questions please do not hesitate to contact: Ali Husain Tract 14 Production Engineer Office: 564-4152 Cell: (303)-304-7374 2 Job Planning IV~12i Cement Squeeze and Add ~erfs Perforations: 7898' - 7923' (25) shot with 4.5" casing gun 8072' - 8112' (40) shot with 2" HSD PJ Omega Deviation at Perfs: 41 ° Gas Lift Design: No gas lift mandrels Tag History: January 31St 2008 at 8210' CTMD Volume to mid perf: Tubing 69 BBLs or 45 BBLs with 1.75" coil. Liner 15 BBLs or 14 BBLs with 1.75" coil. Total 84 BBLs or 59 BBLs with 1.75 coil. Fracture Pressure: 2600 psi (assume 0.65 psi/ft & 4000' TVD) Static: Last BHP in 2006 was 1842 psi @ 4000' A column of diesel down the backside to 2500' MD (2250' ND) will give ~ 300 psi WHP. Measure Depth (it) 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 500 1000 1500 2000 x p 2500 3000 3500 4000 4500 5000 3 III-12i Cement Squeeze and Add t~erfs Risk Discussion • Based on (PROF on 2/15/08, infectivity is expected to be 99% (600 BWPD) (.4 bpm) at 925 psi. • Reservoir pressure is medium for the Schrader Bluff formation (From a SBHP 1842 psi at 4000' TVD) About 22 bbls of diesel (down to 2500' MD or 2200' TVD) will be needed to have approximately 300 psi on wellhead. • The reservoir temperature in the Schrader Bluff is extremely low ~80F. Ensuring that all fluid pumped in the well at 80 deg F is critical to the success of the job. In a similar job on MPS-21 the cement set up prematurely and resulted in abandoning the well (lost Undereamer BHA in the well when tried to mill the unplanned cement plug). • The deviation in the 3.5" tubing is 70°-76°. • The tubing tail at 7864' and close to the perforations (Top at 7898') (34') • The plan is to contaminate cement after squeezing the perfs and cleanout the weltbore to avoid leaving a cement plug in the hole. Pre-Squeeze 1. DHD: Shoot fluid level on IA. 2. RU pump trucks & fluids as necessary. Fluid pack IA. CTU Squeeze 3. RU CTU with HP squeeze skid, Call out the cementers after rigging up. 4. MU BHA with 1.75" fluted no-go CRC, at least 1 stinger and a 2.25" BDN (no checks). Min. ID in well = 2.75" at X Nipple. 5. Spear w/ 10 bbls meth wtr down the backside and fluid pack the well with 126 bbl 80F filtered KCI water or seawater (~1.5 x well bore volume). Begin RIH while pumping the kill (BHST is ~80°F). After 126 bbls of water have been pumped, switch to diesel and pump 22 bbls down the backside to achieve static positive pressure (~22 bbls of diesel down the backside (2500' MD) should result in a positive wellhead pressure of 300 psi, based on SBHP of 1842 psi at 4000' TVD). Note: Do not pump J313 (slick water) into the perfs ahead of the cement, as it will clabber up cement. 4 M~12i Cement Squeeze and Add C~ierfs Well bore volume = 84 bbls to 8210' MD (most. recent tag) 6. RIH, tag TD &PUH until full string weight is recovered. PUH additional 10' and flag pipe. 7. Once TD is reached and pipe is flagged, PUH above the perfs to 7800' and switch to pumping down the coil to ensure the nozzle is clear. Once the nozzle is confirmed clear, pump KCI or SW down the coil to maintain BHT and keep the well liquid packed. Continue this until the cementers are rigged up and PT'd. 8. Line up the cementers to pump down the CT when ready. Reciprocate across perforation interval (7898' -8112') while pumping the following: a) 10 bbls of KCI or Freshwater b) 10 bbls of 3% KCI c) 25 bbls of 12% HCI-10% Xylene (DAD acid) d) 10 bbls of 3% KCI e) Coil volume of spacer water Additives and concentration can be determined per current best practice for a bottom-hole temperature of ~80° F. 9. RIH to flag and pump overflush to ensure all acid is removed from wellbore sump (acid is a cement accelerator). With wellbore flushed, PUH and park at 7800'. 10. Do not proceed with squeeze unless the tubing is liquid packed and gas free and there is some positive wellhead pressure. 11. Batch mix 45 pumpable bbls LARC cement to meet the following specifications: Volume to Pump 45 bbls total Cement Type Liquid Latex Acid Resistant w/ D-176, 3% BWOC Filter Cake .85" firm cake ± 0.15" in lab Thickening Time 5-7 hours at 82°F SBHT Fluid Loss Target 75 cc/30-minutes at 82°F SBHT Acceptable Range 50-90 cc/30-minutes @ 82°F SBHT hi her referred Rheologv YP>5 with no settling or gelation in fluid loss cell. 12. Catch a sample of cement for QC testing. Line up cementers to the coil. Have cementers call out displacement volumes from their tanks. 13. Pressure up IA to 1500 psi. 14. With backside SI, pump the following down the coil. 5 M~12i Cement Squeeze and Add ~erFs 10 bbls spacer water (Do Not use J313 Friction Reducer as it will clabber cement) 45 bbls LARC cement (empty batch mixer) Displace with spacer water 15. RIH with coil to flag as cement reaches the nozzle. 16. As cement reaches the nozzle, open choke and monitor returns (maintain positive WHP to avoid under-balancing the well). Do not pull uphole until ~4 bbls of cement are out the nozzle. (Ideally, this will place the cement top 104' above nozzle in order to prevent dilution of cement while pulling uphole). After 4 bbls cement are out the nozzle, pull uphole and lay in cement 1:1. Pull up to just above top pert (to prevent cement dilution if perfs are taking cement). 17. Close the choke and reciprocate just above top perfs 7898' until wellhead pressure rises 1000 psi. Do not build squeeze pressure white coil is across perfs to prevent getting "noded-in". 18.Once 1000 psi pressure bump is observed, open choke to take returns at 500 psi and begin pulling up, laying in remaining cement 1:1. 19. Position nozzle at cement top just as last barrel of cement reaches nozzle. 20. PUH at maximum speed to Safety of 4000'. NOTE: 45 bbls of cement would extend up the tubing to 4163' MD if no cement goes into the perfs (assuming TD of 8210'). 21. With coil at safety, close the choke, and slowly increase squeeze pressure up to a target of 2500 psi DP at the perfs in 500 psi increments, holding each increment for 15 minutes. Hold 2500 psi for 1 hour. May need to circulate with 2500 psi backpressure occasionally to avoid freezing the coil. Monitor return volumes closely. • Account far fluid and cement densities when calculating DP at perfs (SBHP = 1842 psi at 4000' TVD). • Assuming TD = 8210' and 45 bbls of cement pumped, about 30 bbls of cement can be squeezed behind pipe before the cement top (poor quality cement) is pumped within 100' of the top perfs (7898') • Attempt to achieve at least 1500 psi DP squeeze pressure at perfs. If unable to achieve at least 1500 psi DP squeeze pressure at perfs, contact APE and plan to resqueeze with an additional 45 bbls of pumpable LARC 22. After one hour at 2500 psi, slowly bleed WHP down over 15 minutes to 500 psi WHP. Minimize surges while bleeding down WHP and during cleanout to prevent nodes from getting displaced. 6 12i Cement S ueeze and Add C~ierfs q 23. Swap to 1-1/2# biozan and launch a ball. Chase ball to nozzle then RIH at 1:1 jetting at max CT pressure and clean out to TD 8210'. Slow rate to 1.0 bpm across perfs to minimize node damage. 24. Take barrel count to ensure 1:1 returns. 25. Switch to friction reduced water. Make 3 up/down passes from TD to tubing tail at 7864'. 26. Jet uphole at 80% running speed and max CT pressure. Slow down across all jewelry. 27. Freeze protect the top 2000' and leave 500 psi WHP. 28. RDMO. Cement Volumes Casing: 7. Top Bottom Length bbllft Volume Rathole 8112 ' 8210 ' 98 ' 0.0371 = 3.6 bbis Across Perforations 7898 ' 8112 ' 214 ' 0.0371 = 7.9 bbis Above Perforations 7798 ' 7898 ' 100 ' 0.0371 = 3.7 bbis ' 0.0087 - .0 bbis Behind Pipe Factor 0% Subtotal: 15.2 bbis Excess .bbis Contingency Behind Pipe Volume: - 30.0 bbis Total Cement To Pump: 48 bbls Total Cement Ta Mix: S0. bbls Post-Squeeze- Slickiine 29. Wait on cement to reach full compressive strength (5 days) 30. Drift and tag TOC/TD. Inform tag depth to APE and coil PE to make plan forward. CTU Perforating 31. MIRU CTU and inspect site. 32. PJSM. 7 N~-12i Cement Squeeze and Add ~erfs 33. MU Baker/Weatherford MHA and pull test. 34. MU BHA with SLB Memory GR/CCL tool. 35. Stab on well for PT (Low 300 psi, high 4000 psi). If good RIH to 8100' and stop for 2 minutes. 36. Start logging up at 60 fpm and stop at 8000' and flag pipe. PUH logging at 60 fpm to 7700'. Stop for 2 minutes and then POOH. 37. At surface confirm good data. (Reference Log ROP/DGR/EWR4 Openhole log (Sept 18th 1997)) 38. Hold PJSM with TCP specialist and discuss make up and break down of gun safety. 39. MU BHA (Baker/VNeatherford MHA) + Firing head and gun #1 20'of 2" HSD 6 spf 60 deg phasing PowerJet Omega 2006 HMX gun. Note: Check the firing ball size! 40. Stab on well and PT down the backside (low 300 psi, High 2000 psi). 41. RIH to flag and correct depth. (Get weight checks as necessary). 42. RIH 20' pass flag. PUH to flag then correct your depth based on top of the shot. 43. RIH to position top of the shot at 8092' (Pert bottom section (8092' to 8112'). 44. Drop ball and pump it down with Methanol to fire guns. 45.Once fire POOH. 46. At surface break down guns and recover ball and MU gun #2 (20'of 2" HSD 6 spf 60 deg phasing PowerJet Omega 2006 HMX gun). 47. Repeat step 41 to 43. 48. RIH to position top of shot at 8072' (Pert top section (8072' to 8092'). 49. Repeat step 45 and 47. 50. RDMO and call Pad operator to put well on injection at max pressure of 1000 psi. If you have any questions please do not hesitate to contact: Ali Husain Tract 14 Production Engineer Office: 564-4152 Cell: (303)-304-7374 s -12i Cement Squeeze and Add ~perfs g~ Cameron 2 9/16" 5M 'e a : 11" 5M FMC gen 6 ~ 11"x 2-7/8" WKM tubing hanger, 7/8" 8rd EUE threads T&B, 2.5" IW BPV profile. 20" 91.1 ppf, H-40 112' KOP Q 300' Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 3.5", 9.3#, L-80, NSCT tubing (ID =2.992", cap. _ .0087 bpf) 7", 26#ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf Pertoration Summary Ref loa: Snerrv Sun DGR 09/2 Size SPF Interval (TW) 4.5" 5 7898'-7923' 4096'-41 2" 6 8072' - 8112' 4230' - 4: 4.5" Alpha Jet charges ~ 135/45 deg. phasing Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29' (N 22E) ' Camco KBUGM 2231' 1" pocket. /co 7" "ES" Cementer 2270 i" HES XD Durasieeve 7829' 2.75" ID. O" safety shear out sub 7833' PLS mech set Packer 7836' ' 2.885" ID. 5" X nipple w/ 2.75" ID. 7852' i' WLEG 7864' 0 7"x20' marker joints from i2' to 7692'. landing collar (PBTD) 8259' float collar 8299' . , 26# L-80 float shoe 8342' DATE REV. BY COMMENTS 9!22/97 02/01l98 M.Linder n an ase y 2- Initial completion 4-ES 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing -conversion to Injector 2!1108 REH Add-Pert SLB CTU 9 MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 BP EXPLORATION 9 MPU H-12i • ~~ ~~ Tree: Cameron 2 9/16" 5M Wellhead: 11" 5M FMC gen 6 w/ 11"x 2-7/8" WKM tubing hanger, 2-7/8" 8rd EUE threads T&B, 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 112' KOP @ 300' Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 3.5", 9.3#, L-80, NSCT tubing (ID =2.992", cap. _ .0087 bpf) 7", 26# ppf, L-80, Mod. btrc. casing ( drift ID =6.151", cap. = 0.0383 bpf Stimulation Summary Perforation Summary Ref log: Saerrv Sun DGR 09/: Size SPF Interval (TVD; 4.5" 5 7898'-7923' 4096'-4 2" 6 8072` - 8112' 4230` - ~ Orig. KB Elev. = 65.9 ' (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29' (N 22E} " Camco KBUGM 2231' 1 " pocket. vco 7" "ES" Cementer 2270 .5" HES XD Durasleeve 7829' ~/ 2.75" ID. i0" safety shear out sub 7833' " PLS mech set Packer 7836' r/ 2.885" ID. 1.5" X nipple w/ 2.75" ID. 7852' .5" WLEG 7864' vo 7"x20' marker joints from i52' to 7692'. "' landing collar (PBTD) 8259' '" float collar 8299' T', 26# L-80 float shoe 8342' 4.5" Alpha Jet charges @ 135/45 deg. phasing DATE REV. BY COMMENTS g/2y97 02/01/98 M.Linder n le an ase y - Initial completion 4-ES 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 11/26/03 Lee Hulme Update drawing -conversion to Injector 2/1 /08 REH Add-Pert SLB CTU 9 MILNE POINT UNIT WELL No : H-12i API : 50-029-22807 BP EXPLORATION MPU H-12i ap M RH-12 AP1:500292280700 SCALE t 600 PLOT DA7E20-INar-2006 LMS_n~eltpacKage_md Y CALC_SB_M.Nt7_PAY_MM_1 ~ rtn ~ o , msfl snc.sor I b ~ H Oi?PM 2040 calc._~C vclov_nd ~ •.^ ~ , O m m C RPD '~' rhOb o - v/v + ~ _core.sor_plug ~ ^a , ~.. _ _ ,~ • , .-- _ C811------ M o~1 a y ., ~~:= LC_56 Y~Y_~: ~ - I 0 GJPI 1D tp a~ ain 0.2 OHOrt~ 200 1.55 O/C3 z.6~ - -Y- CALC_58_M.SW_WS_1 GR RS nphi c ' , v.N _______ c41c_sb.rclay CALC_SB_AA.SW~IRCHIE_1 0 cta>?i 150 0.2 otinm 200 0.6 v/v 0 0 vN ~ ~"~` ~~ c5 ~ ~ ~' . s -6000 ` -~ `~ i~ 7900 ''~ _ _ SBF1-NB 2~ _._. -4050 .~ ----- 1 1 .7350 -- _- - ~~ - -- -N __ ? ~ - -4100 8000 • s _y `i SBE 1 -NF ,:~ 8050 =4150 Z _ __..__ r TSBD-OA .:~ 8100 - s _ s -4200 3 ~ ti4 c ,? {-~ ~ TSBB-OB ~+ ~~ <~ . 6200 ~' t ~t~ -~ ~- j 6250 -4300 __.~_~.. _r i-; f .L I ~ ~ I I_... __ ~ __ l._ ~~-~ 8300 __ I ' ~. _._..~.__ ......T..._~. -4350 ,.._~__..~.......L...~._ ~.~_. ~_~-. ---~--. _~_i 8350 . 1. Selu•ader Bhiff Oil Pool Authorized )s~jectiou Strahuu: Authorized fluids may Ue injected into the strahun that correlates with the inteiti~al Uet•~•een the ineastuecl depths of 4.1?-t feet ancl =1.~r)0 feet in the Conoco hiPL~ Well No. A-1. 12761 ft MPA-01 MPH-12 GR Oeplh ResisitNity GR Depth Resisrtivrty GR MD> RT(LGI GR MU> RT GAPI 150 J ?lay JHI~1NItV00 00 API 15 J .-~~- vhMM:! ~~ ~~~ UU - e ow :~~e en a av ~ j ' ~''~~ ~ SBF2-NA .' -,,,,_. F - - -- ~ 4zoo ~ SBF1-NB>~~ - ~ SBF2-NA SBF72 ; ..._ _ _. ~ _ ._ _ _.i . .4 - SBF12 --- ~._-.. ._ __._ ..... _1 .- . ..._ - - -- SBE4-NC ~ -- SBE2-NE -r- SBE3-ND __ - -- SBE2dJE - ~ '''''o ~ 4900 i ti 00 --I ---- -_ i - -t-..-... SBE1-NF __ ._ +-~ - - _ ._._ SBE1-NF ~ __-. - ..._ • TSBD-OA I i ~ _ + TSBD-OA ~ _ ~ i __ _ -- TSB L et o0 - .... - - .~ - - t _ _ TSBC - i--- I -~ -- ~..,._ -- - --... ._... -42c __ .._ - iaBB-OB i _._ _ _,. i -e i -- TSBB-OB } -a-- i - ~ - 4600 8200 _ ~.,__ 1 - }-_ -4600 _ _ - -4600 - - - - - - _~ I r 4174' and ~ Above NA 4800' and 300+ feet and below OB • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, Juty 29, 2008 11:51 AM To: 'Prebte, Gary B (SAIC)' Subject: MPH-12 (197-170) Gary, I was reviewing the 404 for the cement milling performed 7/2 - 7/11. On 7/3 cement was tagged at 7666'. At the end of January the clear depth was 8200'. Appears to be a type in the record from 1/31. tt appears that work was done to "put" cement in the hole between the end of January and early Juty. Do you have any reports for that work? Thanks, Tom Maunder, PE AOGCC Ah1N~~ ,IUL ~ ~- 2008 Maunder, Thomas E (DOA) From: Prebte, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Tuesday, July 29, 2008 1:57 PM To: Maunder, Thomas E (DOA) Subject: Emailing: MPH-12-MILL.rtf Attachments: MPH-12-MILL.ZIP +1PH-12-MILL.ZIP (9 KB) Tom, I re-ran the events summary and dated it to widen the dates or work completed. The message is ready to be sent with the following file or link attachments: MPH-I2-MILL.rtf Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «MPH-I2-MILL.ZIP» STATE OF ALASKA ~, ,~ ,~, ~ ~.~~D~ ALA OIL AND GAS CONSERVATION COI~%I IC~N`~"`'`~' REPORT OF SUNDRY WEI~i~1~.~~e,~ , ,;~;~; 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimul~~ v Other ~ MILL CEMNT' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ' 197-1700 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22807-00-00' 7. KB Elevation (ft): 9. Well Name and Number: 65.9 KB ~ MPH-12 8. Property Designation: 10. Field/Pool(s): ADLO-025518 ~ MILNE POINT Field/ SCHRADER BLUFF Pool 11. Present Well Condition Summary: Total Depth measured 8365 / feet Plugs (measured) None true vertical 4456.12 ~ feet Junk (measured) None Effective Depth measured 8299 feet true vertical 4273 feet Casing Length Size MD TVD Burst Collapse SURFACE 82' 20" 91.1# H-40 SURFACE - 112' SURFACE - 112' 1530 520 PRODUCTION 8312' 7" 26# L-80 SURFACE - 8342' SURFACE - 4438' 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 28 - 7864 0 0 - Packers and SSSV (type and measured depth) 7" PLS PKR 7836 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: 129 450 1822 Subsequent to operation: 0 17.023 14. Attachments: 15. Well Class after oroposed work' Copies of Logs and Surveys Run Exploratory 1~`! 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 Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/15/2008 Form 10-404 Revised 04/200 R ~ ~ > ~~ A ~ s ~~ ~~L ~ 9 Moog Submit Original Only ~~y~ MPH-12 197-170 PERF ATTACHMENT ~J Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPH-12 1/24/98 PER 7,898. 7,923. 4,096.19 4,115.18 MPH-12 8/1/01 FCO 5,824. 7,812. 3,218.08 4,031.12 MPH-12 8/1/01 FiL 5,824. 7,923. 3,218.08 4,115.18 MPH-12 11/1/01 FIL 7,904. 8,299. 4,100.75 4,404.59 MPH-12 _ 11/27/01 FCO 7,904. 8,241, 4,100.75 4,359.38 MPH-12 4/14/03 FIL 7,922. 7,923, 4,114.42 4,115.18 MPH-12 2/1/08 APF 8,072. 8,092, 4,228.82 4,244.17 MPH-12 2/1/08 APF 8,092. 8,112. 4,244.17 4,259.54 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED 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 n • MPH-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/19/2008 Publishing On InterAct PU BDN for acid_w~sh/cement snueeze M/U BHA open well RIH.attempt to kill well w/ 130 bbls KCL.Formation tight. circ acid to nozzle. recip across oerFs w/ from 7898 to 8112. Pump 45 bbls LARC cmt sqz with est 21 bbls behind pipe. Had to come out of the well due to below min. wall thickness only jetted down to 6200' before the bad spot was tested. ***job .incomplete*""`*"" 5/20/2008 Job continued from 5/19108 Road to yard for reel swap.Return to MPH-12 rig back onto well to begin milling operations.Continue on 5/21/08 WSR 5/21/2008 Continued from 5/20/08 (tnteract publishing) Finish R/U begin RIH to Dry tag cement wl motor,2.72" 3 blade junk mill. Mill from 6260 to 6750'. '"''`job continued on 5/21/08 WSR'"`* 5/22/2008 Continued from 5/20/08 Mill from 673T to 6844. Pooh ck BHA {bit worn on outside edges) RIH w/ new bit. Mill to 6937 Motor stall bit stuck. Pumping Geo pill working pipe. '"`job in progress*'` 5!23/2008 Continued from 5/22/08 (Interact publishing) Worked pipe free pooh. Trim 100' of pipe. RIH w/ motor, 2.72" 5 blade mill. Weight ck @ 6800' was 34k.( Deepest mill depth was 6937) Recip ooh. InstaN 2.795" mill and RIH. seeing motor work @ 6264. Recirculation system in service. Mill from 6937 to 6953..*"job in progress"* 5/24/2008 Continued from 5/23/08 (interact publishing) mill from 6952 to 6978. progress slowed pooh.outside edges on bit wom. RIH w. 2.8" 3 blade mill. Milled from .6978 #0 6998. While attempting to pull up for recip maxed out @ 34k. Pump .new load w/ .8% safe tube and 15 bbl sweep geovis and pipe pooh @ 32k. recip ooh.Found metal flakes stuck to tools(magnatized) RBIH to bottom mill to 7041' *"job in progress"" 5/25/2008 Continued from 5/24/08 (interact publishing) Mill w/ aggitator and 2.8" three blade mill from 7040 to 71~ UW still running all over they aren't consistent at the same depths twice. Consistently pulling at 34k max for the coil. So we POOH freeze protect well and surface lines.""`job in complete"'` • • 6/7/2008 CTU #5. FCO/Mill cement. MIRU CTU. "'"`<InterACT is Publishing>*"" Make up BHA #1, 2.5" JSN. RIH and begin frequent weight checks. At 3000', pulling 2k over normal string weight. „~°i,~„n ~F~C_Q using 1 % XS KCI with 0.8% SafeLube taking 500' bites and pumping 5 bbl sweeps of 150,000 LSRV Goevis and chasing to 1500'. Initial bite from 3000' had good cement returns at surface. Continue technique washing to 7155' ctm. Pump 10 bbl Geovis and chase from bottom. Up weight from 7155' at 15k. MU BHA #2 Milling BHA W/ .Concave 5-Blade Junk Milt and RIH. Tagged CMT (dt 7162' PU and WO dirty vac to make room in open top for Geovis sweeps while milling. Started milling at 7161' and milled to 7171' without any stalls but having trouble getting motor work. "'`* Job continued on WSR 618/08 *** 6!8/2008 CTU #5. Mill cement. *'"` Continued from WSR 6/7/0$ *"* <InterACT is Publishing> Continue Milling cement. Milling came to a halt @ 7171', several tries to get motor work or stalls failed POOH to check tools. Tools looked & tested fine, face of mill was clean and didn't show any signs of wear. Changed mill from 5-Bade Concave to 5-blade Tappered. RIH & tagged bottom and started milling. Milled_to 7188', then tripped to 1500' due to 5k overpull off bottom. Bottoms up good cement fines at surface. Confinued milling to 7201'. POOH and make BHA #4, adding Andergauge AG-itator to BHA. Begin milling at 7200' using 1 % XS KCI with 0.8% SafeLube and Geovis sweeps, with long sweeps to 1500'. Penetration rate increased to 20 fph average with AG-itator. Milled to 7260' and tripped to 1500'. Large slug of cuttings unloaded @ 3700' .and plugged off choke and had to swap to bypass. At 1500' returns showing slugs of CMT and pea size chunks of CMT continue POOH to 250' and returns .cleaned up. RIH and milled to 7268' and Pump Truck lost power for a second and then died a couple minutes later PU off bottom. Supervisor found a bad connector on a sensor and a mechanic is on his way out. Tractor shut down again and restarted, SLB hands trying to get it to stay connected with electrical tape, continue POOH last Geovis sweep is on its way out with 8' of milled CMT. Milled 9T of CMT '""` Job continued on WSR 6/9/08 "~`' 6/9/2008 CTU #5. Mill cement. "'`* Continued from WSR 6/8/08 "`~" <InterACT Publishing> Continue POOH waiting for mechanic to repair tractor. Tractor repaired RIH to continue milling CMTat 7268'. Milled to 7290' and long tripped to 1400' all 3 eovis Pills came goo fines 8~ chunks out of well. RIH to .continue milling. Continued milling with 1 % XS KCI and Geovis sweeps, pertorming wiper trip to 400'. 1/2" cement pieces seen in returns. RIH and milled to 7390' and tripped to surface, at 2215' well started unloading CMT fines & pea size chunks. Cleaned up surface return lines &RIH. Milled to 7418' "*"Job continued on WSR 6/10/08'""` 6/10/2008 CTU #5. Mill cement. '""° Continued from WSR 6/9/08 *'"' <InterACT Publishing> Continue milling from 7418'. Milled to 7420' and tripped to surface, 100' from surface, surface lines are plugged. Lined up backside to pump and purged lines clean and RBIH. Milled to 7450' and tripped to surface. RIH and continue milling to 7480'. on long trip, began plugging off both sides of the .choke and choke bypass. Required to surge tank manifold to c{ear plugging. At surface, cleared all blockages to tanks and chokes. Material cleared from lines was 1/4 to 1/2" cement pieces. Mill had 3 of 5 water courses blocked with cement chunks. Makeup 2.73" 5-bladed concave mill. RIH and continue milling with good penetration rate with the mill. Tripped to surface, RF IH and milled to 7540' and tripped to surface. _ ""'Job continued on WSR 6/11!08""" • • 6/11/2008 CTU #5. Mill cement. *"* Continued from WSR 6/10/08 "*" <InterACT Publishing> Continue RIH to continue milling @ 7540'. last trip out pulled heavy off bottom, try pumping Geovis pills every 25 bbls instead 40, mill is turning CMT into dust. Milled another 30' to 7570 PU WT 28.5k RIH to wait for Geovis pill and stacked out and packed off then popped free, PU and pulling 35k, RIH and WT was 1 k, PU and pulling 33-34k. WT slowly dropped off and continued POOH. OOH and Re-circ fluids need to be swapped out, WTF going back to shop to R8~R tools and get some sleep. SLB willdo maintenance (pack- offs, chains, check surface lines for solids and perform BOP Test. Mwll with MPU will witness test. '""'Job in Progress*~"' 6/11/2008 CTU #9 Milt cement.Continued from WSR ended at 4 am 6/11/08 (Interact Publishing) Mill from 7570'to 7600'_Trip to surface chasing cement. On last trip to surface wts looked good had some plugging at the BS Micro Motion so we opened the bypass around the meter. 6/12/2008 Continued from WSR 6/11/0$ (Interact Publishing) The PUW s were heavy so coming to surface chasing cement. Once at surface had some plugging in the at choke skid flushed out all surface equipment. Popped off well looked at Milt looked good. Stab back on RIH. Mill from 7655 to 7665 POOH R/D Move to L- 219. Cut 100' of coil for pipe management. .........Job complete'............ 7/2/2008 CTU #5. Cut off 6500' of CT in 6' sections to eliminate high cycle we `: of the string at Schlumberger yard prior to roading CTU to MPH- d. '** Job continued on WSR 07/03/2008 ~""` 7/3/2008. CTU #5 w/ 1.75" OD CT. tive: mill cement. Continued from WSR 07/02/08. MIRU CTU <Inter T publishing > Perform weekly BOPE test. MU and RIH with OD JSN. Tag ment tap at 7666' ctmd. Circulate well to 88,000 LS geovis gel system filteri etums through MI cuttings control unit (with i nsic shaker and centrifuge) for irculation. Jet geovis from 7666' d to surface; no cutiings observed in it. Makeup BHA #2, 2.73" 5- ded concave mill with Andergauge AG-Itator. in milling at 7665' at 1.5 pm. Depth at midnight - 7684'. '""* Job continued on WSR 07/03/08 `"" • • MPH-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTT VITYDATE SUMMARY 7/2/2008;.. CTU #5. Cut off 6500' of CT in 6' sections to eliminate high cycle wear section of ;.the string at Schlumberger yard prior to roading CTU to MPH- pad. ''*** Job continued on WSR 07/03/2008 *** 7/3/2008 7/4/2008 7/5/2008: :CTU #5 w/ 1.75" OD CT. Objective: mill cement. Continued from WSR 07/02/08. 'MIRU CTU #5. <lnterACT publishing > Perform weekly BOPE test. MU and RIH iwith 2.1 " OD JSN. Tag cement top at 7666' ctmd. Circulate well to 88,000 LSRV ',geovis gel system filtering returns through MI cuttings control unit (with intrinsic '';shaker and centrifuge) for recirculation. Jet geovis from 7666' ctmd to surface; no ';cuttings observed in MI unit. Makeup BHA #2, 2.73" 5-bladed concave mill with 'Andergauge AG-Itator. Begin milling at 7665' at 1.5 bpm. Depth at midnight - .7684'. *'`* Job continued on WSR 07/03/08'** ........._~.._~..._ ......._._., rv __. _....... __...... ..__ 'CTU #5 w/ 1.75" OD CT. Mill Cement. *** Continued from WSR 07/03/08 *"" Continue milling cement from 7684'. Perform short sweep every 10' of milling. -Mill to 7722' ctmd. Begin chasing to surface when mission mag pump fails. Lose 'ability to circulate through MI van, come down on pump and pull to surface. '!Replace mission mag pump. RBIH and resume milling from 7722' ctmd. Continue !.milling ahead to 7784' ctmd. M-I solids control van plugged off a centrifugal ``causing a 26 gallon Geovis spill into containment. When solids control van went ';down, chase cuttings to surface using 100 bbls of 1 % XS KCI. Repair centrifuge `:;pumps while RIH. Park CT at 6000' and turn well back over to Geovis. Milled to 7784' as of midnight. *** Job continued on WSR 07/05/08 *** __~ :CTU #5 w/ 1.75" OD CT. Mill Cement *** Continued from WSR 07/05/08 *'`" ',lnterACT publishing. Start milling at 7784' taking 15' bites. and short tripping to ',7000', tripping to surface after every three bites. Continued to pull heavy when ',short tripping with up weights to 20k over string weight. Mill in this fashion to 7862' 'ctmd. While tripping from this depth weight gradually increased to coil limit, rendering us unable to POOH. Held 1800 psi IAP and reattempted; up weight '!decreased by 10000 Ib. Pull to surface. Inspect MHA -noted no deficiencies. ;Lay down mast for annual mast inspection. RIH with 2.1"JSN. Dry tag bottom at ';7873' ctm. Up weight off bottom was 33k. Begin pumping Geovis at 1.7 bpm, up Iweight reduced to 24k. RIH and tag bottom washing. Chase out of hole pumping 're-circulated Geovis. Depth milled to at 7873' ctm. as of midnight. *** Job continued on WSR 07/06/08 *** 7/6/2008 CTU #5. Mill Cement. *'* Continued from WSR 07/05/08 *** Start depth at 7874' `ctmd. POOH chasing fill pumping recirculated Geovis. Makeup Weatherford 5- `bladed 2.73" concave mill with Andergauge AG-Itator. RIH and begin rotating '„'motor from 6950'. Begin milling at 7874' ctmd. Up weight before engaging cement 'at 24.2k. Mill cement in ten-foot bites, chasing each bite to 7000' and chasing... ''every third bite to surface. Mill in this fashion to 7912' ctmd_. On bottom milling. Re-milled to 7910' very slowly. POOH to inspect toolstring. At surface, mill face was worn flat with 5/8" scarring on mill face. After pressure testing BHA, 5 gallon ';Geovis spill occurred out top of BOPs while bleeding off tools due to improer valve alignment. End depth at 7910' ctmd. ''`** Job continued on WSR 07/07/08 ""* 7n/2oo8 CTU #5 w/ 1.75" OD CT. Mill Cement. "** Continued from WSR 07/06/2008 *** < InterACT publishing > Start depth at 7910' ctmd. Makeup Milling BHA with 5- bladed 2.73" concave mill. RIH and begin milling at 7917' ctmd. Mill in 15' bites, then short trip to 7000'. Continue milling ahead to 7968' ctmd. At 7968', ROP dropped significantly. Trip out of hole to inspect BHA. At surface, mill had lost most of cutting structure, with radial striations seen up to 1/2" from out edge. Makeup new 2.73" 5-bladed convex mill. Swap out 200 bbls of used Geovis with new 120,000 LSRV Geovis in gel system. Depth at midnight at 7968'. *** Job continued on WSR 07/08/08 *** 7/8/2008:CTU #5 w/ 1.75" OD CT. MiII Cement *** Continued from WSR 07/07/08 *"" <InterACT publishing intermittantly> Start milling at 7968'. RIH with 2.73" Convex 'mill. Begin rotating mill at 7450'. At 7884' ctmd, 2 stalls were recorded. RIH and resume milling at 7965'. Mill 15' and then short trip to 7000'. RBIH and mill ahead ',,to 7985' ctmd. While on bottom milling, begin to troubleshoot excessive aeration ' in our geovis system. Pull up hole to circulate while troubleshooting and ;experience excessive overpulls at -7900' ctmd. Pull to surface to treat our geovis 'system. RIH pumping at 1.5 bpm to roll hole over.. At 6500', begin seeing ;;excessive down weights at -4 to -5k. Continue to RIH to 7000'. At 6970', continue 'encountering excess down weights. POOH pumping to surface to clean wellbore. '.Problems encountered keeping gel to CT pump and swap to 1 %KCL. When KCI reached bit, encounter a stall at 1100' due to suspected solids falling. Finish chasing out of hole. Makeup BHA #8: 2.5" JSN with Andergauge AG-Itator. RIH and begin washing tubing at 6300'. '`'`'`**Job continued on WSR 07/09/08'`'`*""` 7/9/2008:CTU #5 w/1.75" CT. Mill Cement.'""' Continued from WSR 07/08/08 *'`* < 'InterACT publsishing > Start depth at 7985'. Continue jetting at 1.5 bpm and 2.5" :.JSN. Wash to 7800', then long trip to surface. Up weight at 7800' was 32k. Trip '.''to surface pumping recirculated Geovis. At surface, good cement returns seen at 'return tank. RIH pumping 1 bpm to evaluate hole cleaning. Down weights back to ;normal and up weights lower by 6k. Drift tubing to 7806'. POOH keeping hole 'loaded. *" Job in progress *** CTU #5 w/ 1.75" CT Milling cement .Talked with mud engineer about Geo vis and it`s at 123 k Isrv PH is at 9.The top of the mud is real thick the engineer said to circulate an dit will thin out. Milled from 7988' to 7998' Motor stall tried PUH unable to move pipe. Tried increasing wellhead pressure to surge well found that we were' able to inject at 1.1 BPM @ 1035 psi. Circ several hole volume of geo vis then swapped well over to XS KCL so we could increase pump rates. Still unable to get free ******" Job In Progress **'**** A • 7/10/2008.CTU #5 w/1.75" CT Milling Cement Continued from 7/9/08 Still working pipe tryinc~ `to get free. Collect sample from MI screens it appears to be formation sand and what looks like LCM. Free point pipe and it shows to be stuck at 3260'. Came free `'`,pumping slick low torque pi own 2.4 pm .Became stuck again @ 7870' ;,jars are working jars hit 13 times come online w /pump @ 1.4 bpm had a pressure :drop in circ press and pulled free again. POOH slow Swab check last 100' OOH . ;,.All tools are recovered. Repair weight indicator blader.Ml van is cleaned up and ready to go. Cut 100' of coil. MU 2.20" JSN BHA RIH set down at 7811' able to ''bring on pump down coil to get passed. Set down again at 7890' unable to get ',passed POOH. Breakdown toolstring. "` "" `Job in 7/11/2008''CTU #5 w/1.75" CT Milling Cement Continued from 7/10/08 Slowdown coil RDMO "'. Road to shop to PU new reel of coil. *'`****'`** Job Complete **"""**'` FLUIDS PUMPED BBLS 290 XS KCL 15 METH 105 1 % XS KCI 64 1 %KCL 440 GEOVIS 914 Total 02/28/08 ~chlamber~er NO. 4612 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Aurora,GNI,Pt.Mac,Milne Pt,Endicott Well -Inh # 1 nn rlecrrintinn Hate RI (:nlnr r`n 15-25A 12014000 LDL / -~6 'F- 02/20/08 1 1 A-12A 11963077 MCNL zt 3 01/19/08 1 1 GNI-04 12031448 TEMP SURVEY (REVISED) a(j~- ~ (0 01/22/08 1 1 P2-32 11968730 USIT _ ~ 02/13/08 1 1 17-02 11996384 USIT (~Q - ~' 02/17/08 1 1 Y-07A 11962781 SCMT "}-1 ~ " 'R 02/03/08 1 1 P2-58 12031456 USIT /~jQ - ~/ 02/25/08 1 1 MPH-12 12005205 MEM INJ PROFILE +~ _ j~ It '3 02/15/08 1 1 4-14/R-34 11975755 USIT V e ~ 02/25/08 1 1 S-126 11968731 JEWELRYIPERFISBHP '~- ~ ~ 02/15/08 1 1 YLtNJt HIiRNVVVLtU(7t KtI:tIY 1 tST JIIiNINCi ANU Kt I UKNINt9 VNt I:UYY tAI:H 1 V: BP Exploration (Alaska) Inc. ~~>Ritl~~A1iL6°a ~AD ~ "~ ~f1~4 Petrotechnical Data Center LR2-1 6'~tiZ118" tl U U 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: {~~ /~7 t°I ,A ''~'f1t1~i Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: • • 02/04/08 Schl~mb~~ger NO. 4572 Alaska Data 8 Consulting Services Company:. State of Alaska 2525 Gambell Street, Suite 400 3rC~4~lr+i~.¢ FCl~ ~ ~ ~{1pt~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Gt7 17tJ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt, Polaris,Lisburne ~Ar..u In6 a! 1 nn rlnc rin4inn n~4n RI Cninr cn LGI-04 11970706 SBHP SURVEY - j 6` " '~ 01/01/08 1 MPH-12 11978435 MEM DDL 01/31/08 W-216 12031441 USIT (~}- 01/11/08 1 W-214 11855826 CH EDIT PDC GR (USIT) (, 11/19/07 1 GNI-04 11846828 CH EDIT PDC GR (USIT) 11/11/07 1 15-366 11216209 MCNL (0 08/05/06 1 1 H-24A 11767145 MCNL -a- 15 9~C 11129/07 1 1 C-04B 11216198 MCNL ~ - (~''-j ~ I 3 06/02/06 1 1 L3-11 11962776 MCNL ~ ~ q 12/12/07 1 1 YLtAJt A6:RNUWLtUIit Ktl:t1Y I !SY JIIa NINIi ANU Kt t UKNINV VNt I.VYY tHI:K I V: BP Exploration (Alaska) Inc. „~,~, ` Petrotechnical Data Center LR2-1 ~` ,~ a ,. 900 E. Benson Blvd. ~ ~' '`'` Anchorage, Alaska 99508 ss Date Delivered: ~ ~^i:_~ {~ ~ ~~j~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ • ~~ ~~ ~~ STATE OF ALASKA ~ a-i~~~' ~ 200$ ALASKA OIL AND GAS CONSERVATION COMM SIGN REPORT OF SUNDRY WELL OPERATION • & ~~,~ C~fts i~ommissiaty 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~~P~a~~ Performed: Alter Casing ~ Pull Tubing (~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 197-1700 ' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22807-00-00 7. KB Elevation (ft): 9. Well Name and Number: 65.9 KB MPH-12 8. Property Designation: 10. Field/Pool(s): - ADLO-025518 Milne Point Field/ Schrader Bluff Pool 11. Present Well Condition Summary: Total Depth measured 8365 ' feet Plugs (measured) None true vertical 4456.12 ' feet Junk (measured) None Effective Depth measured 8299 feet true vertical 4273 feet Casing Length Size MD TVD Burst Collapse Surface 82' 20" 91.1# H-40 Surface - 112' Surface - 112' 1530 520 Production 8312' 7" 26# L-80 Surface - 8342' Surface - 4438' 7240 5410 ~~~ ~~~~~ FEB ~. ~ 2008 Perforation depth: Measured depth: 7898 - 7923 8072 - 8092 8092 - 8112 = _ True Vertica{ depth: 4096.19 - 4115.18 4229 - 4244 4244 - 4260 Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 28 - 7864 0 0 - Packers and SSSV (type and measured depth) 7" PLS MECH PAKER 7836 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: 161 1225 Subsequent to operation: 1787 1118 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. f 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 Prebl Title Data Management Engineer Signature Phone 564-4944 Date 2/7/2008 Form 10-404 Revise 4/2006 ~~~, ~~~ ~ ~ 1Q()~ ~~ ~ Submit Original Only • • MPH-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY ~ 1/30/2008':""CTU #8 Job Scope: FC©/ADD PERFS*** «InterAct not publishing» MIRU RIH w/ 2" JSN Dry tag fill @ 7923' CTM Cleaned down to 8065' CTM started 'having problems with weight in tubing puled 32k, 14k over through tubing, this -:had been going sense start of job and was getting worse each recip, pack offs were also having problems holding. POOH washing tubing ...Continue job on 1 /31 !2008... 1 /31 /2008 ~_ `*'CTU #8 Continue job from 1/30/2008*'`* «InterAct publishing intermittently»Job Scope Fill Clean Out/CT Flag/Add Perf Perform FCO down to 8210' CTM with each recip CT weights increased till 38k called TD @ 8012' CTM, 98' of rat below planned perforation interval of 8072'-8112' Run Memory Gama/CCL Log from 8100'-7000' RIH w/ 2" x 20' PJ Omega HMX 6 SPF 60 deg. tie in at CT flag and shoot Perf interval 8092'-8112' Confirmed all shots fired. Call APE, discuss depth correlation on tie-in adjust correction to +14' RIH w. 2nd 2"x20' PJ Omega HMX 6 SPF 60 deg. tie in at CT flag and shoot perf interval 8072'-8092' ...Continue job on 2/1/2008... ***CTU #8 Continue job from 1/31/2008**'` «InterAct Publishing» Launch 1/2" ball and fire guns at corrected top shot 8072'-8092' While tripping to surface UTIM picked up bad spots in CT @ 5942' & 4144' with an averaged wall loss of 30%-34% string is below recommended working parameters. (Running footage 519k/405k in chrome) POOH @ surface with all shoots fired. Blow down CT w. N2 and take to yard for pipe change ***Job complete*** FLUIDS PUMPED BBLS 32 XS 1 % KCL 48 60/40 METH 80 TOTAL . . State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg Keg:, '(if? 111'1 ( 01 P.I. Supervisor { , DATE: Tuesday, July 17,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC H-12 MILNE PT UNIT SB H-12 FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Src: Inspector t q 1- \ 70 Well Name: MILNE PT UNIT SB H-12 API Well Number: 50-029-22807-00-00 Inspector Name: John Crisp Insp Num: mitJCr070701164404 Permit Number: 197-170-0 Inspection Date 6/27/2007 Rei Insp Num: MITOPOOOOO 1796 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I ., IType Inj. i w I TVD I H-12 4049 IA 20 2010 1970 1960 I i 1- P.T.DI 1971700 ITypeTest I SPT I Test psi 1500 ! OA . I ' I Interval Four Year Cycle P/F Pass ;/' Tubing 820 830 830 830 i ... Notes: Monobore injector. 3 bbl's pumped for test. ./ SCANNED JUL 2 0 2007 Tuesday, July 17,2007 Page 1 of 1 . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleclænstein@ad.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP ACT I Milne Point I H-Pad 06127107 Lee Hulme John Crisp ,q7-/76 Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIMPH-12 I Type Inj. I W TVD I 4,049' Tubing 825 830 830 830 IntelVall 4 P.T.D.11971700 I Typetest I P Test psil 1500 Casing 20 2,010 1.970 1,960 P/FI P Notes: 3.0 diesel to 2010 psi. Bled back to 200 psi. OA NA NA NA NA Weill I Type Inj. I I TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD Tubing IntelVall P.T.D.I I Type test I Test psi Casing I P/F Notes: I OA I Weill I Type Inj.1 TVD I I Tubing I I Interval I PTD.I Type test Test psi I Casing I I I p/FI Notes: I OA Weill I Type Inj. I TVD Tubing I IntelVall P.T.D.I I Type test Test psil Casingl I I P/F Notes: OA I t TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1!05 TYPE TEST Codes M = AnnuIusMonilDring P = Standard PressuIe Test R = 1nIemaI RactioacINe T_ Stmey A = Tempe<alure Anomaly SunIey 0= DiIferenIìaI Ternperàft Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Worlrover 0= Other (describe in notes) iC'AN-tiiD jUN 2 9 2007 MIT MPU H 6-26-07-1 Jds STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon[--] SuspendE~] Operation ShutdownE~] Perforate[~ Variancerl Annular Disposalrl Alter CasinQ[-1 Repair Well[-'1 Plu¢l Perforations[~] Stimulate[~ Time ExtensionE~] Other[~] Change Approved Programr-] Pull mubingE~ Perforate New Poolr"l Re-enter Suspended Wellr'l Inj Conversion 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development r~ Exploratory[~ 197-1700 i 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic~-I Servicer'-] 50-029-22807-00-00 ,,_ 7. KB Elevation (ft): 9. Well Name and Number: 65.9 MPH-12 8. Property Designation: 10. Field/Pool(s): ADL-025518 Milne Point I Schrader Bluff 11. Present Well Condition Summary: Total Depth measured 8365 feet true vertical 4456.1 feet Plugs (measured) Effective Depth measured 8299 feet Junk (measured) true vertical 4272.8 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 82' 20" 91.1# H-40 112' 112' 1530 psi 520 psi Intermediate Production 8312' 7" 26# L-80 8342' 4438' 7240 psi 5410 psi Liner Perforation depth: Measured depth: 7898' - 7923' True vertical depth: 4096.19'- 4115.18' JUL ...... Tubing: ( size, grade, and measured depth) 3.5" 9.3# L-80 7864' · ,. Packers & SSSV (type & measured depth) 7" PLS Mech Set Packer 7836' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casin~! Pressure Tubin~ Pressure Prior to well operation: 255 72 0 Subsequent to operation: 761 14. Attachments: 15. Well Class after proposed work: Exploratoryr'l Developmentr'l Service[~] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown Oil["-~ Gasr~ WAGF1 GINJF'] WlNJr~ WDSPL[-] Daily Report of Well Operations _ X 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 I 303-059 Printed Name "~ ~.~ ~' -E~,;,~ ~$6. ~'J Title Signature ~ C~5,. I~ ,, .............., Phor~'e ' ,~(,c.i- ,.~'"L,,.~' Date 7/29/03 ~llllk IIiI~IL I A I i I · · ~' 0 v 2003 CANNE MPH-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 5/15/2002 Prep for Conversion: Pull jet pump. 2/28/2003 Prep for Conversion: Change out GLV's; Pressure Test IA to 800 psi. EVENT SUMMARY 4/14/2003 Pressure test IA to 3500 psi, passed. Drift to tag TD at 7922' RKB. 4/28/2003 Pressure test IA to 2500 psi, passed. 5/15/2003 Freeze protect well with 20 bbls MeOH down tubing. 5/20/2003 Injection Profile Log with warmback passes. 6/23/2003 Pressure test surface flowlines to 3650 psi, passed. FLUIDS PUMPED BBLS 20 Methonal 2O TOTAL Page 1 MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission >/~')/)~.~ DATE: June 29, 2003 SUBJECT: Mechanical Integrity Test BPX MPU H Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. we,I H-~ I~,~i.I s I ~.,,.~. 14~ I~,~1 ~o {~o I~o {~o I,nt~v~,l P.T.D.I 197-170 ITypetestl P {Testpsi[ 1031 I Casingl 1100 I 2525 I 2500.1 2500I P/F I Notes: Converted producer to injector . vv~,l I~ '~-I I ~-".~. I I ~u~,n~ I I I I I'~'~rw'l P.T.D. I IType testl ' ITestpsil I Casing I "I I I IR/FI Notes: P.T.D.I Notes: P.T.D.I Notes: P.T.D.I Notes: Type testI I Test psi[ I Casing I 'l I I . I ',, P/F 'l I IType Inj. Type test Type Inj. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU H Pad and witnessed the initial MIT on well H-12. This well was recently convened fi"om producer to injector. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Number of Failures: O Attachments: Total Time during tests: 1 hour CC: MIT report form 5/12/00 L.G. 2003-0629_M IT_MP U_H- 12_cs.xls 7/11/2003 OPERATOR: PERMIT NUMBER & WELL NUMBER PTD: 85-43 Well #: B-11i COMMENTS: PTD: 197-170-0 Well #: H-12i COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: PTD: Well #: COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Torn_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us BPX(A) FIELD / UNIT I PAD: Milne Point Unit/Various DATE: 6/29/03 ~.J I TEST J FLUIDI TYP'I 4 year comphance TYPE ANN. FLUID Diesel Brine PACKER TVD MD 6909' CASING SIZE ! WT i GRADE 7"26# L-80 8111' teshng Injoct~g at834 bwpd ~ 2580psi I I REQ TBG TEST I SIZE 1PRESS. 13.51~'727 PRETEST TBG CSG PRESS 2600 625 START TIME TBG CSG PRESS 2600 2.0~0 15 MIN TIME TBG CSG PRESS 30 MIN TIME TBG CSG PRESS 2600 2600 1.930 1.920 START TIME 8 30 Brine 7836' 7" 26# L-80 2-3/8" f, 100 2.525 2.500 2,500 Init-,_'al,,L~.v.,~.r'.~.'~";' converted produce to injocto: casing integrity test. Iniectino, . .. at 1426 bwpd ¢~ 1229 psi. i. I bbls diesel Bled back to 500psi 9 40 Diesel I I I D':-oscI ~-rin~. I I I II Dicsel I I I I II TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING P = PRODUCED WATER INJ. Distribution: c - Operator c - Database c - Trip Rpt File c - Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL PAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 7.5 0.39 9.5 0.49 WELL TEST: Initial 4 - Year 4 Workover Other OPERATOR REP SIGNATURE: Lee Hulme , AOGCC REP SIGNATURE: Chuck Scheve MIT MPI I [4;]?i yl_~ 7/4 c~/~f3nq Re: FW: MPH-12i IPROF (Coolback) Subject: Re: FW: MPH-12i IPROF (Coolback) l Q7 ~ l '/a Date: Tue, 24 Jun 2003 15:51:53 -0800 From: Winton Aubert <Winton_Aubert~admin.state.ak.us> Organization: AOGCC To: "Schnorr, DeWayne R (GeoQuest)" <SchnorDR~BP.com> Sean, AOGCC hereby approves injection operations in MPH-12i. apply. Winton Aubert AOGCC 793-1231 All permit stipulations "Schnorr, DeWayne R (GeoQuest)" wrote: This is what I got from Sean. From what he says, the temperature cool backs indicate that there is no water being injected above the packer. He requesting if it is all right now to start water injection into this well. DeWayne > ..... Original Message ..... > From: Petersen, Sean D > sent: Monday, June 16, 2003 11:53 AM > To: Winton Aubert (E-mail) > Cc: Townsend, Monte A; Schnorr, DeWayne R (GeoQuest); MPU, Well Operations Supervisor > Subject: MPH-12i IPROF (Coolback) > > Winton, > > Below is a timeline to date for converting MPH-12 from a jet pump producer to an injector. > > 4/14/2003: TD tagged at 7922' FiD (1' of perforations covered, soft bottom noted) > > 4/20/2003 - 5/15/2002: Temporary injection at a rate of ~1000 bwpd, and then SI for an IPROF with coolback passes. > > 5/20/2003: IPROF with coolback passes was performed, with the initial pass representing an extended shut-in period. Coolback results show no flow above the packer at 7836' MD, and flow into the NB sands which are perforated from 7898' to 7923' MD. There may also be some injection into the NA sands -7850' MD, but the higher temperature may also be the packer and other associated jewelry. > > The permanent tie-in work is near completion, and we are seeking approval to begin injection. Please let me know if you need any more information, and reply to this e-mail for approval to begin injection. > > Thanks! > >Sean D. Petersen > ACT Petroleum Engineer > 907-564-5025 > WELL LOG TRANSMITTAL II- ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration[Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FILM BLUELINE Open Hole I I 1 MP H-12 5-2003 Res. Eval. CH I I 1 Mech. CH 1 Caliper Survey Signed · Print Name: Date · ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www. memorvlog, com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Randy Ruedrich Commissioner Jim Regg i~' P.I. Supervisor DATE: April 28, 2003 SUBJECT: Mechanical Integrity Test BPX MPU H Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I P.T.D.I 197-170 TypetestI P ITestpsil 1031 I Casingl 1850I 2500 I 2500I 2500I P/F Notes: Conversion Producer to Inje~or I P.T.D.I Notes: WellI ~ot~: , ~.I.B. ~ lyp~ test ~oto~: ~-~.~.1 ~ot~: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU H Pad and witnessed the initial MIT on well H-12. This well was recently converted from a producer to injector. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Number of Failures: 0 Attachments: Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. MIT MPU H Pad 4-28-03 CS.xls 5/7/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: / Abandon_ Suspend_ COVERSlON TO-- Alter casing _ Repair well _ WATER INJECTOR Change approved program _ Operational shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Vadance _ Perforate _ CONVERSION TO H20 INJ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2388' FNL, 4150' FEL, Sec. 34, T13N, R10E, UM At top of productive interval 4195' FNL, 3913' FEL, SEC 35, T13N, R10E, UM At effective depth 4296' FNL, 3677' FEL, Sec. 35, T13N, R10E, UM At total depth 4322' FNL, 3615' FEL, Sec 35 T13N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic _ Service_ (asp's 556495, 6010042) (asp's 562029, 6008279) (asp's 562265, 6008180) (asp's 562327, 6008155) 6. Datum elevation (DF or KB feet) RKB 65.9 feet 7. Unit or Property name Milne Point Unit 8. Well number MPH-12 9. Permit number / approval number 197-~ // 10. APl number 50-029-22807-00 ~ 11. Field / Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 8365 feet Plugs (measured) true vertical 4456 feet Effective depth: measured 8259 feet Junk (measured) true vertical 4373 feet Casing Length Size Cemented Conductor 112' 20" 250 sx AS 1 (Approx) ..... 450 sx PF 'E', 130 sx 'G', Production 8313' 7" ~873 sx PF 'E', 100 sx PF 'C' Measured Depth True vertical Depth 142' 142' 8342' 4438' Perforation depth: measured Open Perfs 7898' - 7923' true vertical Open Perfs 4096' - 4114' Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 TBG @ 7864' MD. Packers & SSSV (type & measured depth) RECEIVED Alaska 0JJ & ~JAS L;0]]$. OOi;li~jSSiOIi 7" x 3-1/2" PLS Mech Set Packer ~ 7836'. 'Jet Pump Completion' 3-1/2" Camco KBUGM with 1" GLM ~ 2231' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operati~ March, 2003 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service WATER INJECTOR Suspended__ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title: ACT Petroleum Engineer sean D, Petersen FOR COMMISSION USE ONLY Questions? Call Sean D. Petersen @ 564-5025. Date February 05, 2003 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity __ B~OP Test __ Location clearance __ ~ MechanicaJ In.tegfityT.est.~)~. . __ Subsequc~.t form required 10- ¢~0 q Approved by order of the Commission ' .... / /'~--~-~/'~'~ ~ Commissioner Date i ",~ j ~,~ ;~,~,~1%~ SUBMIT IN TRIPLICATE Form 1o-4o3Revoe/~5/ae.RBDHS BFL , C; L ' ' bp BP Exploration (Alaska) inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 12, 2003 Tom~nder Alask'a Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for MPH-12 Conversion from Jet Pump Producer to a Water Only Injector BP Exploration Alaska, Inc. proposes t.~9onvert well MPH-12 from a shut-in jet pump producer to an active water only injector to provide support to the surrounding wells in the Milne Point Unit: MPH-13A, MPH-14. currently an N~nd~y jet pump producer (CA and OB are wet) MPH-12 is that has been SI since ~ay 2.~;)2 due to high water cut and sand production. This well was used as ~h~or producing the N-Sands without screens and with and without stimulation/fracs. Although it was on production for a while, there were problems with the jet p.~,~ps wearing out, and shakeouts verified that the well was making 100% water. Recently MPH-13A was drilled as an N-Sand only lateral as a test for the S-Pad development. Although MPG-09i is also an N-Sand injector, MPH-12 was identified as a simple recompletion that will provide support from a more southern location, and possibly allow for an interference test in addition to increasing reserves. The recompletion plan is to pressure test the IA and tubing on MPH-12 to 3500 psi to verify that the sliding sleeve will hold pressure. Once mechanical integrity is verified, Milne Point's projects group will complete the surface tie-in work to convert MPH-12 from a jet pump producer to an injector. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5025, home 349-3098, or e-mail me at mailto:peterssd@bp.com Sincerely, SCANNED M/~R ~ ? 2003 Sean Petersen Milne Point Unit/Schrader Bluff Production Engineer Well MPH-12 Current Status: · SI & freeze protected since May 2002 Order of Operations: Category Step Description WL 1 Tag TD to verify all perforations open for injection f WL 2 Set plug in X-Nipple at 7852' MD (2.75" ID) WL 3 Verify HES XD SS at 7829' MD is closed Ops 4 MIT: Tubing and IA to 3500 psi to verify SSD closed ~'~ Projects 5 Complete surface tie-in work Tree: Cameron 2 9/16" 5M W~llhg~d: 11" 5M FMC gen 6 w/11"x 2-7/8" WKM tubing hanger, 2-7/8" 8rd EUE threads T&B, 2.5" ClW BPV profile. 20" 91.1 ppf, H-40 J 112' J v, PU H-12 Orig. KB Elev. = ~ (N 22E) Orig. GL Elev. = 37.0' RT To Tbg. Spool =30.29' (N 22E) KOP @ 300' Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. 3.5", 9.3#, L-80, NSCT tubing (ID =2.992", cap. = .0087 bpf) 7", 26# ppf, L-80, Mod. btrc. casing ( ddft ID =6.151", cap. = 0.0383 bpf ) 3.5" Camco KBUGM I 2231' w/1" pocket. Howco 7 .... ES" Cementer 2270' 'Reveme Circulation' Jet Pump Co~t~ Pm~luce~ Fluid "Jet Pump Completion" Reservoir Fluid Stimulation Sumrln~ry Perforation Summary Ref log: Sperry Sun DGR 09/20/97 Interval (TVD) 7898'-7923' 4096'-4114' 4.5" Alpha Jet charges @ 135/45 deg. phasing 3.5" HES XD Durasleeve I 7829' w/2.75" ID. "SO" safety shear out sub I 7" PLS mech set Packer I w/2.885" ID. I 3.5" X nipple w/2.75" ID. I 7833' 7836' 7852' 3.5" WLEG I 7864'1 Two 7"x20' marker joints from 7652' to 7692'. 7"landing collar (PBTD) I 8259' 7" float collar I ~2~' I 7", 26# L-S0 float shoe I 8342' I it I DATE REV. BY COMMENTS 9/22/97 JBF Drilled and Cased by 22-E 02/01/98 M.Linder Initial completion 4-ES 09/16/01 B. Hasebe Addition of Jet Pump flow schematic MILNE POINT UNIT WELL No: H-12 APl: 50-029-22807 I~~tr.O RATION (AK) Tree: Cameron 2 9/16" 5MU ~ ~ Orig. KB Elev. = 65.9' (N 22E) Wellhead: 11" 5M FMC gan 6 MPU ri-! ~-- Orig. GL Elev. = 37.0' !w/11"x 2-7/8" WKM tubing hanger, RT To Tbg. Spool =30.29' (N 22E) 2-7/8" 8rd EUE threads T&B, 2.5" CIW BPV profile. 20" 91.1 ppf, H-40 I 112' KOP @ 300' Max. hole angle = 74 to 77 deg. k Hole angle thru' perfs= 41 deg. ) w/1" pocket. 3.5", 9.3~, L-80, NSCT tubing ) Howco 7" "ES" Cementer (ID =2.992", cap. = .0087 bpf) 7", 26# ppf, L-80, Mod. btrc. casing ( ddft ID =6.151", cap. = 0.0383 bpf ) "Jet Pump Completion" I I I i,;' I w/2.75" ID. w/2.886" ID. Perforation Summa~ Ref Ioa: Sperry Sun DGR 09120197 ~-~ 3.5" WLEG I 7864' / Size SPF Interval (TVD) ~ ' Two 7"x20' marker joints from 4.5" 5 7898'-7923' 4096'-4114' 7652' to 7692'. 4.5" Alpha Jet charges @ 135/45 deg. phasing 7" landing collar (PBTD) - r,. 26#.- 0 fioatshoe [ 8 42' rm'r~ ~-v. e¥ CO~MEm'$ MIl. NE POINT UNIT 9/22/97 JBF Drilled and Cased by 22-E WELL No: H-12 02/01/98 M.Linder Initial completion 4-E$ APl: 50-029-22807 09/16/01 B. Hasebe Addition of Jet Pump flow schematic Tree; Cameron 2 9/16" 5MProposed MPU H-12iOrig. KB Elev. = 65.9' (N 22E) Wellhead: 11" 5M FMC gen 6 Orig. GL Elev. = 37.0' w/11"x 2-7/8" WKM tubing hanger, i RT To Tbg. Spool =30.29' (N 22E) 2-7/8" 8rd EUE threads T&B, 2.5" CIW BPV profile. 20" 91.1ppf, H'-40 J 112' J KOP @ 300' Max. hole angle = 74 to 77 deg. Hole angle thru' perfs = 41 deg. ~j 3.5" Camco KBUGM [ 2231' w/1" pocket. t I 3.5", 9.3#, L-80, NSCT tubing ~ ) Howco 7" "ES" Cementer I 2270' (ID =2.992", cap. = .0087 bpf) 7", 26~ ppf, L-80, Mod. btm. casing ( drift ID =6.151", cap. = 0.0383 bpf ) i i 3.5" HES XD Durasleeve [ 7829' J III I I "SO" safety shear out subL 7833' J ~ Xi 7" PLS mech set Packer wi 2.885" ID. [ 7836' J Stimulation Summary J I 3.5"X nipple wi 2.75" ID. [ 7852' J Perforation Summary / / Ref Ioq: Sperry Sun DGR 09120197 ~ 3.5" WLEG I 7864' j Size SPF Interval ('I'VD) ~ ~ Two 7"x20' marker joints from 4.5" 5 7898'-7923' 4096'-4114' 7652' to 7692'. ; 4.5" Alpha Jet charges @ 135/45 deg. phasing 7"landing collar (PBTD) [ 8259' 7" float collar [ 8299' J -- 7", 26# L-80 float shoe [ 8342' J DATE REV. BY COMMENTS MILNE POINT UNIT 9/22/97 JBF Drilled and Cased by 22-E WELL No: H-12 02/01/98 M.Linder Initial completion 4-ES APl: 50-029-22807 09/16/01 B. Hasebe Addition of Jet Pump flow schematic BP EXPLORATION (AK! SCANNED ~,~R r~ ? ?003 ~r~C.qANI CAi iNTEGRITY _-~ UD i'_'G RELEASE' - Casing: 7" Shoe: Liner: Shoe: . T'v-D TVD iNTEGRiTY Annulus Press Test: ; !5 mit ; 50 mit .~_~CHJ_NT_C)_L iNTEGRITY - PART ~2 Cement Volumes :' gxat. Liner c~= to: to cove= oe=.--~ Theoretical TOC Cement Bond Log (Xes or No) ~ ; In AOGCC File CBL Evaluation, zone above per~-s [), ~ b6~f~4 Production Log: Type Evaluation ' co~dnus:otqs: SCANNED ~AR n ?'2003 'i97~170_0 MD 08365 TVD 04456 C~6~Pletion Date?/ 1/26/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D L CCLrI'EMP/PRES tFdlqAL 7875 1/,2.¥/5g CH 2/1/98 2/3/98 L DGR/EWR4-MD 4ZI~NAL 4704-8365 OH 10/21/98 10/22/98 L DGPOEWR4-TVD ~,'16/1NAL 2920-4456 OH 10/21/98 10/22/98 L GR/CCL/PERF /,/F~AL 7850-8136 CH 5 2/1/98 2/3/98 R MWD SRVY ~RRY 0-8365. OH 3/2/99 3/2/99 Daily Well Ops ~/~///! 7-- ~ ~67/c{~ Was the well cored? yes l~_r Comments: Are Dry Ditch Samples Required? yes ~__.And Received? Analysis Description Rec~~ Thursday, February 03, 2000 Page 1 of 1 ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~] Oil I--] Gas [] Suspended I--I Abandoned E~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-0170 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22807 4. Location of well at surface .~,~ ,~ ,.._~- ....... 9. Unit or Lease Name ~-~ ~':~"; ~ Milne Point Unit 2891' NSL, 4150' WEE, SEC. 34, T13N, R10E, UM At to.p, of productive interval 10. Well Number 1085 NSL, 1367' EWL, SEC. 35, T13N, R10E, UM ~ I/~;'~')~,¢,..: MPH-12 At total depth ~:. -~/~/-',~"-'~-//c ~'.~'~ 11 Field and Pool 5. Elevation in feet (indicate KB, DF, etc.)16.Lease DS"§k~'na~ti('~;~nd Serial No. Milne Point Unit / Schrader Bluff KBE = 65.90' I ADL 025518 12. Date Spudded9/15/97 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Abandll 5' Water depth' if °fish°re I 16' N°' °f C°mpleti°ns9/20/97 1/26/98 N/A MSL! One 17. Total Depth (MD+-I-VD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 8365 4456 FTI 8259 4373 FTI [~ Yes E] No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 30' 8343' 8-1/2" 450 sx PF E, 130 sx G, 873 sx PF E, 100 sx PFC 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 7864~ 7836' MD TVD MD TVD 7898' - 7923' 4096' - 4115' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 80 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 9, 1998 * I Other (explain) - Jet Pump * Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-EEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD ! Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL O~L GRAvrrY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ Note - This well's Jet Pump completion was an experiment. It was produced from 03/09/98 - 03/17/98. Then again 04/17/98 - :)4/30/98, after which it was shut-in. It remains shut-in, but there are plans to hopefully produce it again in the future. This well was producing more sand than was hoped. (per R. Priest) Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SBF2-NA 7855' 4064' SBF1-NB 7894' 4093' SBE4-NC 7938' 4126' SBE2-NE 7962' 4145' SBE1 -NF 8028' 4195' TSBD-OA 8071' 4228' TSBB-OB 8151' 4289' SBA5 8188' 4318' 31. List of Attachments Summary of Daily Drilling Reports, Surveys Terfie Hubble Title Technical Assistant III Date - . , M PH-12 97-0170 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL'. This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for.each additional. interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ?? ?~ .... ~ i.~ i "~ ~ ~ Form 10-407 Rev. 07-01-80 Progress Report Facility M Pt H Pad Well MPH-12 Rig Nabors _._'~? ~ ~.,~' Page 1 Date 10 February 99 Date/Time 14 Sep 97 06:00-09:00 09:00-09:30 09:30-13:30 13:30-17:00 17:00-18:00 18:00-20:00 20:00-01:30 15 Sep 97 01:30-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-02:30 16 Sep 97 02:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-09:00 09:00-12:00 12:00-19:30 19:30-20:00 20:00-21:30 21:30-22:00 22:00-23:30 23:30-04:30 17 Sep 97 04:30-06:00 06:00-10:00 10:00-11:15 11:15-12:30 12:30-13:30 13:30-18:30 18:30-19:00 19:00-19:30 19:30-21:00 21:00-23:30 23:30-00:30 18 Sep 97 00:30-01:30 01:30-02:00 02:00-04:30 04:30-06:00 06:00-12:00 12:00-12:45 12:45-13:45 13:45-15:45 15:45-16:30 16:30-17:00 17:00-18:00 18:00-01:00 19 Sep 97 01:00-01:30 01:30-03:30 03:30-05:00 05:00-06:00 06:00-14:30 14:30-16:00 Duration 3 hr 1/2 hr 4 hr 3-1/2 hr lhr 2hr 5-1/2 hr lhr lhr 1/2 hr 2hr 1/2 hr 20 hr 1/2 hr lhr 1 hr lhr 3 hr 3hr 7-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 5 hr 1-1/2 hr 4hr 1-1/4 hr 1-1/4 hr 1 hr 5 hr 1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1 hr 1 hr 1/2 hr 2-1/2 hr 1-1/2 hr 6 hr 3/4 hr 1 hr 2hr 3/4 hr 1/2 hr 1 hr 7 hr 1/2 hr 2 hr 1-1/2 hr 1 hr 8-1/2 hr 1-1/2 hr Activity Rig moved 20.00 % Rig moved 20.00 % Rig moved 40.00 % Rig moved 80.00 % Rig moved 90.00 % Rig moved 100.00 % Rigged up Divertor Tested Divertor R.I.H. to 0.0 ft Held safety meeting Made up BHA no. 1 Made up BHA no. 1 Drilled to 2463.0 ft Circulated at 2463.0 ft Pulled out of hole to 900.0 ft Serviced Top drive R.I.H. to 2463.0 ft Drilled to 2831.0 ft Backreamed to 2372.0 ft Drilled to 3757.0 ft Circulated at 3757.0 ft Pulled out of hole to 900.0 ft Serviced Top drive R.I.H. to 3757.0 ft Drilled to 4707.0 ft Circulated at 4707.0 ft Pulled out of hole to 900.0 ft Pulled BHA Made up BHA no. 2 Serviced Top drive R.I.H. to 4707.0 ft Drilled to 4818.0 ft Pulled out of hole to 3954.0 ft R.I.H. to 4818.0 ft Circulated at 4818.0 ft Pulled out of hole to 900.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 4818.0 ft Drilled to 5100.0 ft Drilled to 5866.0 ft Circulated at 5866.0 ft Pulled out of hole to 5009.0 ft Backreamed to 4627.0 ft Circulated at 4627.0 ft R.I.H. to 5231.0 ft Reamed to 5866.0 ft Drilled to 6820.0 ft Circulated at 6820.0 ft Pulled out of hole to 4990.0 ft R.I.H. to 6820.0 ft Drilled to 6915.0 ft Drilled to 7772.0 ft Backreamed to 6820.0 ft Facility M Pt H Pad Progress Report Well MPH- 12 Page Rig Nabors ~ Z~;Ig Date 2 10 February 99 Date/Time 20 Sep 97 21 Sep 97 16:00-16:30 16:30-17:00 17:00-18:00 18:00-01:30 01:30-03:00 03:00-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-09:00 09:00-09:30 09:30-12:00 12:00-14:00 14:00-17:30 17:30-19:00 19:00-20:00 20:00-20:30 20:30-04:15 04:15-04:30 04:30-06:00 06:00-07:30 07:30-08:00 08:00-08:45 08:45-09:30 09:30-11:45 11:45-12:00 12:00-13:00 13:00-13:30 13:30-14:00 14:00-14:30 14:30-18:30 18:30-19:30 19:30-22:00 22:00-00:00 Duration 1/2 hr 1/2hr 1 hr 7-1/2 hr 1-1/2 hr 3 hr lhr 1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr 2hr 3-1/2 hr 1-1/2 hr 1 hr 1/2 hr 7-3/4 hr 1/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 3/4 hr 3/4 hr 2-1/4 hr 1/4 hr 1 hr 1/2 hr 1/2hr 1/2 hr 4 hr lhr 2-1/2 hr 2hr Activity Pulled out of hole to 5866.0 ft Serviced Top drive R.I.H. to 7773.0 ft Drilled to 8365.0 ft Circulated at 8365.0 ft Pulled out of hole to 2785.0 ft Pulled out of hole to 915.0 ft Pulled BHA Downloaded MWD tool Serviced Drillfloor ! Derrick Made up BHA no. 3 R.I.H. to 8365.0 ft Circulated at 8365.0 ft Pulled out of hole to 915.0 ft Pulled BHA Installed Casing handling equipment Held safety meeting Ran Casing to 8343.0 ft (7in OD) Installed Cement head Circulated at 8343.0 ft Circulated at 8343.0 ft Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 221.000 bbl Displaced slurry - 313.000 bbl Circulated at 2100.0 ft Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 354.000 bbl Displaced slurry - 81.000 bbl Cleared Bell nipple Rigged down Casing handling equipment Removed Divertor Installed Casing head Installed Adapter spool Cleared Trip tank Progress Report Facility M Pt H Pad Well MPH-12 Page 1 Rig ¢t~l~l~a~r~ q~'~ Date 10 February 99 Date/Time 21 Jan 98 22 Jan 98 23 Jan 98 24 Jan 98 25 Jan 98 26 Jan 98 18:00-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-14:30 14:30-23:30 23:30-02:30 02:30-06:00 06:00-06:30 06:30-13:00 13:00-18:30 18:30-19:30 19:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-14:30 14:30-19:30 19:30-20:30 20:30-21:30 21:30-23:00 23:00-23:30 23:30-06:00 06:00-06:30 06:30-09:00 09:00-12:30 12:30-14:30 14:30-16:30 16:30-20:30 20:30-01:00 O1:00-03:00 03:00-06:00 Duration 12hr 1/2 hr lhr 3hr 4hr 9 hr 3hr 3-1/2 hr 1/2 hr 6-1/2 hr 5-1/2 hr lhr 8hr 1-1/2 hr lhr 1/2 hr 2hr 3-1/2 hr 2-1/2 hr 5hr lhr lhr 1-1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 2-1/2 hr 3-1/2 hr 2 hr 2hr 4 hr 4-1/2 hr 2hr 3 hr Activity Rig moved 100.00 % Held safety meeting Rigged down Xmas tree Installed BOP stack Tested BOP stack R.I.H. to 2022.0 ft Drilled installed equipment - DV collar R.I.H. to 4500.0 ft Held safety meeting Singled in drill pipe to 8244.0 ft Reverse circulated at 8244.0 ft Tested Other sub-surface equipment - Via annulus and string Laid down 8244.0 ft of 3-1/2in OD drill pipe Rigged up Lubricator Conducted electric cable operations Held safety meeting Conducted electric cable operations Perforated from 7908.0 ft to 7923.0 ft Perforated from 7898.0 ft to 7908.0 ft Conducted electric cable operations Worked on BOP - Lubricator Ran Tubing to 2130.0 ft (3-1/2in'OD) Circulated at 2170.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing to 7000.0 ft (3-1/2in OD) Held safety meeting Ran Tubing to 7836.0 ft (3-1/2in OD) Set packer at 7835.0 ft with 0.0 psi Set packer at 7835.0 ft with 0.0 psi Rigged down BOP stack Installed Tubing on landing string Conducted slickline operations on Slickline equipment - Retrival run Freeze protect well - 80.000 bbl of Diesel Rig moved 10.00 % SPF-~¥-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPH-12 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE' 10/ 4/97 DATE OF SURVEY: 092097 MWD SURVEY ~' l rT~ JOB NUMBER: AK-MM-70274 KELLY BUSHING ELEV. = 65.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -65.90 112.00 112.00 46.10 201.07 201.07 135.17 291.07 291.06 225.16 382.54 382.47 316.57 0 0 0 0 0 7 1 6 2 42 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 7.94 W .15 .iON .01W S 84.60 E 1.27 .12N .84E S 74.84 E 1.77 .53S 3.80E .00 .00 -.05 .75 3.75 473.53 473.25 407.35 563.51 562.85 496.95 654.26 653.05 587.15 746.07 744.13 678.23 838.47 835.38 769.48 4 45 5 49 6 40 7 48 10 8 S 67.10 E 2.33 2.56S 9.35E S 65.04 E 1.21 5.94S 16.93E S 62.93 E .96 10.28S 25.80E S 62.81 E 1.24 15.56S 36.10E S 60.97 E 2.55 22.38S 48.80E 9.65 17.94 27.77 39.25 53.53 928.85 924.17 858.27 11 18 1021.79 1014.89 948.99 13 41 1113.40 1103.39 1037.49 16 8 1205.22 1190.88 1124.98 19 7 1297.08 1276.77 1210.87 22 25 S 64.65 E 1.49 30.04S 63.77E S 65.96 E 2.58 38.42S 82.05E S 65.29 E 2.69 48.16S 103.53E S 65.89 E 3.25 59.65S 128.87E S 72.77 E 4.45 70.99S 159.35E 70.23 90.28 113.80 141.55 174.07 1388.83 1360.53 1294.63 25 45 1480.50 1442.30 1376.40 27 57 1572.79 1523.19 1457.29 29 34 1664.59 1602.84 1536.94 30 3 1757.17 1682.06 1616.16 32 15 S 76.10 E 3.92 80.96S 195.42E S 76.59 E 2.41 90.73S 235.65E S 75.71 E 1.82 101.37S 278.76E S 75.09 E .62 112.88S 322.93E S 78.07 E 2.90 123.95S 369.52E 211.36 252.48 296.61 342.04 389.58 1847.74 1758.16 1692.26 33 24 1937.69 1832.09 1766.19 36 0 2028.13 1904.59 1838.69 37 25 2122.98 1979.74 1913.84 37 45 2214.12 2050.69 1984.79 39 58 S 75.90 E 1.82 135.02S 417.36E S 77.00 E 2.97 147.01S 467.15E S 78.23 E 1.76 158.59S 519.95E S 77.42 E .63 170.80S 576.51E S 76~33 E 2.54 183.79S 632.19E 438.29 489.16 542.71 599.99 656.73 2305.34 2118.41 2052.51 2398.01 2184.58 2118.68 2489.96 2247.77 2181.87 2583.65 2306.01 2240.11 2674.56 2355.68 2289.78 44 44 48 54 59 8 43 25 39 5 S 76.91 E 4.59 197.92S 691.62E S 78.19 E 1.16 211.90S 754.97E S 78.09 E 4.02 225.62S 820.32E S 77.77 E 6.65 240.97S 892.03E S 81.01 E 5.72 254.93S 966.84E 717.38 781.65 847.71 920.30 995.32 2766.96 2400.74 2334.84 2858.67 2440.23 2374.33 2950.96 2474.20 2408.30 3043.96 2502.23 2436.33 3137.51 2524.99 2459.09 62 31 66 26 70 20 74 33 77 17 S 82.90 E 4.11 266.19S 1046.70E S 82.10 E 4.36 277.00S 1128.74E S 80.64 E 4.47 289.89S 1213.55E S 78.94 E 4.85 305.62S 1300.80E S 76.71 E 3.72 324.76S 1389.48E 1074.14 1154.85 1238.88 1326.18 1416.01 ORIGINAL RECEIVED BPXA PDO SPF- nY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPH-12 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 MWD SURVEY JOB NI/MBER: AK-MM-70274 KELLY BUSHING ELEV. = 65.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3228.64 2548.29 2482. 3322.71 2575.27 2509. 3415.31 2599.13 2533. 3506.96 2620.71 2554. 3598.70 2643.01 2577. 39 73 4 S 76.68 E 4.63 345.03S 1475.20E 37 73 35 S 73.36 E 3.43 368.32S 1562.24E 23 76 32 S 72.64 E 3.26 394.48S 1647.79E 81 76 13 S 72.06 E .71 421.49S 1732.67E 11 75 38 S 72.71 E .93 448.42S 1817.48E 1503.44 1593.16 1682.48 1771.46 1860.35 3691.71 2666.33 2600. 3784.50 2690.22 2624. 3879.81 2715.15 2649. 3975.38 27'40.18 2674. 4071.74 2765.57 2699. 43 75 19 S 71.09 E 1.72 476.39S 1903.06E 32 74 50 S 71.18 E .53 505.38S 1987.90E 25 74 50 S 71.63 E .46 534.71S 2075.09E 28 74 47 S 71.10 E .54 564.19S 2162.49E 67 74 39 S 73.00 E 1.91 592.83S 2250.91E 1950.32 2039.95 2131.91 2224.10 2316.97 4165.48 2788.62 2722. 4260.57 2810.64 2744. 4356.54 2833.14 2767. 4446.06 2854.24 2788. 4542.21 2877.91 2812. 72 76 52 S 69.14 E 4.64 622.31S 2336.83E 74 76 20 S 66.67 E 2.59 657.10S 2422.52E 24 76 32 S 69.96 E 3.34 691.57S 2509.20E 34 76 11 S 69.03 E 1.08 722.04S 2590.68E 01 75 17 S 67.85 E 1.52 756.28S 2677.35E 2407.78 2500.22 2593.47 2680.47 2773.62 4640.24 2903.04 2837. 4739.63 2929.05 2863. 4835.30 2954.76 2888. 4932.14 2980.58 2914. 5025.56 3004.64 2938. 14 75 0 S 66.09 E 1.76 793.34S 2764.54E 15 74 40 S 71.21 E 4.98 828.26S 2853.85E 86 74 9 S 68.14 E 3.14 8~0.26S 2940.26E 68 74 54 S 68.59 E .89 894.67S 3027.01E 74 75 14 S 68.13 E .59 927.96S 3110.92E 2868.26 2964.13 3056.27 3149.58 3239.82 5120.62 3029.27 2963. 5216.66 3055.10 2989. 5312.34 3081.85 3015. 5407.97 3108.22 3042. 5503.56 3133.68 3067. 37 74 43 S 70.03 E 2.01 960.74S 3196.66E 20 74 4 S 70.05 E .67 992.31S 3283.61E 95 73 26 S 68.88 E 1.35 1024.53S 3369.63E 32 74 31 S 71.16 E 2.55 1055.93S 3456.00E 78 74 34 S 72.55 E 1.40 1084.62S 3543.55E 3331.61 3424.11 3515.97 3607.86 3699.93 5598.83 3159.07 3093. 5.694.40 3184.70 3118. 5785.78 3208.37 3142. 5883.20 3233.03 3167. 5978.47 3257.83 3191. 17 74 30 S 72.65 E .13 1112.08S 3631.17E 80 74 22 S 73.42 E .79 1138.95S 3719.23E 47 75 35 S 72.42 E 1.69 1164.87S 3803.59E 13 75 4 S 72.94 E .74 1192.93S 3893.56E 93 74 45 S 72.38 E .66 1220.34S 3981.37E 3791.64 3883.56 3971.68 4065.80 4157.67 6072.93 3282.79 3216. 6167.50 3308.14 3242. 6263.27 3332.86 3266. 6358.36 3355.79 3289. 6455.68 3378.83 3312. 89 74 35 S 71.01 E 1.41 1248.95S 4067.85E 24 74 18 S 70.67 E .46 1278.85S 4153.92E 96 75 45 S 68.89 E 2.35 1310.83S 4240.72E 89 76 20 S 68.14 E .98 1344.63S 4326.59E 93 76 16 S 68.24 E .12 1379.76S 4414.37E 4248.71 4339.80 4432.30 4524.57 4619.08 SPF-~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPH-12 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE- 10/ 4/97 DATE OF SURVEY: 092097 MWD SURVEY JOB NUMBER: AK-MM-70274 KELLY BUSHING ELEV. = 65.90 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 6552.04 3401.73 3335.83 76 13 S 67.27 E .98 1415.19S 4501.00E 6647.02 3424.73 3358.83 75 45 S 67.50 E .56 1450.63S 4586.07E 6742.22 3449.96 3384.06 73 30 S 67.96 E 2.41 1485.41S 4671.00E 6837.20 3479.23 3413.33 70 35 S 67.91 E 3.05 1519.35S 4754.73E 6931.09 3512.39 3446.49 68 1 S 68.36 E 2.77 1552.06S 4836.24E 4712.62 4804.70 4896.41 4986.72 5074.51 7026.72 3550.00 3484.10 65 39 S 68.96 E 2.55 1584.05S 4918.11E 7122.27 3591.47 3525.57 62 54 S 69.12 E 2.88 1614.84S 4998.49E 7217.76 3637.13 3571.23 59 57 S 69.26 E 3.09 1644.63S 5076.87E 7312.98 3687.71 3621.81 55 52 S 69.47 E 4.29 1673.06S 5152.34E 7407.88 3743.69 3677.79 51 49 S 70.61 E 4.38 1699.23S 5224.34E 5162.40 5248.46 5332.31 5412.96 5489.57 7501.82 3804.40 3738.50 47 37 S 71.51 E 4.52 1722.50S 5292.11E 7597.86 3871.54 3805.64 43 39 S 70.92 E 4.17 1744.60S 5357.11E 7693.97 3942.31 3876.41 41 29 S 68.91 E 2.66 1766.90S 5418.16E 7791.13 4015.24 3949.34 41 12 S 68.12 E .61 1790.41S 5477.89E 7885.61 4086.63 4020.73 40 38 S 68.36 E .63 1813.35S 5535.37E 5561.20 5629.83 5694.83 5759.00 5820.87 7981.02 4159.14 4093.24 40 25 S 68.48 E .24 1836.16S 5593.02E 8074.54 4230.60 4164.70 39 55 S 66.24 E 1.63 1859.37S 5648.70E 8170.87 4304.80 4238.90 39 18 S 67.29 E .95 1883.61S 5705.14E 8289.81 4397.25 4331.35 38 40 S 67.03 E .56 1912.65S 5774.11E 8365.00 4455.95 4390.05 38 40 S 67.03 E .00 1930.99S 5817.36E 5882.85 5943.12 6004.46 6079.22 6126.15 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6129.47 FEET AT SOUTH 71 DEG. 38 MIN. EAST AT MD = 8365 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 110.25 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,365.00' MD SP}- 'v-suN DRILLING SERVICES ... ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPH-12 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 JOB NUMBER: AK-MM-70274 KELLY BUSHING ELEV. = 65.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -65.90 .00 N .00 E 1000.00 993.72 927.82 36.32 S 77.34 E 2000.00 1882.24 1816.34 155.11 S 503.22 E 3000.00 2489.80 2423.90 297.81 S 1259.37 E 4000.00 2746.64 2680.74 571.88 S 2184.96 E .00 6.28 6.28 117.76 111.47 510.20 392.45 1253.36 743.16 5000.00 2998.13 2932.23 918.75 S 3087.98 E 6000.00 3263.49 3197.59 1226.63 S 4001.17 E 7000.00 3538.98 3473.08 1575.31 S 4895.39 E 8000.00 4173.59 4107.69 1840.67 S 5604.47 E 8365.00 4455.95 4390.05 1930.99 S 5817.36 E 2001.87 748.51 2736.51 734.64 3461.02 724.51 3826.41 365.39 3909.05 82.64 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPF' ~v-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPH-12 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE- 10/ 4/97 DATE OF SURVEY: 092097 JOB lVUMBER: AK-MM-70274 KELLY BUSHING ELEV. = 65.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -65.90 65.90 65.90 .00 165.90 165.90 100.00 265.90 265.90 200.00 365.95 365.90 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .02 N .00 W .00 .00 .17 N .35 E .00 .00 .32 S 3.05 E .05 .05 466.15 465.90 400.00 566.58 565.90 500.00 667.19 665.90 600.00 768.05 765.90 700.00 869.48 865.90 800.00 2.32 S 8.78 · 6.07 S 17.21 10.97 S 27.14 16.92 S 38.75 25.03 S 53.58 E .25 .20 E .68 .43 E 1.29 .61 E 2.15 .85 E 3.58 1.43 971.43 965.90 900.00 1074.39 1065.90 1000.00 1178.85 1165.90 1100.00 1285.35 1265.90 1200.00 1394.80 1365.90 1300.00 33.65 S 71.42 43.67 S 93.75 56.19 S 121.16 69.64 S 155.15 81.59 S 197.94 E 5.53 1.95 E 8.49 2.97 E 12.95 4.45 E 19.45 6.50 E 28.90 9.45 1507.22 1465.90 1400.00 1621.91 1565.90 1500.00 1738.11 1665.90 1600.00 1857.04 1765.90 1700.00 1979.48 1865.90 1800.00 93.63 S 247.83 107.38 S 302.28 121.81 S 359.65 136.27 S 422.35 152.53 S 491.09 E 41.32 12.42 E 56.01 14.70 E 72.21 16.20 E 91.14 18.93 'E 113.58 22.44 2105.47 1965.90 1900.00 2234.12 2065.90 2000.00 2371.72 2165.90 2100.00 2517.82 2265.90 2200.00 2694.73 2365.90 2300.00 168.46 S 566.04 186.85 S 644.82 208.11 S 736.86 230.01 S 841.01 257.57 S 984.02 E 139.57 25.99 E 168.22 28.65 E 205.82 37.59 E 251.92 46.10 E 328.83 76.91 2926.95 2465.90 2400.00 3289.71 2565.90 2500.00 3690.00 2665.90 2600.00 4073.03 2765.90 2700.00 4494.67 2865.90 2800.00 286.31 S 1191.32 359.60 S 1531.83 475.86 S 1901.49 593.21 S 2252.10 739.01 S 2634.71 E 461.05 132.23 E 723.81 262.76 E 1024.10 300.29 E 1307.13 283.03 E 1628.77 321.64 4876.13 2965.90 2900.00 5256.03 3065.90 3000.00 5624.41 3165.90 3100.00 6009.16 3265.90 3200.00 6401.17 3365.90 3300.00 874.88 S 2976.71 1005.23 S 3319.20 1119.43 S 3654.70 1229.31 S 4009.59 1360.12 S 4365.20 E 1910.23 281.46 E 2190.13 279.91 E 2458.51 268.38 E 2743.26 284.75 E 3035.27 292.01 SPF- 'v-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPH-i2 500292279600 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 JOB NUMBER: AK-MM-70274 KELLY BUSHING ELEV. = 65.90 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6795.71 3465.90 3400.00 1504.58 S 4718.32 E 3329.81 294.54 7064.47 3565.90 3500.00 1596.33 S 4950.07 E 3498.57 168.76 7273.18 3665.90 3600.00 1661.36 S 5121.18 E 3607.28 108.71 7443.18 3765.90 3700.00 1708.26 S 5250.24 E 3677.28 70.00 7590.01 3865.90 3800.00 1742.82 S 5351.95 E 3724.11 46.84 7725.47 3965.90 3900.00 1774.41 S 5437.63 E 3759.57 35.46 7858.30 4065.90 4000.00 1806.79 S 5518.83 E 3792.40 32.83 7989.89 4165.90 4100.00 1838.27 S 5598.38 E 3823.99 31.60 8120.57 4265.90 4200.00 1871.27 S 5675.74 E 3854.67 30.68 8249.66 4365.90 4300.00 1902.86 S 5751.01 E 3883.76 29.09 8365.00 4455.95 4390.05 1930.99 S 5817.36 E 3909.05 25.29 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D Ft I L-I--I N 13 SEFIVI Cl:: S To: WELL LOG TRANSMITI'AL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPH-12, AK-MM-70274 October 21, 1998 MPH-12: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22807-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22807-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ~ AII'ACHED COPIES OF TltE TRANSMITYAL LETTER TO THE AITENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date:ocT 22 1998 Alaska Oil & uaa Cons. Comm~on A~ctx~e BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 0 F:! I I--I-- I IM G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPH-12, AK-MM-70274 October 7, 1998 1 LDWG formatted Disc with verification listing. API#: 50-029-22807-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ~ ATTACHED COPIES OF THE TRANSMITTAL LETI'ER TO THE AITENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date:OCT 0,7 Alaska (jil ~ Gas Cons. ¢ornmi~on Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sign 5631 Silverado Way, Suite (3 · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 ,. a of Alaska Alaska Oil & Gas Conservation Comm. Atten' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 01-Feb-98 :Well Name iServices MPF-34 [SBT/GR MPH-09 !STATIC PRESSURE iPFC/PERF Bluelines R/F Sepia Film oj MPH-09 MPH-09 !GR/CCL 1 1 !MPH-12 PFC/PERF 1 I 0 i. ii ::;MPH-12 STATIC PRESSURE 1 1 0,~ !'MPH-09 STATIC PRESSURE 1 1 0 ii iMPH-09 GR/CCL PERF 1 I 01 MPH-09 GR/CCL SETTING SRVS 1 I 0!~ 't II ived Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September I 1. 1907 (?hip Alvord Senior Drilling Engineer BP Exploration (,Alaska) Inc. POBox 196612 Anchorage, ,AK 99519-6612 Milne Point Unit MPH-I 2 BP Exploration (Alaskat Inc. Permit No: 97-170 Sur. Loc.: 2891'NSL. 4150'WEL. Sec. 34. T13N. RIOE. UM Btmhole Loc: 969'NSL. 3599'WEL. Sec. 35. TI_~N. R10E. UM Dear Alvord' Enclosed is tile approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law t¥om other governmental agencies, and does not authorize conducting drilling operations until all other required permitting, determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice ~approximately 24 hours)of tile BOPE test perfbrmed betbre drilling below the surface casing shoe must be given so that a representative of the Commission may witness tile test. Notice max' be ~iven bv contactinz the Commission petroleum field inspector on the North David W. Johnston ~ Chairman -.. BY ORDER OF THE COMMISSION dlf enclosures cC: Department ol' Fish & Game. Habitat Section w,o encl. I)cpanmcnt t,[' Envmornment Conservation xwo encl. STATE OF ALASKA ALASKA '~L AND GAS CONSERVATION COMwilSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l~ Drill I--IRedrill lb. Typeofwell [-I Exploratory I--IStratigraphicTest I~ Development Oil [] Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE - 66.5' Milne Point Unit / Schrader Bluff 3. Address !6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 ~'~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2891' NSL, 4150' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1085' NSL, 3911' WEL, SEC. 35, T13N, R10E, UM MPH-12 At total depth 9. Approximate spud date Amount $200,000.00 969' NSL, 3599' WEL, SEC. 35, T13N, R10E, UM 09/12/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 380109, 969'I No Close Approach 2560 8371' MD / 4464' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 74.75 ° Maximum surface 1390 psig, At total depth (TVD) 4001' / 1790 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 8340' 31' 31' 8371' 4464' 790 sx PF 'E', 130 sx 'G', 100 sx PF 'C' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateRECEIVED Production Liner S EP 65 1997 Alaska 0ii & Gas Cons. Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diver[er Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord /~_...~'~. ~ Title Senior Drilling Engineer Date ,,9{%"/~? Commission Use Only Permit Number APl Number I App_.roval Da_te I See cover letter ~ ? ,, 0 1 ? 0 50- O ~ (:/- 2, 2. ~ 0'7 ~'-"//" ¢'"~ for other requirements Conditions of Approval: Samples Required []Yes I'~No Mud Log Required []Yes Hydrogen Sulfide Measures []Yes r~lNo Directional Survey Required []Yes [] No Required Working Pressure for DOPE ,[~2M; []3M; [] 5M; [] 10M; [] 15M Other: Original Signea 8y by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: J. E. Robertson IMP H-12 Well Plan Summary IType of Well (producer or injector): SCHRADER BLUFF PRODUCER 564-5159 ISurface Location: Target Location: Bottom Hole Location: 2891 FSL, 4150 FEL, S34 T13N R10E UM 1085 FSL, 3911 FEL, S35 T13N R10E UM 969 FSL, 3599 FEL, S35 T13N R10E UM I AFE Number: 1337094 I Rig: I Nabors22E I Estimated Start Date: I 12SEP 97 I I Operating days to complete: ]7.0 I MD: 1837 ' I I TVD: 14464' I I KBE: J Well Design: Schrader Bluff ProdUcer I66.5 Formation Markers: Formation Tops MD TVDSS KOP 300 300 Base of Permafrost 1884 1725 Top of Ugnu 7020 3467 Top M Sand 7549 3771 Top NA (Target) 7853 4001 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 7888 4O28 NCND 7928 4059 NE 7952 4077 NF 8013 4124 OA 8055 4156 OA4 8097 4188 OB 8137 4219 Top of Seabee 8171 4245 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 8371 4398 TD at 200' MD past base of Schrader Casing/Tubing Program' Hole ~ize "Csg~ Wt/Ft Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD MD/'rVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-Mod 8340' 31'/31' 8371' / 4464' Pipe Specifications: ! ! O.D. Wt/Ft Grade Conn. ID Area Tensile Max Pull Collapse Burst (bbl/ft) (kips) (80% TR) (psi) (psi) 20" 94# H-40 Weld 19.124" 0.3552 40.0 32.0 520 1530 7" 26# L-80 BTC-Mod 6.276" 0.0382 80.0 64.0 5410 7240 5" 19.5# G (Pr) 4-1/2" IF 4.276" 0.0178 436.1 348.9 8765 12163 5" 19.5# E (Pr) 4-1/2" IF 4.276" 0.0178 311.5 249.2 7041 8688 Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at ±4001' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1790 psi (8.62 ppg EMW), is 1390 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. Mudloggers are NOT required for this well. Mud Program: Spud Mud ISpecial design considerations J See "Drilling Hazards and Risks" section about dealing with the I possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: J LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A CompletionANorkover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300', S-shaped profile I Maximum Hole Angle: 174.75° Close Approach Well: NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on H-Pad have been permitted for annular injection. MP H-12 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test diverter system. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 8371' MD / 4464' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity from the top of the Ugnu to TD. NOTE: Shod trip no deeper than 300' MD past the base of permafrost. After the base of the permafrost, trips should be made every 1000'-1300' MD, or as hole conditions require. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost (2100' md). Displace STAGE1 cement with seawater at 8.0-10.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate 9.8 ppg mud a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad. Particularly close attention should be paid to hydrate experiences on previous H-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: HYDRATES HAVE BEEN ENCOUNTERED ON ALL THE RECENTLY DRILLED MILNE POINT 'H' PAD WELLS. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. WEIGHTING UP TO 9.8 PPG WITH A 2 POUND/BBL LECITHIN CONCENTRATION HAS PROVED SUCCESSFUL IN MANAGING THE HYDRATES. The cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP H-12. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on H-Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. Plan on using a 'C' cement for the second stage tail cement due to probability of hydrates. MP H-12 7" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL Weighted Spacer (Weighted to 1 ppg above TD mudweight). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 434 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 7049' MD TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 130 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (8371' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (7549' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 7049' MD SPACER: STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: 50 BBL Weighted Spacer (Weighted to 1 ppg above TD mudweight). TYPE 'E' PERMAFROST Retarder 12.0 ppg 356 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1525' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg 100 SACKS YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 575' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER AT 2100' MD. EST TOP 'C' 1525' MD WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-three (21) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (21+2 = 23 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. Anadril I Sc~l ul~be r~. er Alaska District 1211 ]last 80th AveRue ~chorage, A/( 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PhAN for S~ARHD SHRVICES DRILLING Well ......... : MPH-12(P3) WSeld ........ : MI[NH POINT, HPAD Confutation..: Minimum Curvature Units ........ : FEET Surface Lat,.: 70,43808530 N Surface Long.: 249.53935043 W Legal Description Surface ...... : 2891 PS[ 4150 P]lL TARG]lT ....... : 2085 PS[ ]911 P]lL B~L .......... : 969 PS[ ]599 P]lL Lf~CATXONS - ALASKA Zone: 4 X-Coord ¥-Coord S34 T13N RlO]l U]~ 556495.12 601004£.75 S35 T13N R10]l UM ~62030.00 6008280.00 S35 T13N RlO]l ~ 562343.53 6008167.03 PROPOSED ~HLL PROFIL]i STATION M}~iSUR~D INCLN IDEI~TIF£CATION DSPTH AlqGLB 0.00 0.00 L.50 3~00 5.00 KB 0.00 BUILD 1.5/300 300.00 400.00 BULL/) 2/100 500.00 600.00 D£RHCTION AZIMUTH 0.00 0.00 114.00 114.00 l£4,00 %qiRTICAL-D]iL>THS S]iCT/ON Tgq) SUB-g~A DEPART 0.00 -66.50 0,00 300.00 233.50 0.00 399.99 333.49 499.91 433.41 5.22 599.66 533,16 12.18 suxuo 2.5/]0o Prepared ..... : 03 Sep 1997 VeTt sect az.: 1~0.25 KB e]evation.: 66,50 ft Magnetic DcL~: +27.984 Scale Factor.: 0.99990363 Converge COORDINATHS-PROM WELhHHAD ~-·; +0._43406203 ANADRrLL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN · ALASKA Zone 4 TOOL DL/ X Y FA(.~ 100 O.00 N 0.00 E 556495.12 6OL0042.75 HS O.00 N 0.00 E 556495.12 6OL0041.7~ LI4R 0.00 0.53 S L.20 E 556496.32 6010041,23 LI4R 1.50 2.13 S 4.78 H 556499.92 60L0039.66 lI4R 1.50 4.97 S [1.]5 ~ 556506.31 6010036.85 114R 2-00 700.00 7-00 114.00 699.lL 632.61 22.61 9,22 S 20.70 800.00 9.50 114.00 798,06 731.56 36.93 15.05 S 33.81 900,00 12.00 114,00 896.30 829.80 55.54 22,64 S 50.85 L000.O0 14.50 i14,00 993,63 927.L3 78.41 32.96 S 71,79 [100.00 17.00 114.00 L089,8~ 1023.37 105.50 43,00 S 96.58 556515~89 6020032.69 H8 2.00 556529.04 6020026.95 HS 2.50 556546.13 6010019.50 RS 2.50 556567.14 6010010.34 NS ~-50 556592.0~ 6009999-49 HS 2.50 Z ~0 H -U 1200,00 19-50 134,00 Z284.83 1118.33 136.74 55,74 S 125,19 H 556620,7l 6009986.97 RS 2.50 CuR%r~ 2.5/100 1216.11 19.90 234,00 2200.00 1133.50 142-26 57.95 S L30.15 H 556625,69 6009984.80 325 2.50 (Anadrill [c) 97 MPH12P3 3.0C 2: 51 PM P) ~O MP~{-12 STAT ION DENT I FICAT [ON BUILD 2.5/L00 END 2.5/100 BU]hD BASE PEP.~IAFROST BUILD 3.5/100 3.5/lOO CURVE 3/loo PROPOSED WRL~ PROFELE MEASURED INC_LI~ DIRECTION DHPTH ANGLE AZIMUTH 130O.00 21.71 1400.00 23.92 [07.96 1500.00 26.[7 [05.43 1600.00 28.47 ~03.28 1700.00 ]0.80 101.42 VERT]CAL-DEPTHS SECT[ON T'VD SUB-SEA DEPART 1278.42 12/[.92 L71.92 1370.59 1304.09 210,68 146[.[9 1394.69 252,91 1550.03 1483.53 298.56 k636.94 [570.44 347.52 03 8ep [997 Page 2 COORDINATES-FROM ALASKA Zone 4 NELLHHAD X Y 69.31S 157.68 E 556653.31 60099~3.64 82.18 S 194.24 E 556689.95 600996~.05 94.31 S 234.78 E ~56730,59 60099~9.2~ 105.6~ S 279.25 ~ 5567~5,14 6009938.23 116.19 S 39~.55 E 556823.5/ 6009928.05 1800.00 33.30 101.42 1721.70 1655.20 399,95 126.70 ~ 379,56 1854.00 34-65 101.42 1766.48 ~699.98 429.77 132.68 S 409.13 1884.41 34.65 101,42 1791,50 1725.00 446-85 [36.10 S 426.O8 1914.00 34.65 101.42 1815.84 ]749.34 463.47 ]39,43 S 442.57 2000.00 37.66 10[.42 ~885,27 1818.77 513.60 149.48 S 492.29 2100,00 41.16 101.42 ~962.$3 1896.03 576.32 162.05 S 554-51 2200.00 44.66 10L.42 2035.76 1969.26 643.59 175.52 S 62[.23 2300,00 48.16 £01.42 2104.70 2038.20 715,~4 189.86 S 692.2~ 2400,00 51.66 L01.42 2169.L0 2102,60 790,73 205.01 S 767.19 2500.00 55.~6 101.42 2228.70 1162.20 870.05 220.91 $ 845.87 2600.00 58.66 £01.42 2283.29 2216.79 952.83 237.50 $ 927.98 2700.00 62.[6 101.42 2332.67 2266,17 1038.74 254,7~ $ 1013.20 2800.00 65.66 101,42 2376.64 2310.[4 1127.47 272.50 S 1101.22 2900.00 69.~6 101,42 2415.05 2348.55 12~8.69 290.78 S 1191,70 3000.00 72.66 101.42 2447.76 9381.26 [3[2.05 309.49 S ]284,3£ 3032.78 73.80 ~01.42 2457.22 2390.$2 []43-07 315.70 S 1115.08 E 3297.50 73.80 ~01.42 2531.05 2464.55 [594.27 366.04 S 1564.26 E 3300.00 73.80 101.50 2531,75 2465.25 1596.64 366.52 $ 1566.6~ E 3400.00 73.76 104.61 2559.68 2493.18 [691.90 388.22 S 1660.13 ~ 3500.00 73.77 107.75 2587,64 252[.14 [787.65 414.98 S 1752.33 H TOOL DL/ PACE 100 ~=== 29b 2.50 271 2.50 245 2.50 225 2.50 HS 2.50 556875.59 6009917.94 }iS 2.50 556905.21 6009912.19 I-IS 2.50 556922.18 6009900.90 I-IS ~.00 556938.69 6009905,69 HS O.00 556988.48 6009896.02 HS 3.50 55~050.79 6009883.93 HS 3.50 557117,60 6009870.95 ~S 3.50 557388.68 6009857.15 NS 3.50 557263.76 6009842.58 85 3.$0 557342-56 6009827.28 HS 3.50 5574~4.78 6009811.31 )ES 3.50 557510.12 6009794.7~ HS 3.50 557598.26 6009777.63 HS 3.50 557688.87 6009760.04 HS 3.50 557781.62 6009742.03 HS 3.50 557812,43 6009736.05 HS 3.50 558061,95 6009687.60 91R 0.0O S$8064.3~ 6009687.14 91R 3.00 558357.99 6009666.16 9OR 3.00 558250.37 6009640.10 89R 3.00 BUll_d) 3/100 3580.05 73.80 110.25 2610,O0 2543.50 1864.49 440.00 S 1825.00 ~ 550323.22 6009615.63 HS 3.00 3600.00 74.40 110.25 2615.46 2548.96 1883.68 446.64 S ~843.00 H 55834~.27 6009609.13 ~S 3,00 END 3/100 BUILD 36[l.57 74.7~ 110-25 2618,54 2552.04 1894.83 450.50 S ~853.49 H 558351.7~ 6009605.35 }IS 3.00 ......... IAoad.~il!..l~.).~.7...H~R~,.)~.gE,.~.Ak_~.~ ........................................................................................................................................................................................................... )'IPH- 12 { P3) 03 Sep 1997 Page 3 STAT[ON IDENTIFICATION DROP 4/100 TOP UCd~U TOP N S~ND ;ND 4/100 DRO~ I~/'TOP $CHRAD;R TARGET MHASURHD INCLN DEPTH ANGLE 6784.31 74.75 6800.00 74.12 6900.00 ?000.00 66.12 7020.15 65.32 PROPOSED WELL PROFILE DIRIICFION VHRTICAL-DEPTHS A~[~/FH TVD SUB-SEA = 310.25 3453.06 3386.56 110,25 3457.27 3390.~7 110.25 3487.96 3421-46 110.25 3525.21 3458.71 110.25 3533.50 3467.00 SECT[ON CX)O]LD]lqAT~S-~ROM AEugSKA Zone DEPART ~ELLH~AD X y 4955.86 1509.93 S 4725.30 E 561231.27 6008567.80 LS 497~,97 15~5.16 S 4739.48 H 561245.49 6008562.68 LS 5066,12 1548.10 S 4828.76 E 561335.00 6008530.49 LS 5158,90 1580.21 S 49£5.80 E 561422.28 6Q08498.98 5177,27 1~86.57 S 4933.03 E ~6~439.56 6008492.75 59 7100,00 62.12 ILD.25 3568.85 3502.35 5248.86 7200,00 58.12 1X0.25 3618.65 3552.15 5335-55 7300,00 54,12 ~[0.25 3674.39 3607,~9 541~.56 7400.00 50.12 LLO.25 3735.97 3669.2g ~497.47 7500.00 46.12 ~0.25 3802.51 3736.0£ ~57~.91 7549.60 44.14 L10.25 3837.50 3771.00 7600.00 42.12 L30.25 3874.28 3807.70 7653.07 40.00 ~2~.25 39£4.29 3847.79 7853.07 40.00 [10.25 406~.50 4001.00 7853.07 40.00 £10.25 4067.50 4001.00 ?oo~ ~./ FAC~ 1 O0 0.00 4.00 4 -00 4.00 4.00 1621,34 S 5000.20 ~ $61506,90 6008468.48 LS 4.00 1641.35 S 5082.53 H 56[588,45 6008439.10 LS 4-00 1670.08 S 5159.41 ~ 56~666.55 6008410.96 LS 4-00 1697.39 S 52~3.45 ~ 561740.77 6008384.22 LS ~.00 1723.[5 ~ 5303.29 H 561810.80 6008358,98 L~ 4,00 5607.06 5641.52 5676.38 5804.93 5804.93 1735.32 9 5336.26 H 563843.86 6008347.07 L,S 4.00 1747.24 ~ 5368,59 H 562876.28 6008335.39 L,S; 4.00 1759.31 S 5401.29 H 561909.07 6008323,58 ~ 4-00 [803.80 S 5521.90 H 562030.00 6008280.00 HS O.00 1803.80 ~ 5521,90 H 562030.00 6008280.00 HS O.00 ~ 7888.3/ 40.00 130,25 4094.50 4028.00 5827.59 2811.64 NC/ND 7928:78 40.00 230,25 4L25.50 4059.00 5853.60 1820.6~ NI~ 7952.28 40.00 2~0.25 4L43.~0 4077.00 5868,70 2825.87 NP 8013.63 40.00 210,25 4L90.50 4124.00 5908,14 1839.51 OA 8055.40 40-00 1~0,25 4222.60 4156.00 5934.99 1848.02 OA4 8097.k8 40.00 310.25 4254,50 4188.00 5961,84 1858.11 08 8L17.65 40.00 110,25 4285.50 4219.00 5987.86 1867.11 BASH SCHRADHR 8£7L.59 40.00 110.25 4311.50 4245.00 6009.67 1874.66 7" CASING POINT 837L.59 40.00 1~0.25 4464,71 4398.2l 6238.23 1919.16 TD 8371.59 40.00 ]10.25 4464.?L 4398.21 6138,23 1919.16 (Anadrill (c197 MPH]2P3 3.0C 2:5l PM P) 5543.16 R 562051.31 6008272.32 RS O.00 5567.56 E 562075.78 6008263.50 H$ O.00 5581.74 E 562089.99 6008258.38 HS 0.00 56L8-74 E 562L27.09 6008245.02 NS 0.00 5643.93 E 562152.35 6008235.92 H8 0.00 5669.L2 g 562LTT.6L 6008226.81 HS 0-00 5693.52 g 562202.08 60082L8.00 HS 0.00 5713.99 g 562222.60 60062L0.60 HS 0.00 ~834.60 E 562343,53 6008L67.03 0.00 5834.60 E 562343,53 600BL6T~0~ 0.00 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION ............ ,~_ _,~...~...,.. _..LL.~..$.,,~,_ ........................... "O ITl i iim IIiii I I I~I~I~ III 'SHARED SERVI ES DRILLING /" I I ! I I NPH-~2 (P3) VERTICAL SECTION imll ii i i i Section at: VIEW 1~0 25 - A lANAI,RiLL , ..... .f._~ .~_ _...iTVU.SCa~e.:''-~l'~nch = 800 feet ~'KA'DI'Cl IDep Scale,', ! inch = 800 feet __ .-- Ff;ASI_i~ILI'1'Y PI.AN · c-- NC,T A ~PRC)VEC FOFt ,,r ... EX ~cu'rlOhl ~ N~PkeP ,de,L,ficaL,o~ ~ 8K" SECTN [NCLI ~Lalq ¢ ~¢ t ~, ~, o o o o.o [ B) BUILD ].5/100 300 300 0 0.0 .................... ~ - C) BUILD 2/100 500 500 5 3.0 D] BUILD 2,5/}00 700 699 23 7.0 E) CURVE 2,5/~00 ~216 ~0 )42 ~9.9 Fl BUILD 2,5/J00 ~700 ~7 348 30.8 G) END 2.5/~00 BUlLO H854 ~766 430 34.6 H) ~ILD 3.5/)00 ~9t4 ~Bi6 463 34.6 :~-- ....... ~r.~K-{~ l) ENO 3.5/100 BUILD 3033 2457 t343 73.8 .% J) CURVE 3/1DO 3297 2531 ~594 73.8 ~= % KI BUILD 3/100 3580 26t0 ~864 73.8 L) E~ 3/JO0 BUILD 36~ ~Bt9 1895 74.7 M) D~P 4/]00 6784 3453 4956 t NJ E~ 4/~00 DROP 7653 3914 ~76 40.~ ~ D} lARGE1 7853 4057 5B05 40.( ~ P) 7' CASING POINT B37~ 44~ 6138 40.( O} TD 8372 44~ 6{38 40.( , ........... ~,,~- -** - .....~- .............. ~ m m m I m W mm m~mmmm{ ~ - ~- ........ ) .................. ~ ........................... I (/¢a6-~]! (¢)9'/ I~HI;~P'J 3,06 Z:§t Pit P) 0 400 BO0 1P00 1600 2000 2400 ~HO0 3gO0 3bUO 40UU 44UU quou ~Ju DbgU t~UUO b,~UU Ut~UU Sec t i on De?'tupe Ill I I III z G'~ ITl i __ SHARED SERVTCES BRILLTNG ND BKB SECTN INCLN 7653 39~4 5676 40.00 7B53 4067 5805 40.00 8372 4485 6t38 40.00 8372 4465 6138 40.00 Narker IdenLificat~on A) END 4/100 DROP B) TAR6ET CJ 7" CASING POINT D) TD i · - --i MPH-12 (P3) VERTICAL SECTION VIEW I II II Section at' 110.25 TVD Scale ' 1 inch - lO0 feet PAGE 86 Dep Scale · ~ inch -- 100 feet Drawn ..... : 03 Sep ~997 i0- ='?u~'~ s~' = ~e~ ,. Anad/'i ] ~ch]umb~ger m m mm mm mmm .. ...... . .... , ,. m m FEASt~!I.~Ty PLAN I[XEC I. JTI()N i ~/~- ~ ~ ¢ ' 'm ~- ~g - _ _ : m ) X . : i~ , .... ' 5600 5650 5700 5750 5800 5850 5go0 5950 6000 6050 6100 6:150 6200 6250 , E300 Section Departure ~ {.4nadP.i]] (¢]97 NPH,i2P3 3.OC 3:15 PN P) ~ Anadri] ] S£h]u~be£ge£ MPH-12 (P3) PLAN VIEN CLOSURE .... ' 6~42 feel ~L Azimuth ]08.2~ DECLINATION' ~27,984 (E) SCALE · t inch = 800 feet E]RAWNi ' 03 Sep ]997 SHARED SER ' 0ES Map&er Identif icetion NO N/S E/W A) KB 0 0 N 0 E B) BUILD 1.5/100 300 0 N 0 E C) BUILD 2/100 500 2 S 5 E D) BUILD 2.5/100 700 9 S 21 E E) CURVE 2.5/t00 !2t6 58 S !30 E F) BUILD 2.5/100 1700 116 S 328 E G) END 2.5/100 BUILD 1854 133 S 409 E H) BUILD 3.5/100 1914 139 S 443 E I) END 3.5/100 BUILD 3033 316 S ]315 E J) CURVE 3/i00 3297 366 S 1564 E K) BUILD 3/100 3580 440 S 1825 E L) EN4] 3/100 BUILD 3612 45i S 1853 E N) DROP 4/100 6784 15t0 S 4725 E N] END 4/i00 DROP 7653 i759 S 540i E O{ TARGET 7853 iD04 S 5522 E P) 7' CASING POINT 8372 i919 S 5835 E Il) TD 8372 i9i9 S 5835 E DRILLTNG ANADR'LL AKA-DPC F'EASI.r LIT . PLAN NOT APPROVED FOR EXECUTION ........ { -- %~~ ,,, ................ , ............ m ....... I ......................................... r ................................ ! .................................................. ,!.m! ............................................................................................... I 400 0 400 BOO 1200 1600 2000 24U0 L-q:lO0 32DU JbUg 4UUO 44U0 4UUU b2UO ObUU bUUU b4gO hUgO <- WESI' EAST -> _ i i i i i (~n~ri)l (c)97 14p1-11~3 3.0C 3:i6 PN PI z u i H12G090 DATE INVOICE / CREDIT MEMO THE ATTACHED CHECK IS IN PAYMENT FOR ri'EMS DESCRIBED ABOVE. DESCRIPTION ~ ~-~h u c a.,Tm 0 or GROSS 1©0. O0 i 00. O0 7 DATE O~ / Ot~.,~ / 9 7 oo ! ;2.~o901 VENDOR DISCOUNT ALASKAST 14 O0 i00.0 100. O0 / · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ~ ;~'~ / ~ (} INIT CLASS ~) ~..,~ WELL NAME ~'~ !0 ["~ - I ~ PROGRAM: exp [] dev ~l~'redrll [] serv [] wellbore seg U ann, disposal para req GEOLAREA ~ ~ 0 UNIT# ] I 3 ~ ~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... ~ 2. Lease number appropriate ................... 3. Unique well name and number .................. (~ N 4. Well located in a defined pool .................. (~ N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... (~ N 7. Sufficient acreage available in drilling unit ............ (~ N 8. If deviated, is wellbore plat included ............... ~ N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. ..(~) N 11. Permit can be issued without conservation order ........ ..~ N 12. Permit can be issued without administrative approval ...... "(~ N 13. Can permit be approved before 15-day wait ........... i~) N ENGINEERING APPR DATE 14. Conductor string provided 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~)N 23. If diverter required, does it meet regulations .......... ~) N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation N 26. BOPE press rating appropriate; te'st't~ ' '~¢Z~ ....... (~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ¢ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... N J 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ //Y N 34. Contact name/phone for weeklyproqress repo. rts .... ~ . Y N [exploratory omy] REMARKS GEOLOGY: RPC ~ ENGINEERING: COMMISSION: DW B EW~/r~ R N C'~~: JDH ~ Comments/Instructions: c) Z ~> HOW/Ijt - A:\FORMS\cheklist rev 07/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Oct 02 17:12:34 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 2 AK-MM-70274 Z I EMKE BURLEY MPH-12 500292280700 BP EXPLOP~ATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 02-0CT-98 MWD RUN 3 A~C-MM- 70274 ZIEMKE BURLEY 34 13N 10E CROF LMED Date. 2891 4150 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 65.90 37.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 20.000 112.0 PRODUCTION STRING 8.500 8365.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. AS PER KATIE NITZBERG ON 09/23/98: " THE MARKED LINE GR RAN ON JAN 12, 1998 WAS 1 FT. OFF FROM LWD DEPTHS SO DEPTH SHIFTING IS WAIVED. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY DH3~SE-4 (EWR4) . 5. ALL MWD RUNS REPRESENT MPH-12 WITH API# 50-029-22807-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8365'MD, 4456'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE STD2qT DEPTH FET 4650.0 RPD 4650 0 RPM 4650 0 RPS 4650 0 RPX 4650 0 ROP 4650 0 GR 4656 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 8307.0 8307.0 8307.0 8307.0 8307.0 8365.5 8314.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 4704.0 4815.0 3 4815.0 8365.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined At, sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 4650 8365.5 6507.75 7432 GR 7.0414 110.418 60.2758 7318 RPX 0.3026 2000 11.3955 7315 RPS 0.3266 2000 11.4956 7315 RPM 0.2409 2000 10.5742 7315 RPD 0.22 2000 12.3382 7315 ROP 7.4371 1879.6 220.303 7432 FET 0.1244 13.777 1.07537 7315 First Reading 4650 4656 4650 4650 4650 4650 4650 4650 Last Reading 8365.5 8314.5 8307 8307 8307 8307 8365.5 8307 First Reading For Entire File .......... 4650 Last Reading For Entire File ........... 8365.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4650.0 RPD 4650.0 RPM 4650.0 RPS 4650.0 RPX 4650.0 STOP DEPTH 4757.0 4757.0 4757.0 4757.0 4757.0 ROP 4650.0 GR 4656.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 4815.0 4764.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 17-SEP-97 5.06 5.46 MEMORY 4815.0 4704.0 4815.0 74.7 74.7 TOOL NI/MBER P0843CRG6 P0843CRG6 8.500 8.5 LSND 9.30 78.0 9.0 800 4.4 3.300 3.434 3.000 3.500 19.5 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 2 FT/H 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 4650 4815 4732.5 ROP 86.0925 1184.48 383.305 GR 29.5513 59.0529 44.5804 RPX 8.279 22.2098 13.4028 RPS 8.7693 20.7014 13.7951 RPM 8.3989 18.8183 13.1653 RPD 9.4101 18.8327 14.192 FET 0.1613 13.777 7.08026 Nsam 331 331 217 215 215 215 215 215 First Reading For Entire File .......... 4650 Last Reading For Entire File ........... 4815 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 4650 4650 4656 4'650 4650 4650 4650 4650 Last Reading 4815 4815 4764 4757 4757 4757 4757 4757 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4757.5 4757 5 4757 5 4757 5 4757 5 4764 5 4815 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : -TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8307.0 8307.0 8307.0 8307.0 8307.0 8314.5 8365.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAy EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 20-SEP-97 5.06 5.46 MEMORY 8365.0 4815.0 8365.0 38.7 76.3 TOOL NUMBER P0843CRG6 P0843CRG6 8.500 8.5 LSND 9.30 70.0 9.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 ROP MWD 3 FT/H 4 1 68 GR MWD 3 API 4 .1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 0 4 8 12 16 20 24 28 8OO 3.6 2.200 1.890 1.650 3.300 Channel 1 2 3 4 5 6 7 8 30.6 Name Min Max Mean Nsam DEPT 4757.5 8365.5 6561.5 7217 ROP 7.4371 1879.6 212.705 7101 GR 7.0414 110.418 60.7555 7101 RPX 0.3026 2000 11.3347 7100 RPS 0.3266 2000 11.426 7100 RPM 0.2409 2000 10.4957 7100 RPD 0.22 2000 12.282 7100 FET 0.1244 10.1896 0.893531 7100 First Reading 4757.5 4815.5 4764.5 4757.5 4757.5 4757.5 4757.5 4757.5 Last Reading 8365.5 8365.5 8314.5 8307 8307 8307 8307 8307 First Reading For Entire File .......... 4757.5 Last Reading For Entire File ........... 8365.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File