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Home My WebLink About201-0171. 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: Extend Suspension Date 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10945' None Casing Collapse Structural Conductor Surface Intermediate Production Liner 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 12/31/2025 10943'1050' 4-1/2" 5670' Packer: Baker ZXP Liner Top Packer Packer: Baker 80-40 GHB-22 Seal Assy SSSV: None Perforation Depth MD (ft): L-80 3259' 10216-10236', 10250-10290', 10510-10570', 10644-10664' 10040' 3-1/2" 5339-5348', 5354-5371', 5467- 5493', 5527-5537' 7" Perforation Depth TVD (ft): 108' 3287' 5276'10065' 16" 9-5/8" 79' 9946' MD 108' 2352' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-017 P.O. Box 100360, Anchorage, AK 99510 50-103-20483-00 Kuparuk River Field Meltwater Oil Pool-Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 9893' MD and 5202' TVD 9909' MD and 5210' TVD N/A Leslie Manning Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Leslie.Manning@conocophillips.com (907) 263-3731 Senior CTD/RWO Engineer KRU 2P-419 5671' 23' 23' 23', 575', 2010', 2477', 2662', 3345', 7889', 10199' N/A approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: le: Leslie Manning certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ame and ure with Date:Leslie.Manning@conocophillips.com (907) 263-3731 Senior CTD/RW O Engineer 15. Well Status after proposed work: OIL WINJ WDSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval:Date: esentative: Date for Operations:12/31/2025 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSSV Type:Packers and SSSV MD (ft) and TVD (ft):Packer: Baker ZXP Liner Top Packer Packer: Baker 80-40 GHB-22 Seal Assy SSSV:None 9893' MD and 5202' TVD 9909' MD and 5210' TVD N/A 9946' Tubing MD (ft): L-80 Tubing Grade: 4-1/2"5339-5348', 5354-5371', 5467- 5493', 5527-5537' Perforation Depth TVD (ft):epth MD (ft): , 10250-10290', , 10644-10664' Tubing Size: 5670'10943'3-1/2"1050' 5276'10065'7"10040'on ate 2352'3287'9-5/8"3259'e 108'108'16"79'or al CollapseBurstTVDMDSizeLengthg D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): None MPSP (psi):Plugs (MD): PRESENT WELL CONDITION SUMMARY 10. Field:Proposed Pools: Meltwater Oil Pool - SuspendedKuparuk River Field Meltwater Oil Pool-Suspended Current Pools:esignation (Lease Number): ADL0373112, ADL0389058 8. Well Name and Number:g: ation or Conservation Order governs well spacing in this pool? Yes Noquire a spacing exception due to property boundaries? 5. Permit to Drill Number: 6.API Number: 204-017 50-103-20483-00 4. Current Well Class: Exploratory Development Stratigraphic Service 360, Anchorage, AK 99510 ame: s Alaska, Inc. quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Other: Extend Suspension Date KRU 2P-419 5671'23'23'23', 575', 2010', 2477', 2662', 3345', 7889', 10199' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-016 By Grace Christianson at 10:40 am, Jan 09, 2026 -00 SFD P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Commissioner, State of Alaska January 7, 2026 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached, the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Well KRU 2P-419 (PTD# 204-017). This 10-403 is being submitted to request an extension of the Suspension Expiration Date to March 1, 2026. If you have any questions, please contact me at (907) 263-3731. Sincerely, Leslie Manning Senior CTD/RWO Engineer Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 7,889.0 2P-419 3/30/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: PA witnessed by Sully Sullivan 410 below OG. Final site clearance by Sully Sullivan 2P-419 1/8/2026 conklaa Notes: General & Safety Annotation End Date Last Mod By NOTE: PA witnessed by Sully Sullivan 410 below OG. Final site clearance by Sully Sullivan 1/8/2026 conklaa NOTE: VIDEO LOG SHOWED PARTED LINER AT 10290' 2/14/2014 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.1 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.1 3,286.9 2,351.6 40.00 L-80 BTC PRODUCTION 7 6.28 3,340.0 10,065.3 5,276.4 26.00 L-80 BTC-MOD LINER 3 1/2 2.99 9,893.0 10,943.0 5,669.7 9.20 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 40.1 Set Depth 565.0 Set Depth 564.2 String Max No 4 1/2 Tubing Description Tubing Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 545.0 544.4 6.71 Shoe - Mule 4.500 4 1/2" 12.6 ppf, L-80 NSCT Tubing Mule Shoe 3.958 Top (ftKB) 3,685.0 Set Depth 9,946.1 Set Depth 5,225.4 String Max No 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-MOD ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,776.5 5,152.8 64.98 GAS LIFT 5.984 CAMCO KBG-2-9 3.938 9,830.4 5,175.6 64.89 XO Reducing 5.200 CROSSOVER 4.5"x3.5" TUBING 2.991 9,879.1 5,196.4 64.45 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE 2.812 9,895.1 5,203.3 64.30 NIPPLE 4.500 CAMCO 'D' NIPPLE w/2.75" NO GO PROFILE 2.750 9,908.2 5,209.1 64.30 LOCATOR 5.000 BAKER G-22 LOCATOR 3.000 9,909.5 5,209.6 64.30 SEAL ASSY 4.000 BAKER 80-40 GBH-22 SEAL ASSEMBLY w/HALF MULE SHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 40.0 40.0 0.00 MARKER PLATE 30" Marker Plate 1/4" thick 12/24/2025 0.000 575.0 574.2 7.72 CIBP K1 CIBP Baker 12/8/2025 0.000 3,340.0 2,374.2 64.75 CUT 2/19/2025 6.800 3,345.0 2,376.3 64.75 CIBP CIBP set 2/18/2025 0.000 3,685.0 2,528.7 61.77 CUT WELLTEC MECHANICAL TBG CUT AT 3685' RKB 3/31/2024 3.958 9,800.0 5,162.8 65.09 TUBING PUNCH 3' TUBING PUNCH, 2", 7 GRAM, 6 SPF, 18 0.61" HOLES 3/23/2024 3.958 10,199.3 5,332.3 65.08 CIBP Set 2.62" CIBP (mid-element @ 10200' RKB) OAL=1.37' 3/9/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,893.0 5,202.5 64.32 PACKER 7.000 BAKER ZXP HR LINER TOP ISOLATION PACKER 5.000 9,911.9 5,210.7 64.31 NIPPLE 5.500 RS PACKOFF SEAL NIPPLE 4.250 9,943.3 5,224.2 64.39 XO BUSHING 5.570 CROSSOVER BUSHING 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,216.0 10,236.0 5,339.4 5,347.8 T-3, 2P-419 3/1/2014 6.0 IPERF 2.5" GSPF HSD MILLENIUM, 60 deg phase 10,250.0 10,290.0 5,353.8 5,370.9 T-3, 2P-419 2/26/2014 6.0 IPERF 2" GSPF HSD MILLENIUM , 60 deg phase 10,510.0 10,530.0 5,466.7 5,475.6 T-3, 2P-419 3/8/2004 6.0 IPERF 2.5" HSD PJ, 60 deg phase 10,530.0 10,570.0 5,475.6 5,493.5 T-3, 2P-419 3/7/2004 6.0 IPERF 2.5" HSD PJ, 60 deg phase 10,644.0 10,664.0 5,527.3 5,536.6 T-3, 2P-419 3/6/2004 6.0 IPERF 2.5" HSD PJ, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.1 3,287.0 40.1 2,351.6 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 105Drag up (lbs): 125Time started reciprocating: 21:30Time stopped reciprocating: 02:37Annular flow after cement job (Y/N): NCirculating BHT (F): 65Static BHT (F): 51Pressure before cementing (psi): 375Hours circulated between stages: 3Bbls cmt to surf: 136.6Method used to measure density: DensometerMethod used for mixing cement in this stage: TubReturns (pct): FULLTime cementing mixing started: 01:30 1/24/2004 2P-419, 1/8/2026 12:57:34 PM Vertical schematic (actual) LINER; 9,893.1-10,943.0 IPERF; 10,644.0-10,664.0 IPERF; 10,530.0-10,570.0 IPERF; 10,510.0-10,530.0 Pre-Flush; 10,065.0 ftKB IPERF; 10,250.0-10,290.0 IPERF; 10,216.0-10,236.0 CIBP; 10,199.3 PRODUCTION; 3,340.0- 10,065.3 TUBING PUNCH; 9,800.0 GAS LIFT; 9,776.5 Cement Plug; 7,889.0 ftKB Cement Plug; 7,889.0 ftKB Cement Casing; 2,745.0 ftKB Cement Casing; 2,746.0 ftKB CUT; 3,685.0 CIBP; 3,345.0 CUT; 3,340.0 SURFACE; 40.1-3,286.9 Cement Plug; 2,662.0 ftKB Cement Plug; 2,505.0 ftKB Cement Plug; 2,010.0 ftKB Cement Casing; 40.1 ftKB CIBP; 575.0 CONDUCTOR; 40.1-108.0 MARKER PLATE; 40.0 Plug & Abandonment; 40.1 ftKB KUP INJ KB-Grd (ft) 35.30 RR Date 2/9/2004 Other Elev 2P-419 ... TD Act Btm (ftKB) 10,945.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048300 Wellbore Status INJ Max Angle & MD Incl (°) 66.34 MD (ftKB) 6,182.71 WELLNAME WELLBORE2P-419 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,745.0 10,065.0 2,111.0 5,276.2 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 92Drag up (lbs): 245Time started reciprocating: 18:30Time stopped reciprocating: 11:15Annular flow after cement job (Y/N): NCirculating BHT (F): 107Static BHT (F): 136Pressure before cementing (psi): 550Hours circulated between stages: 3.75Method used to measure density: DensometerMethod used for mixing cement in this stage: BatchReturns (pct): FULLTime cementing mixing started: 23:15 2/3/2004 2,746.0 6,198.0 2,111.4 3,640.8 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 92Drag up (lbs): 245Time started reciprocating: 18:30Time stopped reciprocating: 11:15Annular flow after cement job (Y/N): NCirculating BHT (F): 107Static BHT (F): 136Pressure before cementing (psi): 310Hours circulated between stages: 7.75Bbls cmt to surf: 0Method used to measure density: DensometerReturns (pct): 100Time cementing mixing started: 09:00 2/2/2004 10,065.0 10,943.0 5,276.2 5,669.7 Pre-Flush Pipe movement: Rotate & RecipDrag down (lbs): 72000Drag up (lbs): 180000Time started reciprocating: 15:30Time stopped reciprocating: 20:30Time started rotating: 16:30Time stopped rotating: 20:30Init torque (ft-lbf): 10000Max torque (ft -lbf): 10000Pressure before cementing (psi): 520Hours circulated between stages: 4Bbls cmt to surf: 0Method used to measure density: densimeterMethod used for mixing cement in this stage: BatchReturns (pct): 100Time cementing mixing started: 19:00 2/7/2004 7,889.0 9,803.0 4,356.6 5,164.0 Cement Plug 3/27/2024 7,889.0 9,803.0 4,356.6 5,164.0 Cement Plug 3/27/2024 2,662.0 3,345.0 2,072.1 2,376.3 Cement Plug Pump 22 Bbls 10 PPG spacer w/ Surf wash @ 2.3 BPM, 80 PSI. Close UPR. Drop 5" foam ball. Open UPR. Pump 39 Bbls 15.8 PPG PTA cement w/ 5 lbs/bbls Bridge Maker II LCM @ 2.3 BPM, 235 PSI. Close UPR. Drop 5" foam ball. Open UPR. Pump 6 Bbls 10 PPG spacer @ 2.3 BPM, 65 PSI. Displace w/ 34.7 Bbls 9.8 PPG brine @ 3.5 BPM, 250 PSI. Good returns throughout job. End job @ 00:49 Hrs. 2/21/2025 2,505.0 2,662.0 1,999.3 2,072.1 Cement Plug pumped 15 bbls, cleaned out to 2,477' CTMD TOC 10/24/2025 2,010.0 2,486.0 1,774.3 1,990.8 Cement Plug HES pump 10 Bbls of fresh water @ 3 BPM, 210 PSI. Pump 38 Bbls of 16.0 PPG PTA cement @ 3 BPM, 580 PSI. Pump 1.5 Bbls of fresh water @ 3 BPM, 310 PSI. Displace w/ 10 Bbls of seawater @ 3 BPM, 210 PSI. POOH T/ 1726'. Circ well clean. Tag witnessed by AOGCC rep Josh Hunt. 12/6/2025 40.1 575.0 40.1 574.2 Plug & Abandonment Pump 4 Bbls fresh water @ 3 BPM, 175 PSI. Pump 30 Bbls Surfactant wash @ 3 BPM, 200 PSI. Pump 5 Bbls fresh water @ 3 BPM, 175 PSI. Pump 50 Bbls 15.8 PPG PTA cement. 15.8 PPG returns at surface w/ 42 Bbls away. 12/9/2025 2P-419, 1/8/2026 12:57:34 PM Vertical schematic (actual) LINER; 9,893.1-10,943.0 IPERF; 10,644.0-10,664.0 IPERF; 10,530.0-10,570.0 IPERF; 10,510.0-10,530.0 Pre-Flush; 10,065.0 ftKB IPERF; 10,250.0-10,290.0 IPERF; 10,216.0-10,236.0 CIBP; 10,199.3 PRODUCTION; 3,340.0- 10,065.3 TUBING PUNCH; 9,800.0 GAS LIFT; 9,776.5 Cement Plug; 7,889.0 ftKB Cement Plug; 7,889.0 ftKB Cement Casing; 2,745.0 ftKB Cement Casing; 2,746.0 ftKB CUT; 3,685.0 CIBP; 3,345.0 CUT; 3,340.0 SURFACE; 40.1-3,286.9 Cement Plug; 2,662.0 ftKB Cement Plug; 2,505.0 ftKB Cement Plug; 2,010.0 ftKB Cement Casing; 40.1 ftKB CIBP; 575.0 CONDUCTOR; 40.1-108.0 MARKER PLATE; 40.0 Plug & Abandonment; 40.1 ftKB KUP INJ 2P-419 ... WELLNAME WELLBORE2P-419 1a. 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: 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: 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: 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: 23. BOTTOM 13-38/"L-80 120' 2-7/8"L-80 4,463' 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 Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 60 bbls Class 'G' Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Oil-Bbl: Flow Tubing 6,255' - 8,626' N/A Gas-Oil Ratio:Choke Size: 6,470 Cement Retainer Per 20 AAC 25.283 (i)(2) attach electronic information 6.4#4,422' 72#120' 6,673' 8,291' SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 16" CEMENTING RECORDSETTING DEPTH TVD TOP HOLE SIZETOP 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. 1,800' Approx. 6,658' / 4,413'N/A N/A 3853' FSL, 1923' FEL, Sec. 25, T13N, R10E, UM 57.05' 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22903-60-00 MILNE PT UNIT E-30AL1 MILNE POINT / SCHRADER BLUFF OIL ADL0025518 & ADL0047438 N/A9,290' / 4,481' 9,290' / 4,481' GL: 23.2' BF: 6/6/2001 5/1/2001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 201-017 / 322-352Aband.: 1/24/2023 1697' FSL, 737' FWL, Sec. 19, T13N, R11E, UM 3264' FSL, 2293' FWL, Sec. 19, T13N, R11E, UM RES & GR 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 Uncemented Slotted Liner3-3/4" Surface: x- 569220 y- 6016391 Zone- ASP4 2,246'2-3/8" BOTTOM 260 sx Arctic Set (Approx. AMOUNT PULLED 6-3/4"747 sx Coldset III, 158 sx Foamed, 70 sx 'G' 36' TPI: x- 571851 y- 6019539 Zone- ASP4 Total Depth: x- 573392 y- 6011122 Zone- ASP4 5-1/2" 15.5# J-55 34' 6,738' 34' 4,462' CASING WT. PER FT.GRADE 36' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 9:40 am, Apr 06, 2023 Abandoned 1/24/2023 JSB RBDMS JSB 041123 6021122 xGMGR03AUG2023DSR-4/14/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 6,803' 4,465' 7,612' 4,477' 8,232' 4,479' 8,442' 4,463' 31. List of Attachments: Wellbore Schematic, Weekly Operation Summaries and Photos. 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 Operations Manager 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: INSTRUCTIONS 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. 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. 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. 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. Top of Schrader OA Base of Scrader OA Authorized Title: 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. None Base of Scrader OA TPI (Top of Producing Interval). Authorized Name and 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 Base of Scrader OA Formation Name at TD: 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. 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: 2023.04.06 07:50:15 -08'00' David Haakinson (3533) Schrader Bluff - OA DATE REV. BY COMMENTS Orig. DF Elev. = 57.0’ (N 27E) Orig. GL Elev. = 23.2' DF to 7” csg. hng. = 33.6' (N 27E) MILNE POINT UNIT WELL E-30A API NO: 50-029-22903 BP EXPLORATION (AK) 5.5" float collar (PBTD) KOP @ 500' Max. hole angle = 69 to 73 deg. from 3950' to 5850' Hole angle thru' perfs = 73 deg. 5.5 "floatshoe 13 3/8'' 72 ppf, L-80 MPU E-30A 115' 5.5" 15.5 ppf, J-55, Btrc. prod. casing (drift ID = 4.825", cap. = 0.0238 bpf) (cap. w/ 2 3/8“ tbg inside = 0.0183 bpf) Two 5.5" x 20’ short jts. f/ 6320' to 6359' md O 5.5” Port CollarCementer 1336’ md 7086’ md 7169 ’md 7” 26 ppf L-80 Btrc. 7”x 5.5” X-Over 117’ md ‘OA’ Sand Sqz’d3 3/8” 0.6 6758’ - 6778’ (4475’ - 4484’)‘OB’ Sand3 3/8” 2 6845’ - 6865’ (4523’ - 4560’) OA/ OB Sands - Limited entry frac w/ 119.6 M# of PropLoked 16/30 Badger prop. behind pipe. 23/8"4.6#ppf,L-80,8rdEUEtbg. (drift ID =1.995", cap. = 0.00387 bpf) 10/20/98 MDO Completion w/ heat trace 4 ES EZSV @ 6754’ W/ Cement below TOL @ 6511’ ( 4.5” od. scoop guide ) 4.5” GS profile RA @ 6666’ TOL @ 6673’ 4.5” GS profile 5.5” Baker whipstock top @ 6657’ 5.5” Baker whipstock @ 6737’ 2-3/8”,4.43ft/#L-80stl&fl43 Pre-Drilled 4 spf 2-7/8”, L-80 stl 6.16#, Pre-Drilled 4 spf pbtd @ 9290’ Liner = 9170’ pbtd @ 8,626’ Liner = 8,291’ Window 6658’ - 666 E-30a L-1 E-30a Window 6738’ - 6744’ RA @ 6746’ (northlateral) (southlateral) Tree:2 9/16" - 5M Wellhead:7" 5M Varco ADRS-7 Weld on style Tbg. Hng:7 1/16“ 5M X 2 3/8” EUE W2“TypeHBPV 05/21/01 MDO Sidetrack 3-S and completion 4-ES 11/19/05 MDO ESP RWO 4-ES Change tree size 10/02/07 REH ESP RWO by 4ES 6470' md Cement Retainer 2-3/8" 4.6#, L-80 EUE 8rd Tbg Mule Shoe 2223' md 5.5" Casing collapsed at 400' Pumped 60 BBL cement plug 7/31/12 AAR Doyon 14 suspended well PROPOSED SCHEMATIC Surface plug: surface to 2,223' MD Hilcorp Alaska Surface plug: surface to 2,223' MD 2-3/8”,4.43 ftff/#L-80 stl &fl43 Pre-Drilled 4 spf OO 2 O 2 2-7/8”,L-80 stl 6.16#, Pre-Drilled 4 spf 08-16-2022 12LB. class G Cement Halliburton. Well Name Rig API Number Well Permit Number Start Date End Date MP E-30A Fullbore 50-029-22903-01-00 201-011 8/16/2022 1/24/2023 Confirm circulation, Circ in 75 bbl. of 12.0ppg Class G cement. Good returns to surface. 50 bbl. citric pill to tank 032, 21". Pumped 5 bbl. fresh water clear line 25" to tank, PT hardline 1000 low 4000 high. Pumped 70 bbl. 80 deg. fresh water down tubing seen about 40 bbl. dirty fluid then turn clear after 54 bbl. Swapped over to 20 bbl. surfactant down tubing. Pumped 5 bbl. fresh water clear line swapped to 12 lb. class G cement down tubing, at 52 bbl. seen cement to tank, at 60 bbl. sampled seen 11.5 lb. cement clean, at 75 bbl. weighed cement 12 lb clean. Flushed hardline to tank, raised tank and rinsed clean to vac truck. Returns to class two truck 290 bbl. Returns from pump truck clean up 186 bbl. ( 73 bbl. was left over fresh). Tank rental 032 232bbls from Tanko. No operations to report. 8/13/2022 - Saturday No operations to report. 8/16/2022 - Tuesday 8/14/2022 - Sunday No operations to report. 8/15/2022 - Monday 8/12/2022 - Friday No operations to report. 8/10/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/11/2022 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP E-30A Fullbore 50-029-22903-01-00 201-011 8/16/2022 1/24/2023 1/20/2022 - Friday GPB R&P Worley Excavator Operator arrived @10:00 am to start the Dig on MPE-30 P&A. Worked on digging hole from 5:30 am to 7:30 pm removed dirt down to depth of 10.5ft MPU R&P installed the MPU trench box well head removal . Worley off location by 8:00 pm. Day shift Operator Clinton Chase, Hak CM Kruskie. 1/18/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary GPB R&P Worley Excavator Operator arrived @10:00 am to start the Dig on MPE-30 P&A. Worked on digging hole from 1:00 to 5:30 pm removed old cellar box and started on hole. Day shift Operator Clinton Chase, Hak CM Kruskie. 1/19/2022 - Thursday GPB R&P Worley Excavator Operator arrived @10:00 am to start the Dig on MPE-30 P&A. Worked on digging hole from 5:30 am to 5:30 pm removed dirt down to install trench box for well head removel. Day shift Operator Clinton Chase, Hak CM Kruskie. WELD MARKER PLATE FOR P&A: CAM ST. JOHN WITH AOGCC ON LOCATION FOR WITNESS. VERIFIED CUT AT 3' BELOW TUNDRA LEVEL. TAKE PICTURES. VERIFIED MARKER PLATE IS CORRECT. WITNESSED PLACEMENT OF MARKER. WELD MARKER PLATE. TAKE PICTURES. BACKFILL EXCAVATION. JOB COMPLETE. No operations to report. 1/21/2022 - Saturday GPB Worley Tree P&A crew arrived at MPU @ 9:00 set up and cut and removed E-30 tree and conductor 3' below tundra. Crew left MPU 4:00pm. No top job needed clean surface, clean cut . Kruskie, Allison,McNeal,Mikulecky, Company men. 1/24/2023 - Tuesday 1/22/2023 - Sunday MPU WST Day shift jack hammered cement on conductor below plate to 8 inches below cut off depth of 9 ft from surface grade ( surface to tundra is @ 6 ft then 3¿ below to cut off point ) from 7:am am to 5:30 PM. Rock, Parkerwood, labor. Company man Mikulecky. Night shift MPU WST night shift jack hammered cement off the conductor under plate to cut off depth . from 12:00am to 5:30 am. Mueller, Mangum,Company Lead Mikulecky 225-02967.15.10.01 1/23/2023 - Monday CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Tom Fouts To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] FW: MP E-30AL1 AOGCC 10-407 Submittal, PTD: 201-017 Date:Thursday, April 13, 2023 8:11:15 AM Morning James, After speaking with the geologist, the BHL Y coordinate should be 6021122 and the formation at TD is going to be the OA. Please let me know if you have any other questions. Regards, Tom From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Wednesday, April 12, 2023 8:18 AM To: Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] FW: MP E-30AL1 AOGCC 10-407 Submittal, PTD: 201-017 Hi, There are a couple of issues with this 407: 1. The BHL Y coordinate is being flagged as off. ~ Can you take a look at this ? 2. Can you let me know what the BHL formation names is ? thanx From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Thursday, April 6, 2023 8:49 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: MP E-30AL1 AOGCC 10-407 Submittal, PTD: 201-017 And one last 407 for this round of emails. Thank you! Kayla Junke Natural Resources Tech II AOGCC (907) 793-1225 From: Tom Fouts <tfouts@hilcorp.com> Sent: Thursday, April 6, 2023 8:34 AM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: MP E-30AL1 AOGCC 10-407 Submittal, PTD: 201-017 Hello, Please review the attached 10-407 submittal for Milne Point well MP E-30AL1 Sundry No.: 322-352 Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. 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no ALASKA OIL AND GAS CONSERVATION COMMISSIONAIaska CA ,: ,- ; o,is.: 4.)t411.iiss'on WELL COMPLETION OR RECOMPLETION REPORT AND LOtich la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended 1b. Well Class: " 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 7/28/2012 201 - 017 312 - 287 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 5/1/2001 50 - 029 - 22903 - 60 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 5/6/2001 MPE -30AL1 3853' FSL, 1923' FEL, Sec. 25, T13N, R10E, UM 8. KB (ft above MSL): 57.05' 15. Field / Pool(s): Top of Productive Horizon: Milne Point Unit / Schrader Bluff 1697' FSL, 737' FWL, Sec. 19, T13N, R11 E, UM GL (ft above MSL): 23.2' Total Depth: 9. Plug Back Depth (MD +TVD): 3264' FSL, 2293' FWL, Sec. 19, T13N, R11 E, UM 9290' 4481' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 569220 y- 6016391 Zone- ASP4 9290' 4481' ADL 025518 & 047438 TPI: x- 571851 y- 6019539 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 573392 y 6021122 Zone- ASP4 None 18. Directional Surve y : 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): ❑ Yes ►'_ No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: RES, GR 6658' 4413' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 13 -3/8" 72# L -80 36' 120' 36' 120' 16" 260 sx Arctic Set (Approx.) 5 - 1/2" 15.5# J - 34' 6658' 34' 4413' 6 -3/4" 747 sx Coldset, 158 sx Foamed, 70 sx 'G' 2 -7/8" 6.4# L -80 6511' 9170' 4324' 4472' 3 -3/4" Uncemented Slotted Liner 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open S D SET (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE (MD) PACKER SET ( MD / TVD) 2 -3/8 ", 4.6 #, L -80 Kill String 2246' None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. A'� c- {- r' i; `( U L DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6470' Cement Retainer 6255' - 9290' 60 Bbls Class 'G' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes IN No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None 4RBDWIS AUG 2 4 2012 tm a Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE f`! ' r ' •riginal Only /2-/ 29. GEOLOGIC MARKERS (List all formations anarkers encountered): 30. FORMATION TESTS NAME TVD Well Tested . Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Schrader OA 6803' 4465' None Base of Schrader OA 7612' 4477' Base of Schrader OA 8232' 4479' Base of Schrader OA 8442' 4463' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Reports, Well Schematic Diagram 32. I hereby certify that the Is - • • ing is t u = - • r -ct to the best of my knowledge. r Signed: Joe Lastufka 1 Title: Drilling Technologist Date: ° g,yS/Z MPE - 30AL1 201 - 017 312 - 287 Prepared By Name/Number: Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPl (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • • ' %r'' / %1 �'i' / /��' %/� "� /r�'' %/'�, %�%�r' � %' %? r << !. � rat °�� /i�`'� f,,. %f�' °, �/ /j . / , , / / �s �,�. s,,,; f .: 0 ,ter n,s r ^; f f . � � j > r •rj �� f ry �4t � �. i /,'," 4/7 4 „; 1;4 ;;;././, /4/74; Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/20/2012 12:00 - 14:00 2.00 MOB N WAIT PRE REPAIRED GRAVEL ON PAD AND ROLLED OUT - WAIT ON MATS TO BE BROUGHT FROM PRUDHOE - PERFORM WORK ORDERS ON RIG 14:00 - 21:00 7.00 MOB P PRE MOVE OFF OF MPE -19 - MOVE DOWN TOWARD MPE -30 - RIG BEGAN TO TURN TOWARD MPE -30 AND CAVED INTO PAD, RIG WAS 40' AWAY FROM EDGE OF PAD - BACKED RIG OUT OF HOLE AND POSITION RIG ON FIRM GRAVEL - NOTIFIED RWO FIELD SUPERINTEDANT - CALLED FOR MINOR GRAVEL WORK AND RIG MATS TO BE BROUGHT OUT 21:00 - 22:00 1.00 MOB P PRE MOVE RIG OVER WELL AND SHIM. - IA 100 PSI. 22:00 - 00:00 2.00 RIGU P PRE SPOT CREW TRAILER, PIPE SHED RAMPS, LOWER THE STAIRS, MAKE UP THE HARDLINE TO THE FLOWBACK TANK. RIG UP CIRCULATING LINES IN THE CELLAR TO THE SQUEEZE MANIFOLD. PREPARE TO START TAKING ON 120 DEGREE SEAWATER. 7/21/2012 00:00 - 02:30 2.50 RIGU P PRE TAKE ON 120 DEGREE 8.5 PPG SEAWATER IN THE PITS. FINISH RIGGING UP THE KILL MANIFOLD IN THE CELLAR. TEST THE LINES TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES. GOOD TEST. TEST THE CHECK VALVES IN THE LINE. GOOD TEST. - RIG ACCEPTED AT 00:00 02:30 - 04:00 1.50 RIGU P PRE CHANGE OUT THE ODS TUGGER LINE AND MAN RIDER CABLE. 04:00 - 07:00 3.00 RIGU P PRE GENERAL RIG MAINTENANCE AND MP2 WORK ORDERS. WAIT ON DAY WSL, TOOLPUSHER, AND BP SUPERINTENDENT TO PERFORM WELL KILL. 07:00 - 08:30 1.50 WHSUR P DECOMP R/U WELL SUPPORT LUBRICATOR - TEST TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - PULL BPV, SECURE TREE 08:30 - 11:30 3.00 WHSUR P DECOMP PJSM FOR WELL KILL PROCEDURE - RWO SUPERINTENDANT, WSL AND TOOL PUSHER PRESENT - TUBING = 200 PSI, IA = 80 PSI - BLEED GAS OFF IA WITH MINIMAL PRESSURE, 5 MINUTES - LINE UP AND PUMP 25 BBLS OF 120 DEGREE SEA WATER DOWN TUBING TAKING RETURNS OUT IA, 3 BPM = 640 PSI - TOOK 15 BBLS TO FILL IA - CLOSE CHOKE TO FLOWBACK TANK AND BULL HEADED 30 BBLS TO PERFORATIONS, 5 BPM = 2490 PSI - OPEN CHOKE AND PUMP 198 BBLS DOWN TUBING OUT IA TO FLOW TANK, 5 BPM = 2260 PSI - 253 BBLS TOTAL PUMPED, 166 BBLS RETURNED TO FLOW BACK TANK Printed 8/7/2012 2:41:09PM se;,,,:yet 51/i/xyvA,,,I,As7v,; 9 7a Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:00 0.50 WHSUR P DECOMP MONITOR WELL FOR 30 MINUTES - TUBING = 0 PSI, IA = 0 PSI, BOTH SIDES ON SLIGHT VACUME - WILL MAINTAIN CONSTANT HOLE FILL WHILE N/D AND N/U 12:00 - 15:00 3.00 WHSUR P DECOMP R/U WELL SUPPORT LUBRICATOR - TEST TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - SET TWC, R/D WELL LUBRICATOR - PERFORM ROLLING TEST FROM BELOW, 500 PSI, 10 MIN, CHARTED - TEST TWC FROM ABOVE 250 PSI, 3500 PSI, 5 MIN CHARTED 15:00 - 16:30 1.50 WHSUR P DECOMP BLOW DOWN AND RIG DOWN THE CHOKE SKID LINES AND HARDLINES TO THE TIGER TANK. 16:30 - 18:00 1.50 WHSUR P DECOMP CAMERON BLED OFF THE ADAPTOR VOID AND DRAIN THE TREE. NIPPLE DOWN THE TREE AND INSPECT THE HANGER. MAKE UP THE 2 -3/8" CROSS OVER 5 TURNS. 18:00 - 20:30 2.50 BOPSUR P DECOMP INSTALL THE ADAPTOR AND NIPPLE UP THE BOPE. INSTALL THE TURNBUCKLES, RISER AND MOUSEHOLE. AIR UP THE BOOTS. 20:30 - 22:00 1.50 BOPSUR P DECOMP CHANGE OUT THE HCR KILL VALVE. 22:00 - 23:33 1.55 BOPSUR P DECOMP CHANGE OUT THE LOWER RAMS TO 2 -3/8" SOLID BODY RAMS. 23:33 - 00:00 0.45 BOPSUR P DECOMP RIG UP TO TEST THE BOPE. GREASE THE CHOKE MANIFOLD. 7/22/2012 00:00 - 01:30 1.50 BOPSUR P DECOMP CONTINUE TO RIG UP TO TEST THE BOPE. 01:30 - 08:00 6.50 BOPSUR P DECOMP TEST THE BOPE TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES EACH TEST. TEST THE LOWER 2 -3/8" RAMS AND ANNULAR WITH THE 2 -3/8" TEST JOINT AND THE UPPER 2 -7/8" X 5" VBR'S WITH 2 -7/8" TEST JOINT. ANNULAR FAILED TEST WITH THE 2 -3/8" TEST JOINT AND DECISION WAS MADE TO GO FORWARD WITH TEST AND FINISH THE REMAINING TEST THEN CHANGE OUT THE ANNULAR AND RETEST IT BEFORE PROCEEDING WITH OPERATIONS. - BOB NOBLE OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST - MAINTAIN CONTINUOUS HOLE FILL AT 20 BBLS / HR OF 8.5 SEA WATER 08:00 - 13:00 5.00 BOPSUR N RREP DECOMP PJSM, C/O ANNULAR ELEMENT - M/U AND INSTALL 2 3/8 TEST JOINT IN BOP, FILL STACK WITH WATER - TEST ANNULAR 250 PSI, 3500 PSI, 5 MIN, CHARTED 13:00 - 15:30 2.50 BOPSUR N RREP DECOMP INSTALL THE BELL NIPPLE, RISER, MOUSEHOLE AND RIG UP THE 2 -3/8" TEST JOINT AND FUNCTION THE ANNULAR SEVERAL TIMES. 15:30 - 17:30 2.00 BOPSUR N RREP DECOMP TEST ANNULAR WITH 2 -3/8" TEST JOINT TO 250 PSI, 3500 PSI, 5 MIN, CHARTED AND PERFORM KOOMEY TEST. 17:30 - 18:30 1.00 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT AND BLOW DOWN THE SURFACE LINES. 18:30 - 19:00 0.50 BOPSUR P DECOMP CLEAN AND CLEAR THE RIG FLOOR. Printed 8/7/2012 2:41:09PM p7;.,,,v/7 v 1,r,$, ,,-,,,w-,,';'' ,,,,•,,,,, % irj' .( ,, ' ' o / %// b ,: %e: e: .r e � j '- , i Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 19:30 0.50 WHSUR P -_ DECOMP PERFORM RIG EVACTUATION DRILL AND HOLD AN AAR. 19:30 20:00 0.50 WHSUR P ■- DECOMP RIG UP AND TEST PSI / LOW / 355 00 0 PSI PSI HIGH IGH FOR 5 MINUTES. GOOD TEST. 20:00 - 21:00 1.00 WHSUR P -_ DECOMP PULL THE TWC AND RIG DOWN THE LUBRICATOR. 21:00 - 23:00 2.00 PULL P DECOMP DRAIN THE STACK, PICK UP THE LANDING JOINT. MAKE UP THE LANDING JOINT TO THE HANGER AND BOLDS. PULL THE HANGER FREE AT 75K UP WT. PULL THE HANGER TO THE RIG FLOOR AND CHECK THE CONDUCTIVITY. LAYDOWN THE HANGER AND LANDING JOINT, CUT THE ESP AND HEAT TRACE CABLE. -UP WT 75K / DOWN WT 68K 23:00 - 00:00 1.00 PULL P DECOMP MAKE UP THE HEAD PIN AND BREAK CIRCULATION AT 2 BPM WITH 440 PSI. CONTINUE TO CIRCULATE BOTTOMS UP THROUGH THE GAS BUSTER AT 5 BPM WITH 2050 PSI. 7/23/2012 00:00 - 01:00 1.00 PULL P ■- DECOMP MONITOR WELL FOR MINUTES. STRING STRING THE E ROPES ROPES THROUU GH THE SHEAVE AND BLOW DOWN THE CHOKE MANIFOLD. 01:00 - 12:00 11.00 PULL P DECOMP PULL OUT OF THE HOLE WITH THE 2 -3/8" EUE 4.6# J-55 ESP COMPLETION FROM 6476' TO 3500' - HOLD D1 WELL CONTROL DRILL 12:00 - 12:30 0.50 PULL P DECOMP SERVICE THE TOP DRIVE AND DRAWWORKS. 12:30 - 18:00 5.50 PULL P DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH THE 2 -3/8" EUE 4.6# J-55 ESP COMPLETION FROM 3500' TO 394'. STARTED SEEING 10 -15K OVERPULL. TOP OF MOTOR LOCATED AT 305' AND CENTRALIZER LOCATED AT 394' WHEN REMAINING TUBING HUNG UP. NOTIFICATIONS CALLED AND APPROVAL GIVEN TO OVERPULL UP TO 50K WAS GIVEN. PULLED 35K TO 45K WHEN PULLED FREE. CONTINUED OUT OF THE HOLE TO SURFACE. MOTOR HOUSING AND CENTRALIZER WERE LEFT IN THE HOLE. LENGTH OF FISH IS APPROXIMATELY 22' LONG WITH AN OD OF 2.32 ". SEE ATTACHMENT FOR PICTURES OF THE BOTTOM OF RECOVERED COMPLETION. -266 5" CANNON CLAMPS -75 2' CROSS COLLAR CANNON CLAMPS - 58 SC CROSS COLLAR CLAMPS 18:00 - 21:00 3.00 PULL P -_ DECOMP LAY DOWN THE ESP PUMPS AND REMAINING MOTOR PARTS. 21:00 22:00 1.00 PULL P ■- DECOMP RIG DOWN THE ESP AND CLEAN AND CLEAR THE FLOOR OR OF OF ALL CENTRILIFT TOOLS. 22:00 - 00:00 2.00 PULL C DECOMP DISCUSS OPTIONS WITH TOWN ODE AND FIELD SUPERINTENDENT BEFORE PROCEEDING FORWARD. PLAN FORWARD APPROVED BY FIELD SUPERINTENDENT GREG SARBER. LOAD THE PIPESHED WITH 2 -3/8" P110 WTS-6 WORKSTRING AND MOBILIZE BAKER FISHING. Printed 8/7/2012 2:41:09PM ay , Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/24/2012 00:00 - 02:30 2.50 FISH C DECOMP LOAD AND STRAP 2 -3/8" WTS-6 TUBING INTO THE PIPESHED ALONG WITH 3 -1/8" COLLARS. PREPARE FISHING BHA. - M/U SPEAR WITH 2.375" DOUBLE GRAPPLE WITH 2- 1 1/4" EXTENSIONS, XO, DRAIN SUB, BUMPER SUB, JARS, XO, 9- 3 1/8" DC, XO, INTENSIFIRE, XO, XO. 02:30 - 07:00 4.50 FISH C DECOMP SINGLE IN THE HOLE WITH THE BAKER FISHING BHA TO 368'. - P/U WT 45K. S/O WT 46K. - AS INSTRUSCTED BY BAKER FISHING REP, TAG TOF AT 388' - SLACK OFF TO 399' ENGAGING FISH. 07:00 - 12:00 5.00 FISH C DECOMP SECURE RIG FLOOR, REVIEW DDI SOP FOR JARRING OPS. - JAR 30K OVER, STRAIGHT PULL 30K OVER. - MOVING FISH UPHOLE 11' AND PULLING FREE. - POH TO 358' - LOSSES TO WELL IN LAST 12 HRS= 102 BBLS 8.5 PPG KWF. - WELL CONTINUES TAKING 10 BPH. 12:00 13:00 1.00 FISH C ■- DECOMP CREW CHANGE, POST FOR LID FISHING BHA. - COMPLETE E PO POST JARRING DERRICK INSPECTION AS PER DDI SOP. 13:00 - 15:00 2.00 FISH .. C DECOMP POH, LID 2 3/8" TBG AND 9 DRILL COLLARS. 15:00 - 15:30 0.50 FISH C DECOMP PULL FISH TO SURFACE. - RECOVERED ALL ESP MOTOR PARTS. - GAUGE CENTRILIZER ON BOTTOM OF MOTOR ASSY. 4.75" TIGHT. 15:30 - 17:30 2.00 FISH C -_ DECOMP UD FISH AND FISHING BHA. - CLEAR RIG FLOOR. 17:30 - 18:00 0.50 EVAL C DECOMP DECISION FROM TOWN MADE TO RUN PDS CALIPER LOG. - PULL WEAR RING, INSTALL TEST PLUG. - R/U AND USE CONTINUOUS HOLE FILL DOWN VA USING PUMP WITH BYPASS - KEEP HOLE FULL WITH 8.5 PPG SEAWATER. - WELL CONTINUES TAKING 10 BPH 18:00 - 22:30 4.50 EVAL C DECOMP PJSM. REVIEW SOP FOR WL. - R/U DUTCH RISER. - P/U SWS EQUIPMENT AND LUBRICATOR. - TEST LUBRICATOR TO 250/3500 PSI 5 MIN EACH CHARTED. 22:30 - 23:15 0.75 EVAL C DECOMP PULL DUTCH RISER. - PULL TEST PLUG. - REINSTALL DUTCH RISER WITH LUBRICATOR. - BREAK APART AT QTS. - M/U PDS CALIPER LOG TOOLS. TOTAL LENGHT= 19.28' - TEST QTS TO 250/3500 PSI 5 MIN EACH CHARTED. Printed 8/7/2012 2:41:09PM r(") :" 7 '/' ,''' ,..4'. ,, "/ ' /AY 1,? '/ ''; ,i 7 , , :4:i • ,': i`Z ''' , I 'A.:47;f /A ; 4 ,...4..t" ; 1 ',.//// 0 ,'' ,, ,,; 1 , , 7 4 7 -1 , ; -.7,- I, .-' , 4,-.•-' ' // - Ai ,, /#7 " e/ '.1/..M",2"'“*':. •.' *; ' ' '/, ',/ • ' ..,/ , ,x,: ,, • , ,,v ,,,,o/ /./ •, /4 : ,,, ,,,/, / .4 • / ' 1 ,/, / /' "* :' V41,0 * , e ,,,w / ,,,,,, , ; , 4 ,/, , V0 4.4 9s//4 40 ri ,/,t..i jr-/ /- .7 -, ::, i ii,. / ,tr, /' /r; , , # 7 , ,,// , e ; "), /0,M, 41'444, ,/,‘:, I,f. , , ,1 q, 1 , ;/,, , ', ' ' ' ,/ ( , "v 4 ;'0; 2 4/,,1,7;y/ec:/i; it//ofix-r/: 'i,"/- Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:15 - 00:00 0.75 EVAL C DECOMP RIH WITH CALIPER LOG TOOLS. - USE CONTINUOUS HOLE FILL DOWN I/A. - LOSSES TO WELL IN LAST 12 HRS= 50 BBLS 8.5 PPG KWF. - LOSSES TO WELL IN LAST 24 HRS= 152 BBLS 8.5 PPG KWF 7/25/2012 00:00 - 01:30 1.50 EVAL C DECOMP RIH WITH PDS CALIPER LOG TOOLS TO 6480' WIRELINE MD. 01:30 - 03:30 2.00 EVAL C DECOMP LOG UP 50 FPM FROM 6480' - USE CONTINUOUS HOLE FILL. 03:30 - 04:00 0.50 EVAL C DECOMP WAIT 30 MINUTES FOR TOOL TO CLOSE. 04:00 - 06:00 2.00 EVAL C DECOMP L/D LOG TOOLS. - DOWN LOAD DATA FROM PDS LOG TOOL. 06:00 - 07:30 1.50 EVAL C DECOMP MU 4.53" DRIFT ON SLICK LINE. - NOGO AT 398' WIRELINE MD. 07:30 - 11:00 3.50 EVAL C DECOMP WAIT ON PLAN FORWARD FROM RWO ENGINEERING GROUP. - RESULTS FROM PDS LOG. - 09:30 HRS R/D SWS WIRE LINE LUBRICATOR, TILL 10:30 HRS. 11:00 - 15:00 4.00 EVAL C DECOMP WAIT ON TOOLS FROM BAKER TO DRIFT BAD CSG. - WORK ON WORK ORDERS, HOUSEKEEPING. - CLEAN AND CLEAR RIG FLOOR. REMOVE CANNON CLAMPS FROM FLOOR. - COMPLETE STATE BOILER INSPECTION ON #1 BOILER WITH STATE REP. - BAKER TOOLS ARRIVED ON LOCATION AT 15:00 HRS. 15:00 - 15:15 0.25 EVAL C DECOMP PJSM ON PICKING UP BAKER TOOLS. - WSL, BAKER REP., RIG CREW IN ATTENDANCE. - COVER PLAN FORWARD WITH CREW. 15:15 - 19:30 4.25 EVAL C DECOMP WAIT ON PLAN FORWARD FROM TOWN BEFORE PROCEEDING WITH WELL OPS. - REVIEW PLAN FORWARD TO SUSPEND OPERATIONS ON MPE -30. - PERFORM DDI WORK ORDERS WHILE WAITING. - DECISION MADE FROM TOWN WITH APPROVAL FROM ODE AND RWO FIELD SUPERINTENDANT. - MAKE A 4.367" DRIFT RUN TO 450' PRIOR TO RUNNING 4.312" CEMENT RETAINER ON 2 3/8" WTS-6 WORKSTRING. - NOTIFY SLB FOR CEMENT REQUIRMENTS. - USE CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER. - WELL CONTINUES TAKING 8 -9 BPH. Printed 8/7/2012 2:41:09PM � r 0 .. , .„.... ,,„,,,, 7 *„,.: .,../ ., , ,,-7 i //*<-7 - '''.,;-: -,;-, ',,,,,.. 47 ;tr .f ,'•• ,.: ,,,, ii ,, 4 i;447 -•9; , 7' . 3, -34 4; / "/"/,'" ' ' //' -.:-;./ 4y /',: ,1 4 ,K . : X)," .1 / ',/i>,,O, ,, Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 EVAL C DECOMP NOTIFY BTT OF PLAN FORWARD. - BAKER PREPARE 4.367" DRIFT TO SIMULATE CEMENT RETAINER. - INSTALL WEAR RING. - PERFORM DDI WORK ORDERS WHILE WAITING. - USE CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER. - BAKER TOOLS ON LOCATION AT 00:00 HRS. - LOSSES TO WELL IN LAST 12 HRS = 113 BBLS 8.5 PPG SEAWATER. - LOSSES TO WELL IN LAST 24 HRS= 203 BBLS 8.5 PPG SEAWATER. 7/26/2012 00:00 - 01:30 1.50 EVAL C DECOMP LOAD BAKER TOOLS ONTO RIG FLOOR. - R/U DDI TORQUE TURN EQUIPMENT. - PJSM FOR M/U DRIFT BHA AND P/U WORK STRING. 01:30 - 02:00 0.50 EVAL C DECOMP M/U DRIFT BHA. - TANDEM 5.5 CSG SCRAPERS WITH BLADES REMOVED, OD= 4.367 ", BIT SUB, XO, DISCONNECT, XO = 11.58'. 02:00 - 03:00 1.00 EVAL C DECOMP RIH WITH DRIFT BHA. - SINGLE IN ON 2 3/8" WTS-6 WORK STRING FROM PIPESHED. - RIH 12 JTS @ 386' P/U WT 46K, S/O WT 40K. - CONTINUE RIH, TAG AT 399' NOGG - P/U WITH NO RESTRICTION. - MAKE ANOTHER ATTEMPT, TAG 399' SET DOWN 3K. NOGO. - P/U WITH NO RESTRICTION. - NOTIFY ODE. 03:00 - 05:00 2.00 EVAL C DECOMP POH, L/D 2 3/8" WORKSTRING AND DRIFT BHA. 05:00 - 07:00 2.00 EVAL C DECOMP WHILE WAITING ON BAKER INFLATABLE 2.5" CEMENT RETAINER. - P/U 2 -3/8 WTS -WORK STRING FROM PIPE SHED - AND RIH (13 JTS) AND DRIFT TO 428' MD WITH A 21 FT. JOINT OF 2 -7/8" TBG, MULE SHOE. - FREE TO PASS. NO TIGHT SPOT ENCOUNTERED. 07:00 - 08:00 1.00 EVAL C DECOMP PJSM POH F/428' MD. - POH L/D WORK STRING AND MULE SHOE. 08:00 - 09:00 1.00 EVAL C DECOMP WAITING ON BAKER INFLATABLE 2.5" PACKER. 09:00 - 12:00 3.00 ZONISO C DECOMP M/U 2.50" BAKER INFLATABLE CEMENT RETAINER. - MODEL # H34020, SER # 3402019030 - PJSM - SINGLE IN ON 2 -3/8" WTS-6 WORK STRING FROM PIPE SHED TO 2574'. - LOSSES TO WELL IN LAST 12HRS= 100 BBLS. - WELL TAKING 8 BPH. - USE CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER. Printed 8/7/2012 2:41:09PM ;7,7 ',.: / ,x � /.Fc� ��i'.'o / • - / + � / j �� f / q . ® /44 • t:/i r. w / e // i Y'/ .�' e t .ate %. / ". f` '%, i,.r� " ..'//.&�;_ r,ft Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 17:00 5.00 ZONISO C DECOMP CREW CHANGE. PJSM FOR P/U TBG. - CONTINUE RIH WITH 2.5" BAKER INFLATABLE RETAINER BHA. - SINGLE IN ON 2 -3/8" WTS-6 WORK STRING FROM PIPE SHED. - RIH FROM 2574' TO 6473'. - USE CONTINUOUS HOLE FILL. 17:00 19:00 2.00 ZONISO C ■- DECOMP MONITOR WELL, CONTINUES TAKING 8 BPH. - R/U SLB CEMENTERS. - R/U FOSV, HEADPIN AND LINES. 19:00 - 20:50 1.83 ZONISO C DECOMP PJSM WITH BAKER REP FOR SETTING RETAINER. - BREAK CIRCULATION. - PUMP 1 BPM 400 PSI AND FLUSH RETAINER SET AREA WITH 10 BBLS. - SHUT DOWN PUMP. - P/U WT 66K. S/0 WT 59K. - 19:15 DROP 1/2" STEEL BALL. - PUMP BALL ON SEAT 1 BPM 200 PSI. - STAGE UP AND PUMP 500 PSI FOR 10 MINUTES. - INCREASE PUMP TO 1000 PSI, SHEAR AT 1000 PSI. - PUMP PRESSURE DECREASE .5 BPM @ 120 PSI. - SET DOWN 2.5K. RETAINER SET AT 6470' 20:50 - 21:00 0.17 ZONISO C DECOMP PUMP AND ESTABLISH INJECTION RATES. - 1 BPM 320 PSI. 2 BPM 990 PSI. 3 BPM 2080 PSI. 3.5 BPM 2940 PSI. - SHUT DOWN PUMP. - NOTIFY ODE OF INJECTION RATES. 21:00 - 21:30 0.50 ZONISO C DECOMP PJSM FOR PUMPING CEMENT. - REVIEW DDI SOP FOR CEMENT JOB WITH RETAINER. - SLB, WSL, TOOL PUSHER, BAKER REP, MI, CREW, SCS, VAC TRUCK DRIVER IN ATTENDANCE. 21:30 - 00:00 2.50 ZONISO C DECOMP PUMP CEMENT PLUG AS PER PLAN. - PUMP 5 BBLS WATER, PT LINES TO 250/4000 PSI 5 MIN EACH CHARTED. - 22:55 BATCH 60 BBLS 15.8 PPG CLASS G PLUG CEMENT. TAKE CEMENT SAMPLE. - 23:10 WITH SLB PUMP 60 BBLS CEMENT FOLLOWED WITH 5 BBLS WATER 2 BPM 1000 PSI. - PUMP 2 BPM 1000 PSI, INCREASING TO 2.8 BPM 2150 PSI. - WITH CEMENT AT RETAINER PUMP 2.5 BPM 2600 PSI - PUMP 55 BBLS CEMENT BELOW RETAINER. - USE RIG PUMP AND DISPLACE CEMENT WITH 12 BBLS 8.5 PPG SEAWATER. - UNSTING WITH 9K OVERPULL, P/U 3' - LET REMAING 5 BBLS CEMENT FALL ABOVE RETAINER WHILE R/D HEADPIN AND CIRCULATING LINES. -CIP @23:40 - LOSSES TO WELL IN LAST 12 HRS= 100 BBLS 8.5 PPG SEAWATER. - LOSSES TO WELL IN LAST 24 HRS= 74 BBLS 8.5 PPG SEAWATER. Printed 8/7/2012 2:41:09PM ' . 4" •-.4, "1/ 1 f'%;;' " 0 ' //'::'•••••4//:' i-*9 ( ; 4. 1 /4 4; V' 7''', ; ',7 '.,,' , / /; / ,,,,,/,, i ,/“, '. 2-7 :7 ,0 4 "'/ .* t A * " :.- 4 . '4,// - '• ( " :, '" * ".•;' 1 4 , ,,XA.44:al ;fr• •,,,,, /4, 4 4- xi/ /1 Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table ©57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/27/2012 00:00 - 00:30 0.50 ZONISO C DECOMP POH UD 15 JTS FROM 6470' TO 6039' - EST TOC @ 6255' 00:30 - 01:30 1.00 ZONISO C DECOMP R/U AND REVERSE CIRCULATE 3.5 BPM 2700 PSI. - REVERSE OUT DRILL PIPE VOLUME PLUS 10 BBLS. - NO CEMENT RETURNS NOTED. - CHECK FOR TRAPPED PRESSURE. OPEN ANNULAR. - WELL STATIC WITH NO LOSSES. 01:30 - 08:00 6.50 ZONISO C DECOMP PJSM. POH FROM 6039' - UD 2 3/8" WTS-6 WORKSTRING. 08:00 - 08:30 0.50 WHSUR C DECOMP PJSM, PULL WEAR RING - B/O XO'S AND RUNNING TOOLS. 08:30 - 10:00 1.50 ZONISO C DECOMP TEST CEMENT RETAINER W/ 5 BBL CEMENT ON TOP. - R/U TEST EQUIPMENT. - CLOSE BLIND SHEAR RAMS. - PUMP 1.1 BBLS SEAWATER TO TEST PRESSURE. - 1500 PSI FOR 30 MINUTES- TEST PASSED. - WELL CONTROL BARRIERS ARE TESTED CEMENT RETAINER SET AT 6470' 10:00 - 10:30 0.50 ZONISO C DECOMP PERFORM RIG SERVICE - GREASE TOP DRIVE. - RECEIVE APPROVAL TO PROCEED, FROM WTL. 10:30 - 13:30 3.00 ZONISO C DECOMP RUN KILL STRING - M/U 25 FT. MULE SHOE (2 -3/8" TBG. - SINGLE IN HOLE FROM PIPE SHED WITH 2 -3/8 ", 4.7# , EUE TBG. - RIH TO 2220' MD. WITH KILL STRING. 13:30 - 14:00 0.50 ZONISO C DECOMP RIG UP TO CIRCULATE AT 2220' MD. - ESTABLISH CIRCULATION DOWN 2 3/8" TBG. VIA TOPDRIVE USING RIG MP. - SLOW PUMP RATES ARE- - 1 BPM @ 60 PSI. 2 BPM @ 190 PSI. 3 BPM @ 390 PSI. 14:00 - 15:00 1.00 ZONISO P DECOMP PJSM ON MAKING UP AND LANDING HANGER. - WSL, TOOLPUSHER, CAMERON REP, AND RIG CREW IN ATTENDANCE. - MAKE UP TBG HANGER TO 2 3/8" TBG AND LAND WITH 2 3/8" LANDING JOINT. - ORIENT TBG HANGER TO CAMERON REPS SPECIFICATIONS. - RILDS. - NEXT WELL WILL BE MPE -14 NOT MPE -31. 1 PREP -WORK STARTS ON WELL CELLAR AND 1 WIRE LINE STATIC. - WEEKLY CREW CHANGE FROM TOWN. 15:00 - 16:00 1.00 WHSUR P DECOMP TWC TESTED FROM BELOW TO 250 PSI, 1000 PSI FROM 30 CHARTED MINUTES. - 250 PSI, 3500 PSI FOR 5 CHARTED MINUTES EACH, FROM ABOVE. 16:00 - 16:30 0.50 WHSUR P DECOMP BLOW DOWN LINES, DRAIN BOP Printed 8/7/2012 2:41:09PM • 'Mtg., <7 Ar !,, % ' i, ; " "` ✓ ,/,4 4 , /� . ,.?. Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 17:30 1.00 WHSUR P DECOMP BARRIERS IN PLACE. TESTED TWC AND HANGER SEALS, TESTED PLUG AND KWF. - PJSM FOR C/O RAMS AND N/D BOP AND N/U ADAPTOR FLANGE AND TREE. - REMOVE 2 3/8" PIPE RAMS ON LOWER BOP - INSTALL 2 7/8" X 5" VBR. 17:30 - 19:30 2.00 WHSUR P DECOMP N/D BOPE. 19:30 - 21:00 1.50 WHSUR P DECOMP WITH CAMERON REP ATTEMPT TO N/U GREY RDS 7 1/16" X 5K ADAPTOR FLANGE AND TREE. - HEAT TRACE DUMMY PENETRATOR ON HANGER WILL NOT FIT IN ADAPTOR FLANGE PORT. - DUMMY PENETRATOR OD .125" TO LARGE TO FIT IN ADAPTOR PENETRATOR PORT. - NOTIFY ODE AND RWO FIELD SUPERINTENDANT. 21:00 - 00:00 3.00 WHSUR X SFAL DECOMP DECISION MADE BY CAMERON TO HAVE ADAPTOR FLANGE PENETRATOR PORT MACHINED. - REMOVE ADAPTOR FLANGE FROM TREE. - TOOL SERVICE NORM TEST ADAPTOR FLANGE. - SEND ADAPTOR FLANGE TO BAKER MACHINE AS PER CAMERON. - WHILE WAITING ON ADAPTOR FLANGE HOLD PJSM TO C/O TUGGER LINE. - C/O SUPER TUGGER LINE. - LAY RIG MATS AROUND S.E. CORNER OF PAD FOR MOVE TO MPE -14. 7/28/2012 00:00 - 03:00 3.00 WHSUR N HMAN DECOMP WAIT ON ADAPTER FLANGE TO BE MACHINED AS PER CAMERON REP AT BAKER MACHINE. - WHILE WAITING LAY RIG MATS AROUND S.E. CORNER OF PAD FOR MOVE TO MPE -14. - PJSM, CUT AND SLIP DRILLING LINE. - PERFORM DDI WORK ORDERS. - 03:00 HRS CAMERON BACK ON LOCATION WITH ADAPTOR FLANGE. - OFF NPT AT 03:00 HRS. 03:00 - 04:00 1.00 WHSUR P DECOMP PJSM, WITH CAMERON REP N/U 2 9/16" TREE. - N/U 7 'V16" X 5K ADAPTOR FLANGE AND 2 9/16" TREE 04:00 - 05:30 1.50 WHSUR P DECOMP CAMERON TEST HANGER VOID TO 250 PSI 5 MIN. - TEST HANGER VOID TO 5000 PSI FOR 30 MIN. CHARTED. PASSED. 05:30 - 07:00 1.50 WHSUR P DECOMP TEST PRODUCTION TREE - WITH DIESEL - 250 PSI / 5000 PSI F/ 5 CHARTED MINUTES. PASSED. 07:00 - 08:00 1.00 WHSUR P DECOMP PJSM, PULL TWC - P/U AND M/U LUBRICATOR - TESTED 250 PSI / 3500 PSI F/ 5 CHARTED MINUTES, PASSED. - PULL TWC. 08:00 - 09:00 1.00 WHSUR P DECOMP SET 2" TYPE 'H' BPV - LUBRICATOR TESTED 250 PSI / 3500 PSI F/ 5 CHARTED MINUTES, PASSED. - SET BPV. Printed 8/7/2012 2:41:09PM r / /mu /,:t.s;',/,/,:?/-g//,, , /4 4 , uf.f gr.7, f A- ' ,e /4 4`'/ / / e,A ) / . 0:eite/X04*:"4", // /''' ' i l e/ 1, - ? $74* iio,', 4w . T" ov/://viii/ Ar/ „4:), , ,,,,,-;/ , A fe.7!: F r Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 End Date: 7/28/2012 X4- 00VJV -E: (1,000,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/25/1989 12:00:00AM Rig Release: 7/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @57.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 09:30 0.50 WHSUR P DECOMP TEST BPV - TEST FROM BELOW 250 PSI / 1000 PSI - FOR 10 CHARTED MINUTES. PASSED. 09:30 - 12:00 2.50 WHSUR P DECOMP BLOW DOWN LINES - SECURE TREE VALVES. - CLEAN FLUID FROM PITS. - CHARTED SAFETY CRITICAL EQUIPMENT. (BELOW). - TEST KILL LINE 250 PSI / 5000 PSI F/ 10 MINUTES. - PERFORM FACE TO FACE HAND OVER WITH MPU WELL OPS, OF MPE -30. - COMPLETE WELL WORK TRANSFER FORM WITH PAD OPERATOR ON MPE -14. - ALL VALVES SECURED. -RIG RELEASED AT 12:00 HRS FOR MOVE TO MPE -14. I I Printed 8/7/2012 2:41:09PM Tree: 2 9/16" - 5M • M P U E -3 O Orig. 1ev. = 57.0' (N 27E) Wellhead: 7" 5M Varco ADRS -7 Orig. GL Elev. = 23.2' Weld on style DF to 7" csg. hng. = 33.6' (N 27E) Tbg. Hng: 7 1/16" 5M X 2 3/8" EUE W 2" Type H BPV ppf L -80 Btrc. 7 "x 5.5" X -Over 1117' and 13 3/8" 72 ppf, L -80 115' KOP @ 500' Max. hole angle = 69 to 73 deg. from 3950' to 5850' Hole angle thru' perfs = 73 deg. 0 5.5" Port CollarCementer 1336' and 5.5' 15.5 ppf, J -55, Btrc. prod. casing (drift ID = 4.825 ", cap. = 0.0238 bpf) (cap. w/ 2 3/8" tbg inside = 0.0183 bpf) 5.5" Casing collapsed at 400' 2 3/8" 4.6# ppf, L -80, 8 rd EUE tbg. (drift ID = 1.995 ", cap. = 0.00387 bpf) 2 -3/8" 4.6 #, L -80 EUE 8rd Tbg Mule Shoe 1 - l Two 5.5" x 20' short jts. f/ 6320' to 6359' and Cement Retainer 6470' and Pumped 60 BBL cement plug © 6511' (4.5" od. scoop guide ) 4.5" GS profile 5.5" Baker whipstock top © 6657' r E -30a L -1 ( north lateral ) Window 6658' - 666 •b�• :;; Pre- Drilled 4 spf 2 -3/8 ", 4.43 f /# L -80 stl & f143 RA @ 6666' �::;;•;:; TOL @ 6673' Liner @ 9290' Line = 9170' ( I 4.6" GS profile 5.5" Baker whipstock @ 6737' E -30a (south lateral ) Window 6738' - 6744' Pre Drilled 4 spf RA@ 6746' 2 -7/8", L -80 stl 6.16 #, EZSV @ 6754' W/ Cement below ;; pbtd @ 8,626' Liner = 8,291' OA/ OB Sands - Limited entry free w/ 119.6 M# ! ! :e of PropLoked 16/30 Badger prop. behind pipe. 'OA' Sand S4z'd 33/8" 0.6 6758' -6778' (4475'- 4484') u••••••n•••••.u•••.•• OB' Sand 3 3/8" 2 6845' - 6865' (4523' - 4560') 5.5" float collar (PBTD) 7086' and 5.5 "float shoe 7169' and DATE REV. BY COMMENTS MILNE POINT UNIT 10/20/98 MDO Completion w/ heat trace 4 ES WELL E -30A 05/21101 MDO Sidetrack 3 -S and completion 4 -ES API NO: 50- 029 -22903 11/19/05 MOO ESP RWO 4 -ES Change tree size 10/02/07 REH ESP RWO by 4ES 7/31/12 AAR Doyon 14 suspended well BP EXPLORATION (AK) • • r ficA 4 t p _ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 L PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader a 0 0 17 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPE -30AL1 Sundry Number: 312 -287 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r • Cath P. Foerster Chair DATED this day of July, 2012. Encl. $LAMED 01 al2 STATE OF ALASKA -v 0v g ECEIVED Alt OIL AND GAS CONSERVATION COMMTSSION 2 012 APPLICATION FOR SUNDRY APPROVAL JUL 6 2 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ® Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 201 -017 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: 1 P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22903 -60-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPE -30ALI Spacing Exception Required? ❑ Yes 0 No 9. Property Designation: 10. Field / Pool(s): ADL 025518 & 047438 Milne Point Unit / Schrader Bluff 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9290' 4481' 9290' 4481' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 13 -3/8" 120' 120' 4930 2670 Surface 6624' 5 -1/2" 6658' 4413' 7000 4990 Intermediate Production Liner 2659' 2 - 7/8" 6511' - 9170' 4324' - 4472' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section & Open Hole 6517' - 9290' 4327' - 4481' 2 - 3/8 ", 4.7# L - 80 6477' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 26, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: 7/25/2012 ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: Guy Schwartz ❑WAG ❑ SPLUG El Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Na David Reem Title Engineering Team Leader Prepared By Name /Number Signature c 6, Phone 564 -5743 Date '- /u it 2. Joe Lastufka, 564-4091 Commission Use Only / 3\ C on itions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance /Jo i.-.1c e + tr✓ .c.s i o. J : c Other: .� J 7 =n s Subsequent Form Required: 1 0 — LI d APPROVED BY Approved By: P COMMISSIONER THE COMMISSION Date - 7 - 3/— / L Form 10 -403 Revised 0010Q� RB[)IVIS AUG 1 2012 Submit In Duplicate °. J� • • by MPE -30 Expense Rig Workover Well Objective: Suspend operations on Well MPE -30 Justification: Doyon 16 rigged up on well MPE -30 to perform an ESP swap. The pump became stuck at 400' while decompleting and eventually pulled apart. The fish was pulled out of hole. A caliper log was run and shows severe buckling from 400' - 412'. It is not known if another completion is able to be run in hole and more importantly there is a risk to future wellbore access. BP requests approval to suspend operations on MPE -30 while a long term plan for the well is developed. Prior to shutdown of operations a cement retainer will be set. Cement will be pumped below the retainer and 200' above. Cementing is a safety precaution due to potential inability to access the lower wellbore if the future. Additionally, KWF (seawater) will be left in the well with a diesel freeze protect cap. A -2,200' kill string will be ran before setting a TWC a surface. This will keep the well in a safe condition while the reservoir team figures out what the long term plan is. This would meet BP's two barrier policy. MASP: 1,470 psi Well Type: Schrader ESP Producer Pad Engineer: Chad Wermager 564 -5257 Intervention Engineer: Sean McLaughlin 564 -4387 • • kip BP Exploration Alaska Inc. MPE -30 Suspend Operations Recommend Sean McLaughlin Date: RWO Engineer Recommend Dave Rhodes Date: ETL Agree Greg Sarber Date: Superintendent Agree Dave Reem Date: ETL Decide Steve Rossberg for Willingham Date: WTL • • MPE -30 Suspension of Workover operations Scope of operations: o Secure the well for suspension o Run a kill string and set TWC Reference Documents: • ETP 10 -60 - Zonal isolation (Section 6.1 - Principles of Suspension) • AOGCC 20 AAC 25.110 (Suspended Wells) Verify Start -up Checklist: ❑ BP Alaska has verbal approval from the AOGCC to proceed with workover suspension operations on MPE -30. ❑ A Sundry request for shut down of operations for MPE -30 and E -30AL1 will be filed with the State ASAP. ❑ Primary and secondary well barriers shall be installed in the wellbore to provide two temporary barriers Issues and Potential Hazards: ➢ Severe buckling at 400' - 412' prevented the cement retainer drift from passing so a inflatable cement retainer will be used. > Next BOP test due 7/29/2012. > KWF = seawater. Current Toss rate is -10 bph Suspension Plan: Initial Well Barrier Elements: Wellbore KWF, BOPE 1. Continue to keep hole full via continuous seawater circulation. > Monitor IA pressures every hour > Monitor loss rate 2. Drift with 4.367" OD to simulate Cast Iron cement retainer. > Done: The drift would not pass the buckled area. 3. Drift with joint of 2 -7/8" tubing > Done: Successful drift. 4. PU a 2.5" BOT Inflatable Cement Retainer and run in on 2 -3/8" WTS -6 work string. ➢ The max OD of the assembly will be the 2 -3/8" PH6 connection (2.88 ") 5. Set the retainer at - 6,500' per BOT instructions. > Target set depth is 10'- 50' above 4.5" liner top. > Document the following barrier information in Openwells • Manufacture, type, and model number • Tool configuration Well: MPE -30 Version: 1 2 Suspend Well • • • Serial number 6. The WSL needs to verify the SLB field test blend has the following parameters before pumping cement: ➢ Fluid Loss: <250mL ➢ Free Fluid: trace or OmL ➢ Thickening Time: 3:30 - 6 hrs at 92 degF ➢ 1,000 -psi compressive strength: 15hrs max 7. RU Schlumberger cementers. PT cement lines to 4,000psi. Pump 60 bbls 15.8ppg Class G cement at - 3 -4bpm. Maximum pump pressure will be 3000 psi. Cement volume = Volume below the retainer (50 bbls), 5 bbls excess, and 200' above (5 bbls). > The void behind the pre - drilled liner is unknown. A conservative estimate of 3.0" OD was assumed. 8. Cement as follows: ➢ 5 -bbls seawater to PT ➢ 60 -bbls 15.8 -ppg Class "G" plug cement ➢ Displace with seawater > Utilize the rig pumps for displacement > Pump 55 bbls of cement below the retainer, unsting from the retainer and pump 5 bbls of cement above. > Record cement -in -place time in openwells. 9. Pull five stands and reverse bottoms up through the headpin. This will keep cement from going across the stack. Pull out of hole laying down the work string. 10. Close blind /shear rams. Test lower barrier to 1,500 psi for 30 charted minutes. Verify pressure test with the WTL before proceeding. Changes to Well Barrier Elements: Wellbore I KWF, BOPE, Cement plug > Notify the state inspector for witness of bottom plug test. ➢ Use the "BPXA STP Wellbore Testing Criteria Calculator ". The latest version is embedded in the Tubular Pressure Testing RP. o WSL and Toolpusher to sign. Attach pressure chart and calculator to OpenWells. 11. Verify no welibore pressure and open B/S rams. 12. Run 2 -3/8" killstring with mule shoe to 2,200'. Well: MPE -30 Version: 1 3 Suspend Well 13. Record circulating rate and pressures, as well as PU /SO weights before landing hanger, on daily operations report. Land Hanger. ➢ Ensure a dummy penetrator is installed in the hanger. 14. Run in lock down screws and test pack off to 5000 psi. 15. Set TWC and test from below to 250 psi low / 1000 psi high for 30 -min. Changes to Well Barrier Elements: Wellbore KWF, BOPE, TWC, Cement plug 16. ND BOPE and NU adapter flange, tubing head adapter, and tree. Changes to Well Barrier Elements: Wellbore KWF, TWC, Cement plug 17. Pressure test tubing head adapter and tree with diesel to 250 psi low / 5,000 psi high for 5 minutes. 18. Confirm MPU Wells Group assumes freeze protect responsibilities after the rig moves off. 19. RDMO Well: MPE -30 Version: 1 4 Suspend Well Tree: 2 9/16" 5M • /� Ori g . Elev. = 57.0' (N 27E) Wellhead: 7" 5M Varco ADRS -7 M P U E -30 W�ri GL Elev. = 23.2' Weld on style DF to 7" csg. hng. = 33.6' (N 27E) Tbg. Hng: 7 1/16" 5M X 2 3/8" EUE W 2" Type H BPV 7" 26 ppf L -80 Btrc. I 7 "x 5.5" X -Over 117' and 13 3/8" 72 ppf, L -80 115' 126' KOP @ 500' Proposal to Max. hole angle = 69 to 73 deg. from 3950' to 5850' Suspend Well Hole angle thru' perfs = 73 deg. • 5.5" Port CollarCementer 1336' and 5.5" 15.5 ppf, J -55, Btrc. prod. casing (drift ID = 4.825 ", cap. = 0.0238 bpf) 2-3/8" kill string to 2200' (cap. w/ 2 3/8" tbg inside = 0.0183 bpf) 2 3/8" 4.70" ppf, J -55, 8 rd EUE tbg. (drift ID = 1.901 ", cap. = 0.00387 bpf) 200' of cement above retainer Two 5.5" x 20' short jts. f/ 6320' to 6359' and C Cement Retainer set at 6500' Cement plug below the retainer TOL @ 6511' (4.5" od. scoop guide ) ° 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' .... Window 6658' - 666 .: Pre - Drilled 4 spf "' � " 2 -3/8 ", 4.43 fV# L -80 stl & 843 RA @ 6666' V•• -t � WA__ )!.! :•. _ .. 1 : .:.' )t Tl t) /✓t ® pbtd @ 9290' TOL © 6673' (05(' -7I3to) Liner = 9170' I1 1 4.6" GS profile E -30a ( south lateral ) 5.5" Baker whipstock © 6737' Window 6738' - 6744' Pre - Drilled 4 spf RA @ 6746' . 2 -7/8 ", L -80 stl 6.16 #, EZSV @ 6754' W/ Cement below S^.oV60 isiKe -- pbtd @ 8,626' • 1 04 - 12 510 :i Liner = 8,291' OA / OB Sands - Limited entry frac w/ 119.6 M# ! 1 n of PropLoked 16/30 Badger prop. behind pipe. & 4 'OA' Sand S9z'd t:�•::::::i:.•::O::ietVe; 3 3/8" 0.6 6758' - 6778' (4475' - 4484') . �.....nW ............. 'OR' Sartd 3 3/8" 2 6845' - 6865' (4523' - 4560') 5.5" float collar (PBTD) 7086' and 5.5 "float shoe 7169'md DATE REV BY COMMENTS MILNE POINT UNIT 08/05/98 JBF Drilled and Cased by Nabors 27E WELL E- 30A /N 10/20/98 MDO Completion w/ heat trace 4 ES API NO: 50-029-22903 05/21/01 MDO Sidetrack 3 -S and completion 4 -ES Oft _ '/P4,1 ; 5a - om- 1,2903 ^(o0 -A0 11/19/05 MDO ESP RWO 4 -ES Change tree size 10/02/07 REH ESP RWO by 4ES BP EXPLORATION (AK) Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, July 25, 2012 4:53 PM To: 'McLaughlin, Sean M' Cc: Roby, David S (DOA) Subject: RE: MPE -30 suspend operations (PTD 201 -011 and 201 -017) Sean, You have verbal approval to suspend the well as you show on the attached schematic with a cement retainer. The caliper log shows some very severe buckling and it is prudent to secure the well now while you have access to the lower part of the wellbore. Pressure test the cement plug to 1500 psi (min) and chart to document. A 10-403 (please submit sundries for both E -30A and E- 30AL1) should be submitted with the full procedure tomorrow or as soon as possible. As we discussed the RWO was originally not under a sundry operation since you were pulling and replacing an ESP. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Wednesday, July 25, 2012 4:27 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Lastufka, Joseph N (Northern Solutions) Subject: MPE -30 suspend operations Guy, Please see the attached documents for the justification and schematics to suspend operations on MPE - 30. I'm currently working on a detailed plan. I would like verbal approval to proceed with securing the well with a cement retainer and cement plug. Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 7/26/2012 Tree: 2 9/16" - 5M • . Elev. = 57.0' (N 27E) - MPU E -30A Orig Orig. Elev. = 23.2' Wellhead: 7" 5M Varco ADRS 7 Weld on style DF to 7" csg. hng. = 33.6' (N 27E) Tbg. Hng: 7 1/16" 5M X 2 3/8" EUE W 2" Type H BPV 7" 26 ppf L - Bt r c . 7 "x 5.5" X -Over 117' and 13 3/8" 72 ppf, L -80 115' KOP 500' 71. 126' @ T 3 l Max. hole angle = 69 to 73 deg. from 3950' to 5850' Q re II Hole angle thru' perfs = 73 deg. ") 5.5" Port CollarCementer 1336' and 5.5' 15.5 ppf, J -55, Btrc. prod. casing (drift ID = 4.825 ", cap. = 0.0238 bpf) 2 - 3/8 °' kill string to 2200° (cap. w/ 2 3/8" tbg inside = 0.0183 bpf) 2 3/8" 4.70" ppf, J -55, 8 rd EUE tbg (drift ID =1.901", cap. = 0.00387 bpf) 200' of cement above retainer Two 5.5" x 20' short jts. f/ 6320' to 6359' and / i I Cement Retainer set at 6500' ( / //1 L. Cement plug below the retainer TOL @ 6511' ( 4.5" od. scoop guide) I 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' r Window 6658' - 666 Pre- Drilled 4 spf :; •• 2 -3/8 ", 4.43 ft/# L -80 stl & fl43 RA @ 6666' :•'',:::,:;•:::: pbtd @9290' TOL @ 6673' Liner = 9170' I I 4.6" GS profile E-30a ( south lateral ) 5.5" Baker whipstock @ 6737' - Window 6738' - 6744' Pre - Drilled 4 spf RA @ 6746' 2 -7/8 ", L -80 stl 6.16#, - EZSV @ 6754' W/ Cement below pbtd @ 8,626' '.II Liner = 8,291' OA / OB Sands - Limited entry frac w/ 119.6 MS as of PropLoked 16/30 Badger prop. behind pipe. It1 AuAuu •• 'CIA' Sand Sga'd 3 3/8" 0.6 6766' - 6778' (4476' - 4484') ' • ' • ' 'oB'Sand 3 3/8" 2 6846' - 6865' (4623' - 4660') 6.5" float collar (PBTD) 7086' and 6.6 " float shoe 7169' and DATE REV. BY COMMENTS MILNE POINT UNIT , 08/05/98 JBF Drilled and Cased by Nabors 27E WELL E -30A 10/20/98 MDO Completion w/ heat trace 4 ES API NO: 50 -029 -22903 05/21/01 MDO Sidetrack 3 -S and completion 4 -ES 11/19/05 MDO ESP RWO 4 -ES Change tree size . 10/02/07 REH ESP RWO by4ES BP EXPLORATION (AK) 1 - - • o. . ,.. I... i 2 0 a ..,. . :,.., , . -4.40'411.' 1 . 'Pt . • . , . „ . .. ,,,.-.. .., .... , ..„ _. . .... ... - . . ..._ - .,.. 4:$ . 17:2 O . a ol al , o si: .i. • '-0, . oa ez LA 4 ? e., A6 e i e; o To. ' - Page 1 of 1 • • Schwartz, Guy L (DOA) mPLT 30 AL( From: Schwartz, Guy L (DOA) � t - 017 Sent: Thursday, December 29, 2011 1:34 PM To: 'McLaughlin, Sean M' Cc: Hubble, Terrie L; Colombie, Jody J (DOA) (jody.colombie @alaska.gov) Subject: RE: Sundry for MPE- 30A&AL1 (311 -384 and 311 -383) Sean, We will withdraw the sundries ( 311 -384 and 311 -383) as requested. Guy Schwartz adthibiEDEP atiZ Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Wednesday, December 28, 2011 2:53 PM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L Subject: Sundry for MPE- 30A&AL1 (311 -384 and 311 -383) Guy, BP would like to cancel the Sundry for MPE -30A and AL1 (311 -384 and 311 -383). After removing a wellhead clamp and blue goo we have determined that there is not enough wellhead exposed to install a sliplock wellhead as planned. A wellhead install would involve excavation and cutting conductor. If there is a pup below the wellhead we would need to drill down then build up the wellhead back up to grade. The planned swap was for aesthetics rather than a BP compliance issue and a swap would create risk. Given the recent information, operational complexity, and uncertainty of a wellhead swap BP has decided not to pursue it. Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 12/29/2011 • • [ a' [rc SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 j,,b1 -01 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Pool, MPE -30AL1 Sundry Number: 311 -383 Dear Mr. Reem: spa Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, °4 Daniel T. Seamount, Jr. Chair DATED this Z. 'day of December, 2011. Encl. il STATE OF ALASKA ‘y 7 RECEIVED ; ALASKA lL AND GAS CONSERVATION COMMISSION S d ` a ,� ,, APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Q1 & Co s. CI?t:�x,�e�ss�� 1. Type of Request: r nefe??f'Pri ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Replace Failed ESP 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 201 - 017 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 22903 - 60 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPE -30AL1 Spacing Exception Required? ❑ Yes ® No 9. Property Designation: . 10. Field / Pool(s): ADL 025518 & 047438 Milne Point Unit / Schrader Bluff • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9290' • 4481' . 9290' 4481' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 13 -3/8" 120' 120' 4930 2670 Surface 6624' 5 -1/2" 6658' 4413' 7000 4990 Intermediate Production Liner 2659' 2 - 7/8" 6511' - 9170' 4324' - 4472' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section & Open Hole: 651T - 9290' 4327' - 4481' 2 - 3/8 ", 4.7# L - 80 6477' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 15, 2012 0 Oil • ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Na David eem Title Engineering Team Leader Prepared By Name /Number. Signature Phone 564 - 5743 Date /2– 1 3 - Z0 // Terrie Hubble, 564 -4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 21 l I _ �� Sundry Number: `J f ❑ Plug Integrity c I pit_BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: ' SO O s4 46d !� t.3 I d e -,► 6r.. It/e./l!fta•r..y 1 0 4 441141-7.6-1,,. . Subsequent Form Required: / U _ L/ 0 1 APPROVED BY Approved By: , pi A - COMMISSIONER THE COMMISSION Date 1 2 127 / 1) Form 10-403 Revised 01/20f0'0D DEC 2 8 2011 Submit In Dupli I � 0 ORIGINAL ,..€ ,, vfo . • BP Exploration Alaska Inc. bp • MPE -3OA Rig Workover (ESP Swap, Replace Wellhead) Scope of Work: Swap ESP and replace wellhead . Engineer: Sean McLaughlin MASP: 807 psi Well Type: Producer Estimated Start Date: January 15, 2012 W 1 Check all lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. S 2 Ensure DGLV in top station at 126', Pull DGLV from bottom station at 6280' to allow circulation for RWO S 3 Caliper 2 -3/8" tubing S 4 SBHPS — prior to rig arrival ✓ 5 Set a BPV in the tubing hanger. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate seawater. 2. Pull and LD ESP completion. 3. RU slick line and run casing caliper to 6500'. - � F ; c4.s"� - °( ps 4. Run test packer to 6500'. Test Casing to 1.2X the SICP. L 5. Set storm packer —60'. Test storm packer to 1000 psi. �D c _c�,,,..„t� 6. Cut off wellhead and install new sliplock wellhead. ---"? 7. NU BOPE and test the break to 3500 psi 8. Pull storm packer, Release and pull test packer. 9. Run ESP completion 10. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. 1 , ‘ Tree: 2 9/16" 5M Orig. DF Ale 57.0' (N 27E) Wellhead: 7" 5M Varco ADRS -7 M PU E -30A Orig. GL Elev. = 23.2' Weld on style $ DF to 7" csg. hng. = 33.6' (N 27E) Tbg. Hng: 7 1/16" 5M X 2 3/8" EUE W 2" Type H BPV ppf L -80 Btrc. 0 7"x 5.5" X -Over 1 117' and I 13 3/8" 72 ppf, L -80 115' 0 :'_ 1 / I 1 Camco 2 3/8" x 1" KOP @ 500' 0 sidepocket KBMG GLM 126' Max. hole angle = 69 to 73 deg. 0 from 3950' to 5850' 0 Hole angle thru' perfs = 73 deg. 0 0 0 0 5.5 Port CollarCementer 1336' and 0 Centrilift heat trace @ 3240' 5.5' 15.5 ppf, J -55, Btrc. prod. casing 0 ( drift ID = 4.950 ", cap. = 0.0238 bpf) 0 % ' 2 3/8" 4.70" ppf, J -55, 8 rd EUE tbg 0 ( drift ID = 1.995 ", cap. = 0.00387 bpf) 0 Camco 2 3/8" x 1" 0 ,, sidepocket KBMG GLM I 6,280' 0 2 -3/8" HES XN- Nipple I 6,356' 1 11 1 (1.875" polish bore, 1.791" No-go ) Centrilift Upper tandem 6,399' E .� PMSXD 1:6 35 P 10; � _ PMSXD 1:6 192 P 10 0 II Centrilift Lower Tandem 0- FPMSSD 1:4 27 G 12 j „ Gas Separator: 6,433' FRSTX FER NH6 AR mut Centrilift Tandem seal Section FSB3DBUTFERSB /SBPFSA 6,438' Me FSB3DBH6FERSSCVHLSB /SB Two 5.5" x 20' short jts. f/ 6320' to 6359' and Centrilift Motor: I 6,450' I Am FMHG 132hp./2220 volt/39 amp T It 1 Centrilift DH Sensor XTO 6,473' Centralizer I 6,475' \ TOL @ 6511' (4.5" od. scoop guide ) n 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' Window 6658' - 666 ' Pre- Drilled 4 spf `• 2 - 3/8 " , 4.43 f /# L - 80 stl & f143 RA @ 6666 :: i }' rrt ; ; pbtd @ 9290' TOL © 6673' Liner = 9170' I I' 4.5" GS profile E -30a ( south lateral ) 5.5" Baker whipstock @ 6737' Window 6738' - 6744' Pre - Drilled 4 spf RA @ 6746' 2 -7/8 ", L -80 stl 6.16 #, EZSV @6754' W/ Cement below pbtd @ 8,626' !! ° Liner = 8,291' OA I 06 Sands - Limited entry frac wl 119.6 MN i i in of PropLoked 16130 Badger prop. behind pipe. a' sana gz'd 3 318" 0.6 • 6758' - 6778' (4S475' - 4484') • ' 1ee's.nd 3 3 /8" 2 6845' -6666' (4623' -4660') 6.6" float collar (PB1D) 7086' and 5.5 "float shoe 7169'md DATE REV. BY COMMENTS MILNE POINT UNIT 08/05/98 JBF Drilled and Cased by Nabors 27E WELL E-30A 10/20/98 MDO Completion w/ heat trace 4 ES API NO: 50 -029 -22903 05/21/01 MDO Sidetrack 3 -S and completion 4 - 11/19/05 MDO ESP RWO 4 - ES Chg. tree size 10/02/07 REH ESP RWO by 4ES BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS . ~'1~ desk oc~~ 1. Operations Performed: ~~ ~~s~ ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development -^ Exploratory 201-017 ~" 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22903-60-00 7. KB Elevation (ft): 57.05' - 9. Weli Name and Number: MPE-30AL1 - 8. Property Designation: ~ 10. Field /Pool(s): ADL Z~jy.3~ ~ p- 3~'° Milne Point Unit / Schrader Bluff - 11. Present well condition summary Total depth: measured 9290 feet true vertical 4481 ' feet Plugs (measured) None Effective depth: measured 9290 feet Junk (measured) None true vertical 4481 feet Gasing Length Size MD TVD Burst Collapse Structural Conductor 84' 13-3/8" 120' 120' 4930 2670 Surface 6624' S-1/2" 6658' 4413' 7000 4990 Intermediate Production Liner 2659' 2-7/8" 6511' - 9170' 4324' - 4472' 10570 11160 Perforation Depth MD (ft): Slotted Liner 6517' - 9136' Perforation Depth TVD (ft): Slotted Liner 4327' - 4471' 2-3/8", 4.7# L-80 647T Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: g3 ~ 23 32 280 177 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ®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 'rf C.O. Exempt: Contact .Frank Roach, 564-4373 NIA Printed Name Sondra Stewman Title Technical Assistant nature Prepared By NamelNumber: Phone 564'-4750 ' • Date ~~"'Z ~"0~ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2 ti Submit Original Only . ~ ~ ~~~i ~ ~oo~ ~ ~ 1 ~ f ~ ~ ~. tai, .~>~ -~ -~~. ~~ s~-~~~ ' Tree: 2 9/16" - 5M Wellhead: 7" 5M Varco ADRS-7 Weld on style Tbp. Hna: 7 1/16" 5M X 2 3/8" EUE W 2" Type H BPV 13 3/8" 72 ppf, L-80 115' KOP @ 500' Max. hole angle = 69 to 73 deg. from 3950' to 5850' Hole angle thru' perfs = 73 deg. MPU E-30 5.5' 15.5 ppf, J-55, Btrc. prod. casing ( drift ID = 4.950", cap. = 0.0238 bpf ) 2 3/8" 4.70" ppf, J-55, 8 rd EUE tbg ( drift ID =1.995 ", cap. = 0.00387 bpf ) Two 5.5" x 20' short jts. f/ 6320' to 6359' 5.5" Baker whipstock top @ 6657' Window 6658' - 66E RA @ 6666' 5.5" Baker whipstock @ 6737' Window 6738' - 6744' RA @ 6746' EZSV @ 6754' W/ Cement below OA / OB Sands -Limited entry trot w/ 119.6 M# of PropLoked 16/30 Badger prop. behind pipe. 'OA• Rv~d Sgx'd 3 316" 0.8 6759' - 6778' (4475' -4464') ,fig, $8pd 3 318" 2 6645' -6865' (4523' - 4560') 5.5" fbat collar (PBTD) 7086' and 5.5 "float etwe 7169'mtl DATE REV. BY COMMENTS 08/05/98 JBF Drilled and Cased by Nabors 27E 10/20/98 MDO Completion w/ heat trace 4 ES 05!21101 MDO Sidetrack 3-S and completion 4-ES 11/19/05 MDO ESP RWO 4-ES Chg. tree size 10/02/OT REH ESP RWO by 4ES Orig.1l~~lev. = 57.0' (N 27E) Orig. GL Elev. = 23.2' DF to 7" csg. hng. = 33.6' (N 27E) 7" 26 ppf L-80 Btrc. 7"x 5.5" X-Over 117' and 5.5" Port CollarCementer 1336' and Camco 2 3/8" x 1" sidepocket KBMG GLM 126' Gentrilift heat trace @ 3240' Camco 2 3/8" x 1" sidepocket KBMG GLM 6,280' 2-3/8" HES XN-Nipple (1.875" id) 6,356' Gentrilift Upper tandem 6,399' PMSXD 1:6 35 P 10; PMSXD 1:6 192 P 10 Gentrilift Lower Tandem FPMSSD 1:4 27 G 12 6 433' Gas Separator: , FRSTX FER NH6 AR Gentrilift Tandem seal Section FS63DBUTFERSB/SBPFSA 6,438' FS63DBH6FERSSCVHLS6/SB Gentrilift Motor: 6,450' FMHG 132hp./2220 volU39 amp O 6,473' Gentrilift DH Sensor XT Centralizer 6,475' TOL @ 6511' (4.5" od. scoop guide ) 4.5" GS profile E-30a L-1 (north lateral ) Pre-Drilled 4 spf 2-3/8", 4.43 ft/# L-80 stl & fl43 c~~c t~ I-.a., ~z ll,;.,i r~-`Ll~.,bntd @ s29o' TOL @6673' Liner = 9170' 4.5" GS profile E-30a (south lateral ) Pre-Drilled 4 spf 2-7/8", L-80 stl 6.16#, ~`2~ ~`~F{' pbtd @ 8,626' D~D~ , - ~ Liner = 8,291' t~i MILNE POINT UNIT WELL E-30A~1L.) BP EXPLORATION • • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPE-30 Common Well Name: MPE-30 Spud Date: 7/25/1989 Event Name: WORKOVER Start: 7!2/2007 End: 10/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/2/2007 Rig Name: NABORS 4ES Rig Number: Date I From - To I Hours I Task I Code I NPT 4 Phase (7/2/2007 120:00 - 00:00 7/3/2007 00:00 - 03:00 03:00 - 04:30 04:30 - 11:00 4.00 I RIGD I P 3.00 RIGD P 1.50 {MOB I P 6.501 RIGU P 11:00 - 00:00 I 13.00 I RIGD ( C 9/28/2007 03:00 - 11:00 8.00 MOB P 11:00 - 13:00 2.00 RIGU P 13:00 - 13:30 0.50 RIGU P 13:30 - 14:00 0.50 RIGU P 14:00 - 14:30 0.50 RIGU P 14:30 - 16:30 2.00 RIGU P 16:30 - 17:30 ~ 1.00 ~ KILL ~ P 17:30 - 18:30 1.00 KILL P 18:30 - 19:00 0.50 KILL P 19:00 - 20:30 I 1.501 KILL I P 20:30 - 21:30 I 1.00 ~ KILL I P 21:30 - 22:00 0.50 WHSUR P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 WHSUR P 9/29/2007 00:00 - 00:30 0.50 WHSUR P 00:30 - 01:00 0.50 BOPSU P 01:00 - 03:30 2.50 BOPSU P 03:30 - 07:00 3.50 BOPSU P 07:00 - 08:30 I 1.501 BOPSUF~ P 08:30 - 09:30 1.00 PULL I P Description of Operations PRE Rig down off of well slot MPJ-24. Lower and scope Derrick. PRE Continue RD of Modules off of well slot MPJ-24. Back Carrier off of well with Pad Operator, WSL and Tourpusher present. PRE Move the Rig and Modules from MPJ-24 to MPE-30. PRE Arrive on MPE-Pad. Spot the Camp, Shop and Generator at the entrance of the Pad. Spot the Carrier, Pits and Pipe Shed Modules in front of well slot MPE-30. Attempt to RU on the well and no way to get the Pipe Shed to mate up with the Carrier. Have tried behind MPE-05 and in front of MPE-05 - no joy. Discuss with Anchorage Engineering. The possibility of doing the workover without the Pipe Shed was explored. General consensus that going to another well is the safest route. MPK-06 is the contingency well. POST Service & repair rig. Received orders from Anchorage to move to MPL-06. Moved off location @ 22:00 hrs. Final daily report. PRE Move Nabors 4ES rig from MPF-57A to MPE-30A. PRE Spot sub, pipe shed and pits. PRE PJSM: Raise and scope derrick. All crew. PRE Raise derrick to half mast. PRE Prep to scope derrick. PRE Hook up lines to circulate well. P/T lines to 3500-psi. Accept rig @ 15:00-hrs. DECOMP PU lubricator and P/T same to 500-psi. No leaks. Pull BPV. Lay down lubricator. DECOMP Take on 130 degree seawater. DECOMP Hold PJSM & Pre-spud meeting w/ all hands. Pressure test lines to 3600 psi. DECOMP Open well. SITP = 160 psi, SIAP = 40 psi. Equalize well & bleed off pressures to 0 psi. Circulate & kill well. Pump 3 BPM, Pump pressure went from 790 psi to 880 psi. Pumped 205 bbls. Recovered 156 bbls (-75% oil). Had good clean seawater returns. S/D TP & AP dropped to 0 psi. Open well, tubing & annulus on vacuum. DECOMP Monitor well. R/D lines. DECOMP Set TWC per Cameron Rep. DECOMP Pressure test TWC. Test from top w/ 3500 psi,for 10 min Ok. Test from bottom by pumping 3 BPM for 10 min. Max pressure = 300 psi. DECOMP R/D test equip. Blow down Tines. Drain tree. DECOMP Bleed hanger void. N/D tree. DECOMP Install DSA & test spool. DECOMP N!U BOPE, Choke & kill lines. DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Annular 250/3500 psi. BOP test witnessing waived by Chuck Sheve w/ AOGCC. DECOMP Rig down and stow BOPE test equipment. Prepare to upland tubing hanger. DECOMP BOLDS. PUMU landing jt. with TIW valve. Screw into tubing Printed: 10/25/2007 1:23:01 PM • • BP EXPLORATION Page 2 of 3 Operations Summary Report - Legal Well Name: MPE-30 .Common Well Name: MPE-30 Spud Date: 7/25/1989 Event Name: WORKOVER Start: 7/2/2007 End: 10/2/2007 (Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/2/2007 'Rig Name: NABORS 4ES Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 19/29/2007 19/30/2007 08:30 - 09:30 ( 1.00 (PULL I P 09:30 - 18:00 8.50 PULL P 18:00 - 18:30 I 0.501 PULL I P 18:30 - 21:30 3.00 PULL P 21:30 - 23:30 I 2.001 PULL I P 23:30 - 00:00 I 0.50 ~ PULL I P 00:00 - 00:30 0.50 PULL P 00:30 - 01:00 0.50 CLEAN P 01:00 - 05:00 I 4.00 !CLEAN I P 05:00 - 06:00 1.001 CLEAN I P 06:00 - 06:30 0.501 CLEAN 06:30 - 09:30 3.00 CLEAN P 09:30 - 10:30 1.00 CASE P 10:30 - 14:00 3.50 CASE P 14:00 - 15:00 1.00 CASE P 15:00 - 18:00 3.00 CASE P 18:00 - 19:00 1.00 EVAL P 19:00 - 20:00 1.00 EVAL P 20:00 - 00:00 4.00 EVAL P 10/1 /2007 106:30 - 08:30 ~ 2.00 ~ EVAL ~ P 08:30 - 09:30 I 1.001 EVAL I P 09:30 - 12:30 ~ 3.00 I EVAL { P 12:30 - 13:00 0.50 EVAL I P 13:00 - 16:00 I 3.00 I EVAL I P 16:00 - 17:00 1.00 EVAL P 17:00 - 18:00 1.00 RUNCO 18:00 - 18:30 0.50 RUNCO 18:30 - 20:00 1.50 RUNCO 20:00 - 00:00 4.00 RUNCO 110/2/2007 100:00 - 06:00 I 6.00 I RU Description of Operations DECOMP hanger and hoist to floor. PUW = 50K. DECOMP POH w/ESP completion standing tubing in derrick. Maintaining double steel displacement while POH in addition to washing off tubing and ESP cable as needed. 87 jts. POH @ 1645-hrs. DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. DECOMP Con't to POOH & stand back 2 3/8" completion. Using double displacement while POOH. Pulled & stood back 67 stands, Lay down 4 singles & 2-10' pups. DECOMP Break out, inspect & L/D ESP. Had 1 1/2' of sand on top of pump. Seal section had water in top seal. Motor checked good. Pot Head on motor lead was broken. Will check cable prior to re-running. DECOMP Clear & clean rig floor. DECOMP Finish clearing & cleaning rig floor. UD elephant trunk. DECOMP M/U scraper assy as follows: Muleshoe, Double Pin Sub, X-O, 5 1/2" Scraper, Bit Sub, X-O. TL = 9.21'. DECOMP RIH w( scraper assy on 67 stands of 2 3!8" tubing. P/U 10 singles & tagged 4-1/2" Scoop Guide @ 6497' 4ES KB. DECOMP Circulate bottoms up. Pump 3 BPM @ 870 psi. DECOMP Crew change. Service rig. Derrick inspection and check PVT alarms. DECOMP POH w/5-1 /2" scraperimuleshoe BHA. 80/LD same. DECOMP PJSM. PUMU Halco 5-1/2" RBP. DECOMP RIH w/5-1/2" RBP and set @ 6,448'. DECOMP P/T RBP and casing to 1500-psi for 30-charted minutes to verify RBP is competent mechanical barrier and verify casing mechanical integrity. DECOMP POH w/5-1/2" RBP running tool. DECOMP Nipple down flow nipple. N/U shooting flange. DECOMP R/U E-line equip. DECOMP RIH & log w/ USIT tools. Could not get deeper than 3989'. Notified town engineerof problem. Con't logging operations from 3989'. DECOMP Con't to tog USIT. Logged from 3985' to surf. Repeat thru areas of corrosion. DECOMP RDMO SWS e-line egpt. and tools. ND shooting flange. NU flow nipple and check for leaks. DECOMP All crew weekly safety meeting. Various topics: Review HiPo's, safety incidents, working at heights and control of work standard. i DECOMP RIH w/5-1/2" RBP retrieving tool on tubing from derrick. ', DECOMP PUMU single jt. w/TIW valve. Tag top of RBP @ 6444' w/retrieving tool. Release RBP. Hole on vacuum. DECOMP POH UD 9jts, tubing 1x1 through pipe shed. POH standing 68 stds. tubing in derrick. LD RBP and retrieving tool. DECOMP Break out & UD RBP & setting tool. Clear & clean rig floor. RUNCMP PUMU Centrilift ESP assembly per running order. RUNCMP Crew Change. Inspect derrick. Check PVT alarms. RUNCMP P/U, MU & service ESP. RUNCMP RIH w/ 2 3/8" ESP as per program. Ran 104 jts. Pump thru pump & check conductivity every 2000'. RUNCMP Con't to RIH w/ 2 318" ESP completion.Began installing Heat trace w! Cannon clamps on jt # 102. M!U torque = 1290 ft-Ibs. Printed: 10/25/2007 1:23:01 PM r • • BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPE-30 Common Well Name: MPE-30 Spud Date: 7/25/1989 Event Name: WORKOVER Start: 7/2/2007 End: 10/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/2/2007 Rig Name: NABORS 4ES Rig Number: Date ~ From - To ~ Hours I Task I Code I NPT I Phase Description of Operations 1012/2007 00:00 - 06:00 6.00 RUNCO 06:00 - 06:30 0.50 RUNCO 06:30 - 12:30 6.00 RUNCO 12:30 - 13:30 1.00 RU 13:30 - 18:30 5.00 RU 18:30 - 19:00 0.50 RU 19:00 - 20:00 I 1.001 WHSUR I P 20:00 - 21:00 1.00 BOPSU P 21:00 - 22:00 1.00 BOPSU P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 I 1.001 WHSUR I P RUNCMP Check conductivity every 2000'. Pump thru pump every 2000', 1 BPM @ 1800 psi. RUNCMP Crew change out, rig maintenance, derrick inspection and checl PVT alarms. RUNCMP RIH w/ 2 3/8" ESP completion. M/U torque = 1290 ft-Ibs. Check conductivity every 2000'. Pump thru pump every 2000', 1 BPM @ 1800 psi. RUNCMP PUMU tubing hanger w/landing joint and TIW valve. Install penetrators in hanger. RUNCMP Make final field splices in ESP power cable & heat trace cable. Ttest & meg splices. Install final Cannon clamp. RUNCMP Land 2 3!8" ESP completion. RILDS. P/U Wt = 50K, S/O Wt = 40K. Ran 56 Single Channel Cannon, Clamps, 90 - 2' Dual Channel Cannon Clamps, 534 - 5' Dual Channel Cannon Clamps, 3 Flat Guards, 5 Protectolizers, 1 Dual Channel HT Camp & 5 - 3!4" SS bands. RUNCMP Install TWC. Test from top w! 3500 psi, OK. Test from bottom by pumping in annulus @ 2 BPM, 200 psi for 10 min. charted same. RUNCMP Drain BOP stack. Change out 2 318" rams for 2 718" x 5" VB Rams. RUNCMP N/D BOPE & DSA. Set stack back & secure. RUNCMP N/U Tree. Alignment Check & approved by Pad Operator. Perform final checks on ESP cable & Heat Trace cable. Fill stack w! diesel & test to 5000 psi. Tested Good. RUNCMP P/U lubricator & test to 500 psi. pull TWC. Install BPV. L!D lubricator. Secure tree. & clean cellar. RELEASE RIG @ 24:00 hrs, 10-2-2007. Printed: 10/25/2007 1:23:01 PM e e £~~, , MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFicbe\CvrPgs _ Inserts\Microfihn _ Marker, doc ,þ. _ STATE OF ALASKA a RECEIVED ALASKAWL AND GAS CONSERVATION C~ISSION . . REPORT OF SUNDRY WELL OPERATIONSJAN 03 2006 Alaska Oil & Gas Cons C /011 ommls 1. Operations Performed: chanlmehbfáijè -- o Abandon o Suspend o Operation Shutdown o Perforate 1m Other o Alter Casing 1m Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 1m Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 1m Development o Exploratory 201-017 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22903-60-00 7. KB Elevation (ft): 57.05' 9. Well Name and Number: MPE-30AL 1 8. Property Designation: 10. Field / Pool(s): ADL Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9290 feet true vertical 4481 feet Plugs (measured) None Effective depth: measured 9290 feet Junk (measured) None true vertical 4481 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 13-3/8" 120' 120' 4930 2670 Surface 6624' 5-1/2" 6658' 4413' 7000 4990 Intermediate Production Liner 2659' 2-7/8" 6511' - 9170' 4324' - 4472' 10570 11160 ~ '«(1' W¡:;'·~~í! F ~i"""l~:\:,)'.,,,,,·L . ,J Perforation Depth MD (ft): 6517' - 9136' Perforation Depth TVD (ft): 4327' - 4471' Tubing Size (size, grade, and measured depth): 2-3/8",4.7# L-80 6469' Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFt .JAN 9 4 7006 13. Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casinn Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 1m Daily Report of Well Operations o Exploratory 1m Development o Service 1m Well Schematic Diagram 16. Well Status after proposed work: 1m Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant Si~:Æ'"' ~ Phone l d. ~ '---prepared By Name/Number: 564-4750 Date - ~ 1--c£; Sondra Stewman, 564-4750 Form 10-404 Revised 04/2004 ORI Submit Original Only GI ~lAL DATE 08/05/98 10/20/98 05/21/01 11/19/05 REV. BY JBF MOO MOO MOO COMMENTS Orilled and Cased by Nabors 27E Completion wI heat trace 4 ES Sidetrack 3-S and completion 4-ES ESP RWO 4-ES Chg. tree size BP EXPLORATION (AK) MILNE POINT UNIT WELL E-30A API NO: 50-029-22903 OA OB Sand. . Limited ontry fro<: w/119.6 M# 01 PropLokod 16130 Bodgot' prop. behind pipe. 3 3IS" O.S 'o6~'~~~77S' ~~. 4484') .:ca:..saød 3 3IS" 6845' . 6865' (4523'·4560') EZSV @ 6754' 5.5" Baker whipstock @ 6737' Window 6738' - 6744' RA @ 6746' WI Cement 5.5" Baker whipstock top @ 6657' Window 6658' - 66E RA @ 6666' 5.5" float con.r (pBTD) 70S6' md 5.5 " floatohoo 7169 ' md Pre-Drilled 4 spf 2-7/8", L-80 stl6.16#, pbtd @ 8,626' Liner = 8,291' 2-3/8" E-30a Pre-Drilled 4 spf 4.43 ft/# L-80 stl & fl43 south lateral pbtd @ 9290' Liner = 9170' 4.5" 4.5" E-30a L-1 north lateral Two 5.5" X 20' short ts. fl 6320' to 6359' md @ 6511 00. scoop guide GS profile PumpMate Centralizer Centrilift Upper tandem 124 stage FC925 FPMTAR 1:1 Centrílift Lower tandem 21 stage FCNPSH FPMTAR 1:1 Centrilift 400 series Tandem gas section FRSTXAR 23/8" 4.70" ppf, J-55, 8 rd EUE tbg drift 10 =1.995 ", cap. = 0.00387 bpf ) 2-318" Camco 2 3/8" x 1" sidepocket KBMM GLM HES XN-Nippie .875" id I , , 5.5' 15.5 ppf, J-55, Btrc. prod. casing ( drift 10 = 4.950", cap. = 0.0238 bpf ) Centrilift heat trace @ 3240' 5.5" Port Collar Cementer I 1336' md I KOP @ 500' Max. hole angle = 69 to 73 deg. from 3950' to 5850' Hole angle thru' perfs = 73 deg. ... 133/8" 72 ppf, L-80 I 115' I ~ 2 9/16" - 5M . Wellhead: 7" 5M Var 1\ORS-7 Weld on style Too. Hna: NSCT T&B 2" CIW H BPV profile Cameo 2 3/8" x 1" sidepocket KBMM GLM 1117' md I I 130' I c:4 þoF Elev. = 57.0' Orlg. GL Elev. = 23.2' OF to 7" csg. hng. = 33.6' - 7" 26 ppf L-80 Btrc. 7"x 5.5" X-over (N 27E) (N 27E) I 6,284'1 I 6,361' I I 6,412' I I 6,433' I Centrilift 400 series Tandem seal b 6437' I section FST3DBHLPFS AF/HSN CL ' Centrilift FMH 77 hp motor, 2130 I 6,449' I v. 124 amps. I 6,463' I I 6,469' I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report Page 1 of 3 MPE-30 MPE-30 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/8/2005 11/18/2005 Spud Date: 7/25/1989 End: Date From - To Hours Task Code NPT Phase Description of Operations 11/13/2005 12;00· 14;00 2.00 RIGD P PRE PJSM. Rig down rig components. Scope down & layover derrick. 14:00 - 15:00 1.00 RIGD P PRE Finish RID & Prep to move. 15;00 - 20:00 5.00 MOB P PRE Move from MPL-01a to MPE·30a. 20:00 - 00;00 4.00 RIGU P PRE Spot in Rig sub over MPE·30a wellhead. Had difficult time due to MPE-S well location. Took 3 attempts to get spotted in so Pipe Shed misses MPE·S. 11/14/2005 00:00 - 01 :30 1.50 RIGU P PRE Spot Rig Sub, Pits, Pipe Shed, and Camp. 01 :30 - 03:00 1.50 RIGU P PRE Raise and Scope Derrick. 03;00 . 04:00 1.00 RIGU P PRE ACCEPTED RIG @ 0300 hrs. RlU lines to Tree and to Tiger Tank. 04:00 - 07;30 3.50 KILL P DECOMP P/U Lubricator and pull BPV, UD same. Take on 120 F Seawater to Pits. 07:30 - 08:00 0.50 KILL P DECOMP Pre-Job Safety meeting with Rig Crew, Tool Pusher, and Co-Man. 08:00 - 10;30 2.50 KILL P DECOMP Tubing Pres 110 psi, Annulus Pres 1290. Circulate 120 F seawater throughout well bore until Clean returns. Starting rate 1·BPM @ 100 psi, build to 3-4 BPM and to 510 psi for 6,000 Stks or 353 Bbls. Collect 100 Bbls of 95% Crude Oil, 5% Seawater in Tiger Tank. Well on Vacuum. 10:30 - 11 :00 0.50 KILL P DECOMP P/U TWC and set in Hanger. 11 :00 - 12:30 1.50 WHSUR P DECOMP NID Tree and Adaptor Flange. Make check for fit for the replacement TreeuOkay. 12:30·15;00 2.50 BOPSU DECOMP N/U Test Spool and Adaptor. 15:00 . 16;30 1.50 BOPSU DECOMP CIO Pipe Rams to 2·3/8". 16:30 - 18;00 1.50 BOPSU DECOMP R/U test equipment, fill stack and Choke Manifold, prepare to test BOPE to 250 Low, 3500 high. 18:00 - 21 :30 3.50 BOPSU DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. No Failures. BOP test witnessing waived by Lou Grimaldi wI AOGCC. RID test equip. 21 :30 - 23:00 1.50 WHSUR P DECOMP Drain stack. P/U lubricator & pull TWC. UD TWC & lubricator. Had trouble pulling due to frozen plug. 23:00 - 00:00 1.00 PULL P DECOMP M/U landing jt into tubing hanger. BOLDS. Pull hanger to lloor wI 46K. Unplug ESP cable & check conductivity. UD hanger & landing jt. 11/15/2005 00;00 - 01 :30 1.50 PULL P DECOMP Pull ESP cable & Heat Trace over sheave & attach to reel in spooling unit. 01 :30 . 13:00 11.50 PULL P DECOMP POOH w/2 3/8" ESP completion. Recovered 1,881 of 1,884 bands, all 530 of 6' flat gaurds, all 12 of 4' flat gaurds, all 18 of 3' flat gaurds. all 1 of 2' flat gaurds 13:00 - 14:30 1.50 PULL P DECOMP B/O and UD ESP. 14:30 - 16:00 1.50 PULL P DECOMP Clear and clean Rig Floor. RID Elephant Trunk. Place old ESP components in shipping boxes. 16:00·16:30 0.50 PULL P DECOMP Conduct Rig Safety audit. 16:30 - 18;00 1.50 RUNCO RUNCMP M/U new ESP Pump and Motor; Centralizer, Sensor, Motor FMH, Lower Tandem Seal, Upper Tandem Seal, Gas separator, Pump, Pump, Discharge head. 18:00 . 19:30 1.50 RUNCO RUNCMP PJSM for running of ESP. Make up flat head motor cable with splice between discharge head and 10' pup. Test conductivity. 19;30 - 20:00 0.50 RUNCO RUNCMP TlH and tag top of 5-1/2" liner top. 20:00 - 22:00 2.00 RUNCO RUNCMP POH, find bottom protector on MLE to be 4.95" O.D. Removed and installed flat bands, reinstall guards. 22:00 - 00:00 2,00 RUNCO RUNCMP TIH 2-3/8" ESP completion checking conductivity every 2000'. Printed: 11/21/2005 11 :47:27 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-30 MPE-30 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/8/2005 11/18/2005 Spud Date: 7/25/1989 End: Date From -To Hours Task CodeNPT Phase Description of Operations 11/15/2005 22:00 - 00:00 2.00 RUNCO RUNCMP Flushing pump w/0.1 bbls at 900 psi. 11/16/2005 00:00 - 01 :30 1.50 RUNCO RUNCMP TIH 2-3/8" ESP completion with 3300' run in 33 stds and single. Check conductivity at 20 stands in the hole and test is good. 01 :30 - 02:30 1.00 RUNCMP R/U Heat Trace line through sheaves and install 1 00 jts above bottom GLM, check cable, flush pump, keep hole full. 02:30 . 04:00 1.50 RUNCMP Before starting to RIH 2-3/8" ESP completion at 33 stds, check cable conductivity, Test Failed. Call for another meter to double check cable; cable still failed test. Decide to POOH. 04:00 . 06:00 2.00 DFAL RUNCMP POOH with ESP completion. SIB 2-3/8" tubing in Derrick. 06:00 . 08:30 2.50 DFAL RUNCMP Remove Flat Guards. Find damage to ESP Cable within 1-foot of the Pothead attachment. Likely due to the lack of a Flat Guard or Protectolizer at that point. Check that Pump and Motor rotate freely. Centrilift will build a longer Flat Guard to run to the Pothead. 08:30 - 14:00 5.50 DFAL RUNCMP Splice ESP Cable to new Pigtail assembly. Service Pump and Motor. Motor checks out electrically. 14:00 - 15:30 1.50 DFAL RUNCMP B/O pup joint from Pump Discharge to check for free rotation; pump shaft wouldn't turn. R/U to circulate 10 Bbls @ 1/2 BPM, 800-900 psi. SID, B/O circulating line and check for pump rotation, which was free. Pump and motor were likely thermally frozen while hanging in Derrick due to -28 F ambient and -50 F wind chill. 15:30 - 18:00 2.50 RUNCO RUNCMP RIH wI new ESP. Install modified Flat Guard from Pothead to first Motor Clamp Guard. Max dimension across the top of the motor through the outside of the Flat Guard is 4.875" versus 4.950" Drift ID for 5.5",15.5#, J·SS production casing. 18:00 - 19:30 1.50 RUNCO RUNCMP Spooler Generator problems, machanic came and fixed 19:30 - 20:30 1.00 RUNCO RUNCMP RIH Esp completion testing every 2000' (20 stds) cable, flush pump .1 bbl at 900 psi. Continue RIH to 33 stda and 1 single 20:30 - 00:00 3.50 RUNCO RUNCMP R/U Heat Treat line and test cable and HIT, flush pump Good continue running ESP. 11/17/2005 00:00 - 09:00 9.00 RUNCO RUNCMP Continue RIH 2-3/8" 4.7# EUE 8 rd ESP Completion with Heat Trace run from 3200' Checking conductivity every 2000', flushing pump with 0.1 bbl at 900 psi (All Tests Good). Using S-flat guards per joint and a short guard across each coupling. 09:00 - 10:00 1.00 RUNCO RUNCMP P/U #2-GLM and 3-singles from PIS and continue RIH. 10:00· 16:30 6.50 RUNCO RUNCMP M/U Hanger to string and get parameters: P/U wt 46,000 Ibs, SIO wt 36,000 Ibs. Used S-Protectolizers, 3-Flat Guards, and 3-bands on the PumplMotor Assy. Utilized 56-ESP Clamps, 112 2'-Clamps, 503 5'-Clamps and 3,240' of Heat Trace. Install Penetrators in Hanger and measure cutoff lengths for ESP and Heat Trace Cables. Make Splice for Heat Trace Pigtail. The splice came up short by 18" and space-out pups Connect ESP cable to connector. 16:30 - 23:00 6.50 RUNCO HMAN RUNCMP The Heat Trace Splice was 13" short. Pull up, breakout Hanger, remove 8' pup joint and replace with 4' and 2' pups. Cables had play so Centrilift techs conferred wI Centrilift and Milne Point Well Ops Coord. Decide to take out 2' pup and resplice both connectors, Install penetrators and test. All tests good. 23:00 - 00:00 1.00 RUNCO RUNCMP Land Tbg. Hanger RILD Set TWC and test 3500 psi. 11/18/2005 00:00 - 02:30 2.50 BOPSU P RUNCMP Change rams and Nipple Down BOPE. 02:00 - 06:00 4.00 WHSUR P RUNCMP Replace L.D.S on Well Head. N/U Lock Down Flange, Tubing Printed: 11/2112005 11 :47:27 AM . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e BPEXPLORATION Operations Summary Report MPE-30 MPE-30 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/8/2005 Rig Release: 11/18/2005 Rig Number: - r _0 - Spud Date: 7/25/1989 End: Date From - To Hours Task Code NPT Phase Description of Operations 11/18/2005 02:00 - 06:00 RUNCMP Head Adaptor, and Tree. Test Tree and Tubing Head Adaptor to 5,000 psi. Pull TWC with Lubricator and install BPV. Milne Point Operations will freeze Protect the well. Release rig @ 0600 hours. 4.00 WHSUR P . Printed: 11/21/2005 11 :47:27 AM Permit to Drill 2010170 MD 9290 '~"~- TVD DATA SUBMITTAL COMPLIANCE REPORT 61312003 Well Name/No. MILNE PT UNIT KR E-30AL1 Operator BP EXPLORATION (ALASKA) INC 4481 ~' Completion Dat 5/20/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22903-60-00 UIC N REQUIRED INFORMATION Mud Log No Sample N.__~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments D D ,~3ir-eCtT(~n al Survey FINAL MWD Survey ,-1.e331 blD~Wellbore Profile~,'~- 5 GR t,,4~D Resistivity GR 2/5 (.~,/ID Resistivity GR ~': :2/5 ~--~Resistivity GR ~v~,.{ 2/5 ~ Resistivity GR J~,~2/5 Wellbore Profile/~[/2/5 GR /kt.~ Verification ~.5'~erificatio n FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 6486 6485 6486 6485 8070 8070 8070 6674 6674 6674 882O 9297 8820 9297 9297 9297 9297 8820 8820 8820 Open 9/25/2001 ~1.0330 Open 9/25/2001 ~0331 OH 7/9/2001 OH 7/9/2001 oh 9/25/2001 L¢0330 oh 9/25/2001 4,r1~331 oh 9/25/2001 6486-8820 6485-9297 Directional Survey, Paper Copy MWD Survey, Digital Data 6486-8820 Digital Data 6485-9297 Digital Data 8070-9297 BL, Sepia oh 9/25/2001 ,-86r70-9297 BL, Sepia oh 9/25/2001 8070-929'7 BL, Sepia oh 9/25/2001 6674-8820 BL, Sepia oh 9/25/2001 6674-8820 BL, Sepia oh 9/25/2001 6674-8820 BL, Sepia 9/25/2001 LIS Verification 9/25/2001 LIS Verificaiton Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2010170 DATA SUBMITTAL COMPLIANCE REPORT 613/2003 Well Name/No. MILNE PT UNIT KR E-30AL1 Operator BP EXPLORATION (ALASKA) INC MD 9290 TVD 4481 Well Cored? Y/(~ Chips Received? · -Y / N- - Analysis '-~ R~.c~iv~.d? Completion Dar 5/20/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? Y~I Formation Tops ~/N APl No. 50-029-22903-60-00 UIC N Comments: Compliance Reviewed By: Date: Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Milne Point Unit MPE-30A-L1-PB 1 Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR Print 1 TVD-GR Print 1 Borehole Profile Print LAC Reference'Number: 15362 Sent By: Josef Berg Date: Sept 20, 2001 Received ~,' {_~t~ Date: PLEASE ACKNOWLEDGE RECEIPT BY BP EXPLO~TION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas ~ 1300, 401 .Ch Ave. S.W. Calga~, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Transmittal Form BAKER ' HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Milne Point Unit MPE-30A-L1 Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR Print 1 TVD-GR Print 1 Borehele Profile Print LAC Reference Number: 15363 Sent By: Josef Berg Date: Sept 20, 2001 Received ~ ~? Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVE AlaS~ Oil & Gas Cons. ~'/"::'/:i ' ......... ~ ....................... Anchorage: .... ALAS oIL AND GAS CONSERVATION COM IoSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-017 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22903-60 4. Location of well at surface "- ,:-~.~,.. :' '.-¥':,,-~-~ 9. Unit or Lease Name 3853' NSL, 1923' WEL, SEC. 25, T13N, RIOE, UM ~ ..... ' Milne Point Unit At top of productive interval 108' NSL, 676' WEL, SEC. 19, T13N, R11 E, UM .... Attotal depth, "~'! ~J?'~ I~.~ 10. Well Number ' ' ' ~ MPE-3OAL1 3264' NSL, 2293' EWL, SEC. 19, T13N, R11E, UM ' ~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Kuparuk River Sands KBE = 57.05' ADL 047438 12. Date Spudded 113. DateT.D. Reached114. Date Comp., S. usp.,orAband. 115. Water depth, if offshore 116. Nc. of Completions 5/1/2001 5/6/2001 5/,,~/2001,.,,~ N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 9290 4481 ETI 9290 4481 ETI [] Yes [] NoI None MDI 1800' (Approx.) 22. Type Electric or Other Logs Run RES, GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 72# L-80 36' 120' ' 16" 260 sx Arctic Set (Approx.) 5-1/2" 15.5# J-55 34' 6658' 6-3/4" ~'47 SX Colclset III, 158 sx Foamed, 70 sx 'G' 2-7/8" 4.43# L-80 6511' 9170' 3-3/4" Llncemented Slotted Liner 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)' 2-7/8" Slotted Liner Open Hole ' 2-3/8", 4.7#, 'L-80 6477' ' ' None MD TVD MD TVD ....... 6517'- 6901' 4327'- 4478' 9170'- 9290' 4472'- 4481' ' ~6.' ' ACID, FRACTURE, CEMENT SQUEEZE, ETC.' ' " 6933' - 7254' 4481' - 4494' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 7286' - 7607' 4494' - 4477' 6657' Set Whipstock 7639' - 7958' 4475' - 4467' 7990' - 8308' 4469'- 4473' Freeze Protect with 47 Bbls of Diesel 8340' - 8596' 4470' - 4456' 8723' - 8787' 4457' - 4458' 8819' - 9136' 4458' - 4471' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 27, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wa~.~,u(~ci~{~b JUL 1 0 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Top of Schrader OA 6803' 4465' Base of Schrader OA 7612' 4477' Base of Schrader OA 8232' 4479' Base of Schrader OA 8442' 4463' RECEIVED JUL i 0 Alaska Oil & Gas Cons. Commission .31. List of Attachments: Summary Of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best Of my knowledge Signed TerrieHubb,e ,,~~ ~ Title TechnicalAssistant Date MPE-30AL1 201-017 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'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page I of 8 Operations Summa Report Legal Well Name: MPE-30A ,Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/21/2001 09:30 - 11:30 2.00 MOB P PRE Move from MPH-08 to MPE-30 11:30 - 19:00 7.50 RIGU P PRE Spot rig over well. RU equipment. 19:00 - 00:00 5.00= BOPSUF P PROD1 Accept rig 19:00 hrs. NU BOPE. Continue RU equipment. 4/22/2001 00:00 - 02:00 2.00 RIGU P PRE Continue RU equipment. 02:00 - 04:00 2.00 RIGU P PRE MIRU DS Unit ~ 04:00 - 06:00 2.00 BOPSUF P PROD1 Start testing BOPE. Confirm good full body test and blind ram test. Get State man coming. 06:00 - 06:30 0.50 BOPSUR P PROD1 Safety meeting. 06:30 - 13:30 7.00 BOPSUR P PROD1 PT BOPE. Test H2S and LEL alarms. AOGCC witness Chuck Scheve. 13:30 - 15:30 2.00 BOPSUR N HMAN PROD1 Bottom 2-3/8" PIS closed on 2-7~8" test joint (upper and lower 2-3~8" PIS labeled incorrectly at Koomey). Pull replace rams. Retest. 15:30 - 16:30 1.00 BOPSUR P PROD1 RU BPV lubricator. Pull TWC. 16:30 - 18:00 1.50 STWHIP P WEXlT PU and stab injector. PT inner reel valve. 18:00- 18:30 0.50 STWHIP P WEXlT PJSM 18:30 - 20:30 2.00 STWHIP P WEXlT Slack management. Surge and reverse methanol to open top tank. Although cable slack could be heard cable was still at the EOP. 20:30 - 23:30 3.00 STWHIP P WEXlT MU CTC and pull test to 30k. MU BHI OXP head and PT. MU BHA #1. Same time surging e-line forward. 23:30 - 00:00 0.50 STWHIP P WEXlT~, Stab injector and MU. Prep to TIH. 4/23/2001 00:00 - 01:45 1.75 STWHIP P WEXlT "x,TIH w/window milling BHA. 01:45 - 02:30 0.75 STVVHIP P WEXlT Open circ-sub. Displace hole to 9.3 ppg KCL. Close circ-sub. 02:30 - 07:00 4.50 STVVHIP P WEXlT Dry tag and correct depth to 6737' (-15'). RIH with pumps 2.5~3580 and stall at 6739.6'. Mill from here at 2k down and 150 psi motor work. Saw as much as 600~ motor work at 6742.8'. Mill to 6746' pumping 3.0 ppb biozan sweeps. ROP increasing here (no stall or goofy motor work). Must be in formation. Correcte window is 6738' to 6744' md. RA is at 6746' (9' down from top of WS) 07:00 - 07:30 0.50 STWHIP P WEXlT Drill formation 30 - 60 FPH to 6756' 07:30 - 10:00 2.50 STWHIP P WEXlT Ream and backream window 2.813400. Motor work in the 6742' - 6743' area. Dry tag 6757' clean. Pump one more 30 bbl pill of 3 ppb biozan from TD, laying in last 5 bbls to 6500'. 10:00 - 11:30 1.50 STWHIP P WEXlT Open circ sub and POOH circulating 3.213150. 11:30 - 12:30 1.00 STWHIP P WEXlT LD milling BHA. 12:30 - 14:30 2.00 DRILL P PROD1 MU drilling BHA #2 (M09 bit; 3.28 deg motor). Surface test tools. OK. 14:30 - 15:00 0.50 DRILL P PROD1 RIH. 15:00 - 15:30 0.50 DRILL P PROD1 Rig evacuation drill. 15:30- 16:00 0.50 DRILL P PROD1 RIH 16:00 - 17:30 1.50 DRILL P PROD1 Log tie-in. Correct depth (-5'). 17:30 - 23:10 5.67 DRILL N DFAL PROD1 Try to orient to get thru window. Short in OXP. POOH. Replace OXP. Surface test. RIH. Tie-in -10' correction. 23:10 - 00:00 0.83 DRILL N WAIT PROD1 Orient to highside. Dry tag at 6759'. Wait on mud. 4/24/2001 00:00 - 01:45 1.75 DRILL N WAIT PROD1 Wait on mud. All trucks at 33E and 14 the last 24 hours. First load arrived 0100 transfering to rig pit #2. With EDC open start displace hole to 9.3 ppg FIo-Pro mud. 01:45 - 07:30 5.75 DRILL P PROD1 Drill build section f/6756'. Landed 90 degs at 6830' md, 4435' tvd. Drilling ahead w/75-90R TF 2.4 bpm 3850 psi 1:1 returns. Drill to 6970'. 07:30 - 09:00 1.50 DRILL P PROD1 Wiper to window at 90R. RIH. Backream 2.313600 slow with Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: MPE-30A ,Common Well Name: MPE-30A Spud Date: 7/25/1989 ~Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/24/2001 07:30 - 09:00 1.50 DRILL !P PROD1 lower left TF. 09:00 - 10:30 1.50 DRILL P PROD1 POOH. 10:30 - 13:00 2.50 DRILL P PROD1 LD BHA #3. MU BHA ~ (USMPR; 1.0 deg motor; DS49). 13:00- 15:10 2.17 DRILL P PROD1 RIH. Tie-in -11 correction. 15:10 - 18:10 3.00 DRILL P PROD1 Drill fl 6790' to 7144'. Attempting to drop angle from 96+ deg and turn right. Unable to drop angle fast enough to prevent drilling out of the AO sand. Discuss options and decision made to TOH f/openhole sidetrack BHA. 18:10 - 20:15 2.08 DRILL N DPRB PROD1 Open EDC. TOH 20:15 - 21:15 1.00 DRILL N DPRB PROD1 P/U BHA#3. 21:15 - 23:30 2.251 DRILL N DPRB PROD1 RIH log tie-in -9'. 23:30 - 00:00 0.50: DRILL N DPRB PROD1 Start troughing at 6990'. Plan sidetrack starting at +1- 7020'md 4426.5' tvdss 4/25/2001 00:00 - 03:15 3.25 DRILL N DPRB PROD1 Continue troughing from 6990' to 7020'. 03:15 - 05:20 2.08 DRILL N DPRB PROD1 Time drilling openhole sidetrack f/7020'-7030' 139L TF 6-12'/hr. Bring to 93R TF drilled ahead to 7086'. 05:20 - 06:00 0.67 DRILL N DPRB PROD1 Short trip to clean up sidetrack area. 06:00 - 07:50 1.83 DRILL N DPRB PROD1 POH for horizontal BHA. 07:50 - 09:00 1.17 DRILL N DPRB PROD1 Change out bit and bend motor to 1.4 degrees. 09:00-10:35 1.58 DRILL N DPRB PROD1 RIHw/BHA#6. OAL=77.70'. 10:35 - 10:45 0.17 DRILL N DPRB PROD1 Tie into whipstock. (-10'). Close circ sub. 10:45 - 11:00 0.25 DRILL N DPRB PROD1 RIH Pumping 1/3 BPM. Build smooth. 11:00 - 12:45 1.75 DRILL P PROD1 Drill ahead from 7068'. Pump 2.4 bpm, Free spin 3440~, 3590 drilling. RIH wt. 6-8K#, drilling w/3k# string wi and 3 to .5K# wob. ROP @ 130 fph. Drill to 7224'. 12:45 - 13:20 0.58 DRILL P PROD1 Short trip to window. Hole clean. 13:20 - 14:50 1.50 DRILL P PROD1 Drill to 7374'. Build to 91 degrees. 14:50 - 15:35 0.75 DRILL P PROD1 Short trip to window. 15:35 - 18:20 2.75 DRILL P PROD1 Drill ahead following dip. 2.4 bpm. Drilled to 7520'. 18:20 - 19:45 1.42 DRILL P PROD1 Wiper trip to window. 19:45 - 20:25 0.67 DRILL P PROD1 Drilling ahead. 2.4 bpm 3625 psi 4k# wob. Drilled to 7570 20:25 - 21:40 1.25 DRILL N RREP PROD1 Pop-off valve on Nab0rs mud pump went off and would not reset. Replace valve. 21:40 - 00:00 2.33 DRILL P PROD1 Drilled ahead to 7630' md 4434' tvdss. 4/26/2001 00:00 - 02:30 2.50 DRILL P PROD1 Continue drilling f/7630' 2.4 bpm 3770 psi 4k# wob to 7720'. Still drilling in shale. Uncertain if we are above or below target. Drill ahead to find data point on other side of fault expected at +/- 7850'. 02:30 - 04:00 1.50 DRILL P PROD1 Wiper trip through window. See slight motor work at 6990' and 6900'. Drag debris up to window where it clears. 04:00 - 06:00 2.00 DRILL P PROD1 Directional drilling f/7720' ROP ..-25 fph. 2.4 bpm, 3680 ctp, 3260 internal, 2525 external, -2k# string wt, 4k# WOB. Drilling at 7775'. 06:00 - 07:45 1.75 DRILL P PROD1 Continue drilling ahead in search of OA sand target. Get drilling break @ 7810'. 07:45 - 08:00 0.25 DRILL P PROD1 Pick up to orient from high right to left side. (must go CW through Iow side due to orienter stop being ~ 45L) 08:00 - 09:00 1.00 DRILL P PROD1 Drilling ahead. ROP increasing to 80 FPH. 2.4 bpm, CTP 3630 surface, 3200 inner, 2555 outer, 2.5k string wt drilling, lk wob. Drill to 7870'. ROP drops off again. 09:00 - 11:15 2.25 DRILL P PROD1 Short trip to window. Outside pressure ~ 2500# coming off of bottom, 2437 above window w/circ sub open. Tie into whipstock pip tag (+4') RIH, build and side track area smooth, , . Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page 3 of 8 Operations Summa Report Legal Well Name: MPE-30A ~Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase · Description of Operations 4/26/2001 09:00 - 11:15 2.25 DRILL ~ PROD1 no weight bobbles. 11:15 - 17:15 6.00 DRILL 3 PROD1 Drill ahead from 7870'. Drilling slows again to 20 fph. Drill to 7900'. ;Discuss w/town team to drill another 200' at 96 degree l inclination to hopefully find OA target. -2k# string wt, 4k# wob. Drilling rate slows to 10 fph @ 7975'. Call for new mud to be brought out. (22E doing surface cement job) 17:15 - 18:15 1.00 DRILL P PROD1 Drill ahead. String wt. at 2k#, 2.5k# WOB. 2545~ outside pressure, 3635 ctp. Drilling @ 96 deg. 90L TF drill break at 7995' increase f/negitive st. weight to + 6k# drill to 8009'. 18:15 - 19:45 1.50 DRILL P PROD1 Wiper trip to window. 19:45 - 21:20 1.58 DRILL P PROD1 Drilling ahead fl 8009' 100-120/fph 1 k# wob dropping angle to 92 deg. Maintaining 91-91.5 crusing in the OA Drill to 8220'. 21:20 - 23:10 1.83 DRILL P PROD1 Wiper trip to window. Start mud swap to fresh FIo-Pro. No overpull on TOH, 4-6k# string weight TIH. 23:10 - 00:00 0.83 DRILL P PROD1 Drilling ahead 120'/hr lk# wob, -2k/# to +4k/# string weight, fl 8220' to 8330' md 4406' tvdss. 4/27/2001 00:00 - 00:45 0.75 DRILL P PROD1 Continue drilling in OA sand fl 8330' 120'/hr, lk# wob (4k# positive string wt.), 90 deg, 2.4 bpm, 3275 psi on bottom. Drill to 8420'. 00:45 - 03:00 2.25 DRILL P PROD1 Wiper trip. Log tie-in (up) +3' correction. 03:00 - 05:05 2.08 DRILL P PROD1 Drill ahead lk# wob 120'/hr 2.4 bpm 3-4k# string wt. to 8622' md 4401' b/dss. Results from mud swap: inner circ. pressures 3150 > 3025, outer 2540 > 2510, coil 3660 > 3340 psi. 05:05 - 06:50 1.75 DRILL .P PROD1 Wiper trip to window. Hole smooth. Correct depth at Pip tag (+5') 06:50 - 08:30 1.67 DRILL ~P PROD1 Log MAD pass Resistivity through build section. 08:30 - 10:00 1.50 DRILL P PROD1 Drift open-hole w/o pumping. Hole takes weight at 8072'. Orient 180 deg. and pass by cleanly. Weight bobbles again at 8530', 8561' and 8575'. Pick up pumping cleaning 8500' area. Drift w/o pumps. Push to TD. Bring on pumps. Corrected TD = 8626'. 10:00 - 13:30 3.50 DRILL i P PROD1 Pull up hole pumping. Hole in good shape. POH for liner. Displace E-coil to meth/wtr. 13:30 - 14:30 1.00 DRILL !P PROD1 TOH. Lay down BHA #6. Bit in good shape, rerunable. 14:30 - 16:30 2.00 DRILL i P PROD1 Cut E-Line/Coil. Remove from injector. M/U 2-3/8" coil from ROC into injector. Prepare floor for running liner. 16:30 - 17:15 0.75 DRILL ~P PROD1 PJSM for running liner. Discuss all hazards and well control scenarios. 17:15 - 18:00 0.75 DRILL ' P PROD1 Pick up 51 its of 2-7/8" liner w/o turbolators and make up into hole. Torque to 1300 fi/Lbs. 18:00 - 18:30 0.50 DRILL P PROD1 PJSM for night crew. 18:30 - 20:10 1.67 DRILL I P PROD1 Continue running liner. Hold "kick drill" P/U TIW assembly and MU. Discuss job assignments during kick and anticipated realtime situations. Finish p/u liner. 20:10 - 20:25 0.25 DRILL ~P PROD1 PJSM p/u 1 1/4" CSH and reconfigure TIW assembly. 20:25 - 22:00 1.58 DRILL i P PROD1 P/U 1 1/4" CSH. Make up Baker deployment tools. 22:00 - 22:15 0.25 DRILL i P PROD1 PJMS about useing Dowell's ROC. 22:15 - 00:00 1.75 DRILL N RREP PROD1 Reel on ROC frozen within the sump under the reel. Chip ice and apply heat from Tioga. 4/28/2001 00:00 - 00:15 0.25 DRILL 'N RREP PROD1 Continue to thaw ROC reel from ice within sump. 00:15 - 02:00 1.75 DRILL P PROD1 P/U injector m/u CTC to 2 3/8" coil from ROC pull test same and fill with FIo-Pro mud. Printed: 5/2412001 3:02:49 PM BP EXPLORATION Page 4 of 8 Operations' Summa Report Legal Well Name: MPE-30A ,Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From ' To Hours Activity Code NPT Phase 'Description of Operations 4/28/2001 02:00 - 06:00 4.00 DRILL P PROD1 TIH w/2 7~8" liner. Good to 7226' then bottomed out. Work liner fairly good to 7870' @ 0400 hrs. Attempt to pull up hole. Make --100' then pull 70k#. Resume working down 1'-4' deeper increments. Make 8021'. 06:00 - 12:00 6.00 DRILL P PROD1 Circulate 15 Bbls 1.3 bpm 1750 CTP on bottom. P/U and make some footage. Continue with this technique. Attempt to optimize technique without improvement. Maintain course. 8177' at noon. 12:00 - 15:45 3.75 DRILL P PROD1 Continue pushing liner to bottom. Mix 6% Lubtex pill. Liner at 8258'. (240' to go) 15:45 - 18:00 2.25~ DRILL P PROD1 Make it to 8296'. Continue shoving. 18:00 - 00:00 6.00' DRILL P PROD1 Shift change PJSM. Continue working liner. Mixed and pumped 2- 35 bbl EM1-544 pills (Lubtex enhancer) Midnight depth 8393'. Averaging 20'/hr useing same technique as above. 4/29/2001 00:00 - 06:00 6.00 DRILL P PROD1 Continue working liner to set depth. Circulating 15 min at 1.4 bpm, pick-up on liner (38-40k#) until free, shutdown pumps and work liner down avg 15'/hr. 0600hr depth 8471'. Shift change hold PJSM on dropping 5~8" ball for liner release. 06:00 - 07:20 1.33 DRILL P PROD1 Work down to 8486.7'. Attempt to release liner with pressure, 4000 psi, 3 bpm. Pull up to drop ball 8474.9'. Drop 5~8" ball and circulate 3 bpm. 07:20 - 08:30 1.17 DRILL P PROD1 Circulate ball to seat. Shear ball seat. PU weight breaks from 39k to 32k#. Unable to get back to bottom. PUH to 8300' (LRT in casing). Still can not run in hole. Opt to pump bleach job from here. End of CS Hydrill @ 8300' ~ 330' of clean CA sand at toe of well bore. 08:30 - 14:30 6.00 DRILL P PROD1 Pump 100 Bbls of 9.3ppg brine. Follow with 33 Bbls 6 ppb lithium hypochlorite. Pump 66 Bbls of brine. Spot 21 bbls of bleach in liner (OH vol.) Move 1/2 Bbl bleach every 10 minutes for a 4 hour soak. 14:30 - 16:15 1.75 DRILL P PROD1 Displace bleach with 66 Bbls of 9.3 brine. Lay in 30 Bbls of 9.3 ppg Baradril-N mud. Up weight 27k# pumping 1 bpm. 16:15 - 17:30 1.25 DRILL P PROD1 POH swapping well back to Flopro. 17:30 - 20:30 3.00 DRILL . P PROD1 CCH. ROC freeze protected. Lay down liner running tool. Set back injector. Unstab ROC coil from injector and RU e-line coil. 20:30 - 21:50 1.33 DRILL P PROD1 L/D I 1/4" CSH tubing. 21:50 - 22:45 0.92 DRILL P PROD1 Install 2-way check. 22:45 - 00:00 1.25 DRILL P PROD1 Start weekly BOP testing. AOGCC notified and declined witnessing test. 4/30/2001 00:00 - 06:30 6.50 DRILL P PROD1 Continue testing BOPE. No failures. 06:30 - 08:15 1.75 DRILL P PROD1 Lay down testing equipment. Pull test plug. 08:15 - 11:30 3.25 DRILL P PROD1 Cut off 21' of coil. Find cable wadded up in coil. Cut cable was 21.3' long. Still feel "slack" in coil of remaining cable. M/U Coil connector. Pull test 30k#. Pressure test 4000~. 11:30 - 13:30 2.00 DRILL P PROD1 M/U BHA #8. Test tools. 13:30 - 13:50 0.33 DRILL P PROD1 Circulate methanol out of reel. 13:50- 15:50 2.00 DRILL P PROD1 RIHw/BHA#8. DS-49, 1.4 deg. motor, OXP. 15:50 - 17:30 1.67 DRILL P PROD1 Log GR tie in f/6600'. (-4') Aisc fill "gap" in GR Icg by logging to 6750' GR depth. Set down 6673'. Repeats solid. Good weight transfer, getting 6k# WOB. Must be top of liner. 17:30 - 18:30 1.00 DRILL N DFAL PROD1 Stand by for decision with rest of team. Decide to go ahead with whipstock. Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page 5 of 8 Operations Summa Report Legal Well Name: MPE-30A Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/30/2001 18:30 - 19:45 1.25 DRILL N DFAL PROD1 Circulate with TF Iow side to clean up casing in set-depth area. 19:45 - 20:15 0.50 DRILL N DFAL PROD1 TOH f/whipstock. 20:15 - 21:00 0.75 DRILL N DFAL PROD1 L/D motor and USMPR. 21:00 - 23:45 2.75 DRILL N DFAL PROD1 WO Baker whipstock. Pump across coil rain rate. 23:45 - 00:00 0.25 DRILL N DFAL PROD1 P/U BHA #9 (77.70') w/Baker whipstock and hydraulic setting tool. 5/1/2001 00:00 - 01:30 1.50 DRILL N DFAL PROD1 Continue M/U whipstock BHA #8. Stab-on injector. 01:30 - 03:25 1.92 DRILL N DFAL PROD1 TIH w/whipstock. EDC open 1/2 bpm 850 psi. Tag at 6676' down wt, 6673' up wt. Repeat with same numbers. Retag and pick-up to 6669'. With OXP adjust to 20L toolface. Close EDC. Pressure up to 3800 psi (3100 psi diff pressure at tool) and hydraulically set whipstock. Top of whipstock at 6657'. 03:25 - 04:50 1.42 DRILL P PROD1 TOH. 04:50 - 06:05 1.25 DRILL P PROD1 Tag-up. Disconnect and trolly out. L/D setting tool. P/U BHA #10 06:05 - 08:30 2.42 DRILL P PROD1 RIH w/BHA #10. OAL - 65.73'. Hughes diamond mill and string reamer. 08:30 -09:10 0.67 DRILL P PROD1 Log GRtie in. (-11') 09:10 - 13:00 3.83 DRILL P PROD1 Tag whipstock @ 6659' stacking weight and not pumping. Start milling window at 6658'. Bottom of window @ 6664'. Drill 7' of open hole. Back ream through window. 13:00 - 13:30 0.50 DRILL P PROD1 Drill 7' of open hole. 13:30 - 14:10 0.67 DRILL P PROD1 Ream through window up and down. Slight motor work on first pass. Cleaned up nicely. 14:10 - 14:40 0.50 DRILL P PROD1 Mill remaining 3' of open hole to 6674'. Drift w/o pump. Clean. 14:40 - 16:00 1.33 DRILL P PROD1 POH w/circulating sub open. 16:00 - 17:45 1.75 DRILL P PROD1 L/D window milling assembly. P/U BHA #11 17:45- 18:15 0.50 DRILL P PROD1 TIH 18:15 - 19:15 1.00 DRILL P PROD1 Tie in 12' correction 19:15 - 23:30 4.25 DRILL P PROD1 Directionally drill to 6765, Rate of build higher expected pull to adjust bend in the motor. Pressure at BHA 3464psi annular pressure at BHA 2392psi, pump pressure 3740,WOB 7.4k ecd 10.5 at 2.4 BPM. 23:30- 0.00 DRILL P PROD1 POH 5/2/2001 00:00 - 01:30 1.50 DRILL P PROD1 POH 01:30 - 02:30 1.00i DRILL P PROD1 Adjust motor to 1 degree, add resistivity tool, test tool 02:30 - 03:40 1.17 DRILL P PROD1 RIH to 6545' 03:40 - 04:15 0.58 DRILL P PROD1 Tie in -11' 04:15 - 05:00 0.75i DRILL P PROD1 RIH to 6765' 05:00 - 08:25 3.42 DRILL P PROD1 Continue drilling remainder of build section f/6765' to 6965'. 20L- 0 TF, 2.4 bpm 3360 psi 1.4k# wob 95'/hr. 1 deg motor not giving the anticipated doglegs needed to land out at 4425' tvd. Resurvey last 100' to confirm and drill to 6980' md 4429.41' tvd. Survey projected @ bit is 84 deg. Decision made to trip for 1.5 deg motor. Top of OA sand picked at 4408' tvdss, bottom 4438' tvdss. 08:25 - 09:45 1.33 DRILL P PROD1 TOH 09:45 - 11:30 1.75 DRILL P PROD1 Swap out motors for a 1.5 deg motor. 11:30 - 12:50 1.33 DRILL P PROD1 TIH w/BHA #13 (74.85') Test tools -okay. 12:50 - 13:30 0.67 DRILL P PROD1 Log tie-in -7'. 13:30 - 15:00 1.50 DRILL P PROD1 Drill build section f/6980' 0TF 2.0 bpm pushing hard to build. Land out 90 deg at 7038°md 4030' tvdss. Having problems with the orienter. Having to pick-up off bottom to orient. Pull into Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page 6 of 8 Operations Summa RePort Legal Well Name: MPE-30A ,Common Well Name: MPE-30A Spud Date: 7/25/1989 i Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/2/2001 13:30 - 15:00 1.50 DRILL ~ PROD1 casing. Orienter will go left but not right. Going for BHA #14. 15:00 - 16:30 1.50 DRILL N DFAL PROD1 Trip for orientedOXP. Visitors fl BP Alaska Leadership Team 16:30 - 17:30 1.00 DRILL N DFAL PROD1 Change out OXP and reset motor to 1.4 deg. 17:30 - 19:00 1.50 DRILL N DFAL PROD1 RIH. Crew change and PJSM 19:00 - 19:15 0.25 DRILL N PROD1 Tie inwith pip in whipstock -12' 19:15 - 21:15 2.00 DRILL N PROD1 Directionally drill to7236. Short trip 556'. 21:15 - 00:00 2.75 DRILL N PROD1 Directionally drill to7384. Pressure at BHA 3119 psi annular pressure at BHA 2477. Pump pressure 3171 at 2.5 bpm. ReP 65 ft/min ECD 10.7 Short trip 719'. 5/3/2001 00:00 - 02:30 2.50 DRILL P PROD1 Directionally drill to 7513. Short trip to window. 02:30 - 05:00 2.50 DRILL P PROD1 Directionally drill to 7570'. Crossed faults at 7474' & 7500' and currently drilling in shale. High gama reading indicate we maybe above the eA. Shales above the OA hotter than those below. Will short trip while consulting with town. 05:00 - 05:45 0.75 DRILL P PROD1 Make short wiper trip. 05:45 - 08:00 2.25 DRILL P PROD1 Decision to continue building gradually upward to 95 deg. Directional drlg fl 7570', 50R TF. Back into OA sand at 7577'md 4421' b/dss 95 deg @ bit leveling off and plan to decrease angle following eA. Drilled to 7720'. Swapping out old Fie-Pro system for new. 08:00 - 09:30 1.50: DRILL P PROD1 Wiper trip to window. No problems w/hole. 09:20 - 11:00 1.67 DRILL P PROD1 Directional drill f/7720' to 7846'. Unable to transfer WeB. Appears to be a ledge somewhere between 7770'-7780' where the BHA is hanging up. (Have drilled several calsite stringers with radical throws in angle) 11:00 - 12:35 1.58 DRILL P PROD1 Backream area f/7770' - 7790' with different TF's. Motor work f/ 7787' - 7773'. 12:35 - 14:45 2.17 DRILL P PROD1 Hole cleand up. Continue drilling f/7786' to 7920'. 14:45 - 15:35 0.83 DRILL P PROD1 Wiper trip to window. 15:35 - 17:30 1.92 DRILL P PROD1 Continue drilling f/7920' to 8120'. 17:30 - 19:30 2.00 DRILL P PROD1 Wiper trip to window. 19:30 - 21:00 1.50 DRILL P PROD1 Directionally drill to 8214. OXP experienced a down hole short. 21:00 - 00:00 3.00 DRILL N DFAL PROD1 POH Change out EDC and upper quick connect. 5/4/2001 00:00 -02:30 2.50 DRILL N DFAL PROD1 RIH 02:30 - 06:00 3.50 DRILL P PROD1 Directionally drill f/8214' to 8413'. Drilled into another fault at 8240'. Discuss with town. Anticipate downward trend. Decreasing angle. 06:00 - 07:30 1.50 DRILL P PROD1 Wiper trip to window. No hole problems. 07:30 - 13:20 5.83 DRILL P PROD1 Directional drilling f/8413'. 20-30 rep, 3350 CT psi, 2.3bpm. Dropping angle to 82-83 deg. 10-20' rep. Back into sand at 8570'md 4443' tvd drilled to 8613'. 13:20 - 15:00 1.67 DRILL P PROD1 Wiper trip to window. 15:00 - 15:45 0.75 DRILL P PROD1 Stop for logging and geological analysis. 15:45 - 18:00 2.25 DRILL P PROD1 Continue drilling f/8613' rep 90-100'/hr 2-3k# web 18:00 - 19:30 1.50 DRILL P PROD1 Wiper trip to window 2150' 19:30 - 20:00 0.50 DRILL N DPRB PROD1 Wait on side track instructions. Geologic interputaion of log indicate that we are in the OB. Instruction were to select a optimal place for sidetrack and drill into the OA target. 20:00 - 21:20 1.33 DRILL N DPRB PROD1 RIH tie in +2 correction 21:20 - 23:15 1.92 DRILL N DPRB PROD1 RIH to log down to 8110. Pull back to 8040 23:15 - 00:00 0.75 DRILL N DPRB PROD1 Begin sidetrack operation. 5/5/2001 00:00 - 02:45 2.75 STKOH N DPRB PROD1 Build trench 8040'-8070'. Printed: 5/2412001 3:02:,49 PM BP EXPLORATION Page 7 of 8 Operations Summa Report Legal Well Name: MPE-30A Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 4/21/2001 End: 'Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/5/2001 02:45 - 13:45 11.001 STKOH N DPRB PROD1 Directionally drill at controlled rate 6 fi/hr to establish kickoff. Change out mud annular pressure 2420/2391. For the record we are calling the sidetrack starting depth 8040'. Departure good. DFD Seeing shales and sands... Drill to 8284'. 13:45 - 15:50 2.08 DRILL N DPRB PROD1 Wiper trip to window. Ream sidetrack point. 15:50 - 18:00 2.17 DRILL N DPRB PROD1 Drill ahead looking for positive OA confirmation. Making estimate on dip etc. 2.3 bpm, 3500 ctp, 3200 inner, 2440 outer, 4k wob, -10k string wt. Drill into shale @ 8330'. ROP @ 20 fph. Continue drilling to 8380'. 18:00 - 20:10 2.17 DRILL N DPRB PROD1 Wiper trip to sidetrack 450'. 20:10 - 00:00 3.83 DRILL P PROD1 Drill to 8600'. Back into OA target. Short trip1900' 5/6/2001 00:00 - 03:25 3.42 DRILL P PROD1 Completed short trip. Drill to 8665'.BH pressure 3200 psi,BH annular pressure 2427 psi. Pump pressure 3276 psi @ 2.2 bpm 03:25 - 05:10 1.75 DRILL P PROD1 Drill to 8801. Wiper trip to window. 05:10 - 06:40 1.50 DRILL P PROD1 Drill from 8800' to 9000'. 2.3 bpm, 3320# coil, 3050# inner, 2480# outer, -10k# string wt, 1 k# WOB. ROP 100-180 fph. 06:40 - 08:00 1.33 DRILL P PROD1 Short trip to window. 08:00 - 08:15 0.25 DRILL P PROD1 Tie into WS. (+6') 08:15 - 08:30 0.25 DRILL P PROD1 Pull up into casing and service pump. 08:30 - 09:25 0.92 DRILL P PROD1 Run back in hole. 09:25 - 13:30 4.08 DRILL P PROD1 Drill ahead. ROP drops significantly @ 9084'. Probably calcite stringer. Check weights. Getting good weight transfer. 9096' drilling slow 2 fph. Break through @9100'. 13:30 - 13:50 0.33 DRILL P PROD1 Drill ahead @ 120 fph. Hit hard streek again @ 9150'. 13:50 - 15:10 1.33 DRILL P PROD1 Drill hard streek 9150' to 9160'. 15:10 - 15:30 0.33 DRILL P PROD1 Drill ahead at 120 fph to 9167'. 15:30 - 18:00 2.50 DRILL P PROD1 Wiper trip to window. 18:00 - 23:30 5.50 DRILL P PROD1 Directionally drilled to 9290' TD. D&I package giving irratic readings while in the calcite stringers. Well objectives met. Decision to call TD as soon as the well was changed over to new mud. 23:30 - 00:00 0.50 DRILL P PROD1 Pull back to whip stock 5/7/2001 00:00 - 03:30 3.50 DRILL P PROD1 Circulate and condition mud. Pull back to whip stock. Tie in correction+9'. 03:30 - 05:30 2.00 DRILL P PROD1 RIH to TD on final wiper trip. 05:30 - 07:15 1.75 DRILL P PROD1 Pull out of hole circulating through circ. sub. Freeze protect e-coil w/meth/water. 07:15 - 08:15 1.00 DRILL P PROD1 Lay down OXP BH^. 08:15 - 11:45 3.50 DRILL P PROD1 Lay down injector. Cut and secure electric-line coil. Stab 2-3/8" coil from ROC into injector. 11:45 - 16:00 4.25 DRILL P PROD1 M/U 2-3/8" liner. Tapered guide shoe, Pack-off bushing, 17 Jts FL4S, 65 Jts ST-L, 4.5" scoop guide on 3.75 deployment Sleeve. (2660.64' liner length) 16:00 - 19:30 3.50 DRILL P PROD1 M/U 85 Jts of 1" wash pipe. 19:30 - 20:00 0.50 DRILL P PROD1 PU liner running tools 20:00 - 20:30 0.50 DRILL P PROD1 PU injector 20:30 - 21:00 0.50 DRILL P PROD1 Install coil connector. 21:00 - 22:30 1.50 DRILL N PROD1 Pump problem with Nabors pump. 22:30 - 23:30 1.00 DRILL P PROD1 Circulate freeze protection out of ROC with Dowell pump. Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page 8 of 8 Operations S umma , Report Legal Well Name: MPE-30A Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 4/21/2001 End: Contractor Name: NABORS Rig Release: 5/20/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT , Phase Description of Operations 5/7/2001 23:30 - 00:00 0.50, CASE P LNR2 RIH with liner 5/8/2001 00:00 - 02:00 2.00: CASE P LNR2 RIH with liner to 8500'. Lock up 02:00 - 06:00 4.00 CASE P LNR2 Continue running liner by circulating 10 minutes PU and RIH to lock up. Progressing in increments of 2 to 60' randomly. Work liner to 8928'. 06:00 - 12:00 6.00 CASE P LNR2 Continue running liner. Vary techniques with negative results. Resume pumping 10-15 minutes, PU and stack out. Make it to 9113'. 12:00 - 18:30 6.50 CASE P LNR2 Continue working in hole. to 9170'. Anchorage decision to call this TD. 18:30 - 22:00 3.50 CASE P LNR2 Drop ball and displace with mud. Ball didn't land on seat. Multiple attemps to rock the well were unsuccessful. 22:00 - 23:30 1.50 CASE P LNR2 Mix and pump 25 bbl high vis pill followed with 10 bbl 9.3 brine. displace with mud. When leading edge of high vis pill reached the setting tool the ball seated. Potential RP 23:30 - 00:00 0.50 CASE P LNR2 Pump 35 bbl Lithium Hypochlorite. Spot pill and pull to 6600'. Circulate out mud for return to MI. 5/9/2001 00:00 - 04:15 4.25 CASE P LNR2 Spot bleach and POH to 6600'. Change over well to brine. Allow bleach to soak 4 hours. 04:15 - 05:00 0.75 CASE P LNR2 RIH and circulate out bleach. 05:00- 08:00 3.00 CASE P LNR2 POH 08:00 - 09:00 1.00 CASE P LNR2 Freeze protect coil, SB inj. 09:00 - 09:30 0.50 CASE P LNR2 LD liner running equipment. 09:30 - 10:00 0.50 CASE P LNR2 Safety meeting. 10:00 - 13:30 3.50 CASE P LNR2 LD 1" CSH in singles. 13:30 - 15:00 1.50 RIGD P COMP Suck lines, RD equipment, unstab coil from rock. 15:00 - 16:00 1.00 RIGD P COMP Set TWC. 16:00 - 20:00 4.00 RIGD P COMP ND BOPE. UP tree cap and test. Release rig. Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page I of 1 Operations Summa Report Legal Well Name: MPE-30A Common Well Name: MPE-30A Spud Date: 7/25/1989 Event Name: REENTER+COMPLETE Start: 5/16/2001 End: 5/20/2001 Contractor Name: NABORS Rig Release: 3/14/2001 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Activity Code NPT Phase Description of Operations 5/17/2001 00:00 - 06:00 6.00 MOB P COMP RD FROM MPL-04 & MOVE TO MPE-30. 06:00 - 07:30 1.50 MOB P COMP SPOT & BERM RIG. 07:30 - 09:00 1.50 MOB P COMP RAISE & SCOPE DERRICK. 09:00 - 11:00 2.00 KILL P COMP PJU TIGER TANKS & TAKE ON 9.3 PPB FLUID. ACCEPTED RIG @ 0900 HRS, 5-17-01. 11:00 - 13:30 2.50 KILL P COMP R/U LINES TO TREE & TEST SAME TO 3500 PSI. 13:30 - 16:30 3.00 KILL P COMP SlCP 200 PSI. OPEN WELL & BLEED OFF PRESSURE. BLED OFF & RECOVERED 41 BBLS DIESEL TO TIGER TANK. WELL DEAD. 16:30 - 17:30 1.00 WHSUR P COMP BLOW DOWN LINES. TEST TWC TO 3500 PSI. OK. CLEAR CELLAR. 17:30 - 18:00 0.50 WHSUR P COMP N/D X-MAS TREE. 18:00-22:00 4.00 BOPSUF P COMP N/U BOPE. 22:00 - 23:30 1.50 BOPSUF P COMP PRESSURE TEST BOPE. TO 3500 PSI. LP 250 PSI. FUNCTION TEST ALL EQUIP. 23:30 - 00:00 0.50 WHSUR P COMP P/U LUBRICATOR & PULL TWC. 5/18/2001 00:00 - 01:30 1.50 WHSUR I P COMP P/U LUBRICATOR & PULL 5 1/2" TWC. L/D SAME. 01:30 - 02:30 1.00 WHSUR~ P COMP M/U X-OVER & PULL FALSE BOWL. L/D SAME. 02:30 - 03:00 0.501 RUNCOI~P COMP R/U TO RUN 2 3~8" TBG. 03:00 - 06:30 3.50! RUNCOI~P COMP RIH W/2 3~8" TBG TO 3500'. 06:30 - 08:30 2.00 RUNCOI~I3 COMP R/U CIRCULATE OUT FREEZE PROTECTION. MONITOR WELL. 08:30 - 10:00 1.50 RUNCOr~ COMP PULL OUT OF HOLE & STAND BACK TBG. 10:00- 11:00 1.00 RUNCOI~I:' COMP PJSM. R/U TO RUN COMPLETION. CHANGE OUT ESP SHEAVE. 11:00 - 14:00 3.00 RUNCOr~I:' COMP M/U, SERVICE & TEST ESP. 14:00 - 15:30 1.50 RUNCOI~I~ COMP PULL CABLE OVER SHEAVE & TIE-IN TO ESP. RIH TO PORT COLLAR WOULD NOT GO DEEPER. 15:30 - 16:30 1.00 RUNCOI~ COMP POOH TO ESP. REMOVE PROTECTOLIZER CLAMP. 16:30 - 19:30 3.00 RUNCOI~ COMP RIH W/2 3/8" COMPLETION STRING. 19:30 - 21:30 2.00 RUNCOI~ COMP PJU TO RUN HEAT TRACE. TERMINATION END NO GOOD. 21:30 - 00:00 2.50 RUNCOI~!:) COMP RE-SPLICE HEAT TRACER TERMINATION END. 5/19/2001 00:00 - 13:00 13.00 RUNCOI~ COMP RIH W/2 3~8" COMPLETION STRING to 6500'. TAGGED UP ON TOP OF LINER. 13:00 - 15:00 2.00 RUNCOI~I~ COMP L/D EXCESS TBG. SPACE OUT STRING. 15:00 - 15:30 0.50 RUNCOI~ COMP M/U HANGER & LANDING JT. INSTALL PENETRATORS. 15:30 - 20:30 5.00 RUNCOr~ COMP SPLICE HEAT TRACE & ESP CABLE. TEST SAME. NOTE: HAD TO RE-SPLICE HEAT TRACE BECAUSE OF NO-TEST. 20:30 - 21:30 1.00 RUNCOI~ COMP RIG DOWN DOUBLE SHEAVE & HANG SINGLE SHEAVE. 21:30 - 23:30 2.00 RUNCOI~ COMP SPLICE NEW HEAT TRACE PIGTAIL. 23:30 - 00:00 0.50 RUNCOr~ COMP LAND TBG HANGER. P/U WT 43K, SIC WT 33K. RILDS 5/20/2001 00:00 - 00:30 0.50 RUNCOr~!:) COMP SET TWC. DRAIN BOP & HARD LINES. 00:30 - 03:00 2.50 BOPSUiq P COMP N/D BOPE. 03:00 - 04:30 1.50 WHSUR P COMP N/U & TEST TREE & ADAPTER FLANGE. FINAL CHECK ON ESP LINE & HEAT TRACE. 04:30 - 05:30 1.00 WHSUR P COMP PULL TWC & INSTALL BPV. 05:30 - 06:00 0.50 WHSUR P COMP SECURE WELL & CLEAN CELLAR. RELEAS RIG @ 0600 HRS, 5-20-01. Printed: 5/2412001 3:03:10 PM MILNE POINT, ALASKA TO: J.BIXBY/SMITH FROM: O'Malley WELL# IMPE-30 Main Category: Maint Sub Category: Freeze protect Operation Date: 5/22/01 Pump Objective: Frz. Protect the well alter re-completion Operation: TGSM, MIRU: Pressure tested surface equipment to 2000 psi. Start down tubing with diesel. Pumped 7 bbls @ 2500 psi .65 bbls/min. RU to annulus and pumped 40 bbls of diesel @ 1.8 bbls/min 1050 psi. RD. Conclusion: Well freeze protected alter re-completion. SIWHP= 0# IA= 0 OA= Diesel Used [ 47 I AFE# 337234 9335-070-725 Diesel = $1974 AFE#337234 9335-070-780 HB&R= $ 875 Methanol Used [none BP Amoco Baker Hughes INTEQ Survey Report COml~ny: BP Amoco l;leid: Milne Point Site: M Pt E Pad Well: MPE-30 Wdll~: MPE-30AL1 Dale: 6/19/2001 l'nne: 10:26:57 Page: 1 Co-erdinnte(NE) Reference: Well: MPE-30, True North Vertical (1'VD) Reference: MPE-30:57.05 57.0 Section (VS) Referent: Well (0.00N,0.00E,40.83Azi) Snrvey Calenlatlea Metimd: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: M Pt E Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013798.68 ft 569440.72 ft Well: MPE-30 Slot Name: 30 MPE-30 Well Position: +N/-S 2593.85 ft NortMng: 6016390.34 ft Latitude: 70 27 18.492 N +F_J-W -196.55 ff Easting: 569220.04 ff Longitude: 149 26 6.428 W Position Uncertainty: 0.00 ff Latitude: 70 RECEIVqD , Longitude: 149 26 0.655 W North Reference: True JUL 0 9 2001 Grid Convergence: 0.53 deg. /!. 8040.00 4471.62 KOP 9290.00 4481.03 Projected to TD Survey ~D Incl, :'" ':Azim TVD SSTVD N/S:" E/W "' MapN' MaPE DES VS deg.; '. ft: =fi,: = .fi.:: ' :. 'ff. ' 8040.00 88.29 90.56 4471.62 4414.57 3969.72 3391.99 6020391.03 572574.68 0.00 5221.44 8060.00 85.00 91.00 4472.79 4415.74 3969.45 3411.95 6020390.94 572594.64 16.61 5234.29 8090.00 81.80 90.20 4476.24 4419.19 3969.14 3441.74 6020390.91 572624.43 10,99 5253.53 8120.00 83.30 93.00 4480.13 4423.08 3968.31 3471.47 6020390.35 572654.17 10.52 5272.34 8150.00 87.30 94.90 4482.59 4425.54 3966.25 3501.30 6020388.57 572684.00 14.75 5290.28 8180.00 91.00 94.30 4483.03 4425.98 3963.84 3531.19 6020386.44 572713.92 12,49 5308.00 8218.00 96.30 92.10 4480.62 4423.57 3961.72 3569.04 6020384.67 572751.78 15.10 5331.15 8250.00 96.30 89.50 4477.10 4420.05 3961.28 3600.84 6020364.53 572783.58 8.08 5351.60 8281.00 94.00 83.80 4474.32 4417.27 3963.09 3631.65 6020386.62 572814.36 19.76 5373.11 8310.00 94.10 81.40 4472.27 4415.22 3966.81 3660.33 6020390.61 572843.01 8.26 5394.68 8340.00 93.80 77.90 4470.20 4413.15 3972.19 3689.77 6020396.26 572872.39 11.68 5418.00 8371.00 94.30 73.20 4468.01 4410.96 3979.90 3719.70 6020404.25 572902.25 15.21 5443.41 6401.00 93.60 68.90 4465.94 4408.89 3989.62 3748.00 6020414.23 572930.46 14.49 5469.26 6431.00 94.60 66.30 4463.80 4406.75 4001.02 3775.67 6020425.88 572958.01 9.26 5495.98 8461.00 94.70 63.50 4461.37 4404.32 4013.70 3802.74 6020438.82 572964.97 9.31 5523.28 8491.00 92.80 62.30 4459.40 4402.35 4027.34 3829.39 6020452.70 573011.48 7.49 5551.02 8521.00 92.80 57.40 4457.94 4400.89 4042.38 3855.29 6020467.98 573037.24 16.31 5579,34 8551.00 92.80 52.60 4456.47 4399.42 4059.57 3879.83 6020485.39 573061.62 15.98 5608.38 0.00 0.00 0.00 40.83 Survey: MWD Start Date: 5/6/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation , , , MD: ' TVD ,; ," Wellpath: MPE-30AL1 Drilled From: MPE-30AL1PB1 500292290360 Tie-on Depth: 8040.00 ff Cnrrent Datum: MPE-30:57.05 Height 57.05 ff Above System Datum: Mean Sea Level Magnetic Data: 5/112001 Declination: 26.35 deg Field Strength: 57449 nT Mag DIp Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg BP Amoco '~.~ Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 6/19/2001 11=ne: 10:26:57 Pa~e: 2 Fidd: Milne Point Ce-ordinate(NE) Reference: Well: MPE-30, True North Site= M Pt E Pad Ve~lcai ('IYB) Reference: MPE-30:57.05 57.0 Well: MPE-30 ~tl~m (V~ i{~,~mm~-. Well (0.00N,0.00E,40.83Azi) Welllm~: MPE-30AL1 Sam, e~ Calcalatle,, Merited: Minimum Curvature Db: Oracle Survey MD Imei Azhn TVD SSTVD N/S E/W MapN MapE DLS VS ff d~l deg n ff ~[ ft ft ft de~lOOff ff 8581.00 89.60 49.60 4455.84 4398.79 4078.40 3903.16 6020504.43 573084.77 14.62 5637.89 8628.00 89.90 47.50 4456,05 4399.00 4109.51 3938.39 6020535.87 573119.71 4.51 5684.46 8670.00 89.00 41.30 4456.45 4399.40 4139.50 3967.76 6020566.13 573148.79 8703,00 89.50 36.60 4456.88 4399.83 4165.15 3988,50 6020591.97 573169.29 8734.00 88.60 31.00 4457.40 4400.35 4190.90 4005.73 6020617.87 573186.28 8768.00 90.00 25.00 4457.81 4400.76 4220.90 4021.69 6020648.02 573201.96 8802.00 89.30 19.20 4458.02 4400,97 4252,39 4034.47 6020679.62 573214.45 8830.00 88.80 15.10 4458.49 4401.44 4279.14 4042.73 6020706,44 573222.45 8862.00 90.50 12.00 4458.68 4401.63 4310.24 4050,22 6020737.61 573229.66 8892.00 87.90 6,50 4459,10 4402.05 4339.83 4055.04 6020767.25 573234.20 8924.00 88.50 8.20 4460.11 4403.06 4371,55 4059.13 6020799.00 573238.00 8951.00 87,30 5.40 4461.10 4404.05 4398.34 4062.33 6020825.81 573240.94 14.92 5726.35 14.32 5759.32 18.29 5790.07 18.12 5823.20 17.18 5855.39 14.75 5881.02 11.05 5909.46 20.28 5935.00 5.63 5961.68 11.28 5984.04 8980.00 86.70 9.30 4462.61 4405.56 4427.06 4066.03 6020854.56 573244.38 9011.00 85.40 14.40 4464.75 4407.70 4457.32 4072.38 6020864.87 573250.45 9040.00 86.00 16.80 4466.93 4409.88 4485.17 4080.16 6020912.79 573257.96 9070.00 87.30 22.00 4468.68 4411.63 4513.40 4090.10 6020941.12 573267.64 9104.00 89.30 25.70 4469.69 4412.64 4544.48 4103.64 6020972.32 573281.09 9130.00 88.10 29.30 4470,28 4413.23 4567.53 4115,84 6020995.48 573292.88 9164.00 86.90 35.50 4471.76 4414,71 4596.20 4134.03 6021024.31 573310.80 9196.00 86,50 37.50 4473.61 4416.56 4621.88 4153.03 6021050.16 573329.56 9246.00 85.10 43.00 4477.27 4420.22 4659,92 4185.24 6021088.50 573361.41 9290.00 85.10 43.00 4481,03 4423.98 4691.98 4215.14 6021120.84 573391,00 13.59 6008.19 16.94 6035.23 8.51 6061.39 17.84 6089.26 12,37 6121,75 14.59 6147.04 18.56 6180.63 6.36 6212.48 11.32 6262.32 0.00 6306.13 F~EFEi~ENCF IN FOI~MATI©N CoJo[d~l~@te [N/E <elerence Wei~cenlre MPE 3C true Nodh vemca] ¢lVD Re~e~ence S~ ~tem Mean Ssa Lev6 Secllml~ /VS qelerenr~ S~Ol 00 {0 00N MeaSured Deuth Reference MPE-3¢~ 57 O5 57 O5 Calculallon MethO~ M~mmum CurVature 3200 34OO 3700 ~4000 4100 560( 5400 480( ~460£ Magnetic Field ~trength 57449nT Dip Angle 80 79' Dale 5/1 £200 Model BGGM2001 1600 ]~uu 2000 2200 24OO 2600 2800 3000 3200 340O 360( 38OO ¢300 42O0 ,~400 4600 48(508[) 52O0 5400 5600 5800 6000 3800 390[~ ~nnn 4100 4200 4300 4400 450O 4600 47O0 4800 49O0 5000 5100 5200 53OO 540O 550{~ 5~00 5r00 5800 [ 900 6000 8100 6200 6300 6400 650O 6600 6700 6800 ¢00 /000 71~ Z2 Z;~0D Z4[)8 FS00 z50( 6/I 9/2001 I0:28 ObP ZOl-ol7 BP Amoco Baker Hughes INTEQ Survey Report I~TEQ Company: BP Amoco Field: Milne Point Site: M Pt E Pad Well: MPE-30 Wellpath: MPE-30ALIPB1 Date: 6/19/2001 Time: 10:31:33 Page: 1 Co~rdimate(NE) Reference: Well: MPE-30, True North Vertical fi'VD) ]~eferemce:. MPE-30:57.05 57.0 Sen:lion OrS) R~efemm~: Well (0.00N,0.00E,41.51Azi) Snr~? Calaalatlem Metkod: Minimum Curvature Db: Oracle Field: Maine Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: M Pt E Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ff 6013798.68 ft 569440.72 ft Latitude: 70 26 Longitnde: 149 26 North Reference: Grid Convergence: Slot Name: 30 Latitude: 70 27 Longitude: 149 26 Well: M PE-30 MPE-30 Well Position: +N/-S 2593.85 ft Northing: 6016390.34 ft +E/-W -196.55 ff Easttng: 569220.04 ff Position Uncertainty: 0.00 ft w £C£1 t/ED True dUL 0 9 2001 '~'~s~a ON & ~as Cons. Co~iss/o~1. ~s.492 N Anchorage 6.428 W Wellpath: MPE-30AL1PB1 Drilled From: MPE-30A 500292290371 Tie-on Depth: 6657.00 ft Current Datum: MPE-30:57.05 Height 57.05 ff Above System Datum: . Mean Sea Level Magnetic Data: 5/712001 Declination: 26.35 deg Field Strength: 57449 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +F_J-W Direction ff ff ff deg 0.00 0.00 0.00 41.51 Survey: MWD Start Date: 5/4/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation , 'MD' ] ;'TVD , : , , ' ' ,: , : 6657.00 4412.52 KOP 8820.00 4512.91 Projected to TD Survey MD ' 'InCl Azlm ' 'IVD: ' SSTVD ' NIS ~ E/W ", MnpN ' MapE , DLS VS: 'fi' deg:i deg ft .... iff.] ': . .' ft ,:', ft.' ". ': degll00ft ff' ~ 6657.00 52.47 42.33 4412.52 4355.47 3022.18 2572.79 6019436.01 571764.40 0.00 3968.25 6687.00 58.17 41.92 4429.59 4372.54 3040.48 2589.33 6019454.45 571780.76 19.03 3992.91 6717.00 66.15 41.92 4443.59 4386.54 3060.20 2607.04 601 9474.34 571798.29 26.60 4019.41 6747.00 74.36 41,13 4453.71 4396.66 3081.32 2625.74 6019495.63 571816.79 27.48 4047.63 6777.00 79,10 38.00 4460.60 4403.55 3103.83 2644.32 6019518.31 571835.16 18,78 4076.79 6811.00 82.60 36.50 4466.00 4408.95 3130.55 2664.64 6019545.21 571855.22 11.18 4110.26 6841,00 82.10 34.40 4470.00 4412.95 3154.77 2681.88 6019569.58 571872.24 7.14 4139.83 6875.00 82.30 27,90 4474.62 4417.57 3183.58 2699.29 6019598.55 571889.38 18,95 4172.95 6900.00 83.50 26.00 4477.71 4420.66 3205.69 2710,54 6019620.77 571900.42 8.94 4196.95 6930.00 83.80 27,50 4481.03 4423.98 3232.32 2723.96 6019647.51 571913.59 5.07 4225.79 6960.00 83.80 27.40 4484.27 4427.22 3258.78 2737.71 6019674.11 571927.09 0.33 4254.72 6992.00 87.50 22.30 4486.69 4429.64 3287.72 2751.10 6019703.17 571940.22 19.65 4285.27 7025.00 90,20 21.00 4487.36 4430.31 3318.38 2763.28 6019733.94 571952.10 9.08 4316.29 7058,00 93.00 19.90 4486.44 4429.39 3349.29 2774.80 6019764.94 571963.34 9.12 4347.07 7087.00 91.00 18.70 4485.42 4428.37 3376.64 2784,38 6019792.38 571972.66 8.04 4373.90 7120.00 87.20 17.50 4485.94 4428.89 3408.00 2794.63 6019823.63 571982.62 12.08 4404.18 7148.00 86.60 17.90 4487.46 4430.41 3434.63 2803.13 6019850.54 571990.87 2.57 4429.75 7180.00 85.40 14.50 4489.69 4432.64 3465.28 2812.03 6019881.27 571999.49 11,24 4458.61 BP Amoco ~., b,o ~ ' Baker Hughes INTEQ Survey Report INTFQ Company: BP Amoco Date: 6/19/2001 Time: 10:31:33 Page: Fidd: Milne Point Co-ordlnate(NK) Reference: Well: MPE-30, True Norlh Site: M Pt E Pad Vertlml (TVD) Reference: MPE-30:57.05 57.0 Well: MPE-30 Seet~en (VS) Reference: Well (0.00N,0.00E,41.51Azi) Wellpath: MPE-30ALIPB1 Sar~ey Caicmlatlon Method: Minimum Curvature Db: Oracle Survey MD lncl Aztm TVD SSTVD N/S FJW MapN Mapg. DLS VS ff deg deg ff ff ff ff ff ff deg/100ff 7212.00 86.00 13.70 4492.09 4435.04 3496.23 2819.81 6019912.28 572006.97 3.12 4486.93 7242.00 88,20 14.00 4493.61 4436.56 3525.32 2826.98 6019941.43 572013.87 7.40 4513.47 7272.00 91.10 14.60 4493.79 4436.74 3554.39 2834.39 6019970.57 572021.01 9.87 4540.14 7310.00 93.70 17.20 4492.20 4435,15 3590,89 2844.79 6020007.17 572031.07 9.67 4574.37 7347.00 96.30 19.20 4488,97 4431.92 3625.90 2856,30 6020042.28 572042.25 8.85 4608.22 7385.00 91.80 23.00 4486.29 4429.24 3661.25 2869.94 6020077.75 572055.57 15.48 4643.73 7420.00 91.80 26,40 4485.19 4428.14 3693,03 2864.55 6020109.66 572069.88 9,71 4677.21 7453.00 91.80 29.50 4484.15 4427.10 3722.16 2900.01 6020138.93 572085.07 9.39 4709.27 7485.00 93.40 32.80 4482.70 4425.65 3749.52 2916.54 6020166.43 572101.35 11.45 4740.71 7515.00 93.50 35.60 4480.89 4423.84 3774.28 2933.37 6020191.35 572117.94 9.32 4770.41 7547,00 92,30 39.60 4479.27 4422.22 3799.59 2952.87 6020216,64 572137.20 13,03 4802.29 7583.00 92.10 43.10 4477.89 4420.64 3826.60 2976,63 6020244.06 572160.71 9.73 4838.26 7612.00 93.20 46.60 4476.55 4419.50 3647.13 2997.06 6020264.78 572180.94 12.64 4867.17 7640.00 92.90 50.80 4475.06 4418.01 3865.58 3018.06 6020283,42 572201.77 15.02 4894.90 7670.00 93.50 54.80 4473.39 4416.34 3883.69 3041,91 6020301.75 572225.45 13,46 4924.27 7700.00 92.10 57.10 4471.92 4414,87 3900.46 3066.74 6020318.75 572250.12 8.97 4953.29 7732,00 90,40 60.30 4471.22 4414.17 3917.08 3094.07 6020335.62 572277.29 11.32 4983.85 7760.00 89.50 64.40 4471.25 4414.20 3930.07 3118.87 6020348.84 572301.96 14.99 5010.01 7793.00 95.91 67.60 4469,69 4412.64 3943.47 3148.96 6020362.52 572331.93 21,70 5039.99 7830.00 91,30 74.70 4467.36 4410,31 3955.39 3183.88 6020374.76 572366.73 22.64 5072.05 7870.00 90.80 78.20 4466.63 4409.58 3964.75 3222.75 6020384,49 572405.51 8.84 5104.83 7900.00 91.40 83.00 4466.05 4409.00 3969.65 3252,33 6020389.66 572435.04 16.12 5128.11 7930.00 89.00 87.50 4465,95 4408.90 3972.13 3282.22 6020392.42 572464.90 17.00 5149.78 7962.00 87,40 90.80 4466.95 4409.90 3972.61 3314.20 6020393,19 572496.87 11.46 5171,33 7998.00 85,20 93.30 4469.27 4412.22 3971.33 3350.09 6020392.24 572532.77 9.24 5194,16 8032.00 87.80 91.60 4471.35 4414,30 3969,88 3383.99 6020391,11 572566.68 9.13 5215.54 8066.00 89.90 87.20 4472.03 4414.98 3970.23 3417.97 6020391.78 572600.66 14.34 5238.33 8104.00 88.20 81.30 4472.66 4415.61 3974.04 3455.76 6020395.93 572638.40 16.16 5266.22 8144.00 86.30 83.00 4474.58 4417.53 3979.49 3495.34 6020401.76 572677.92 6.37 5296.54 8174.00 87.00 78.60 4476.34 4419,29 3984.28 3524.89 6020406.82 572707.43 14.83 5319.71 8207.00 87,30 75.50 4477.98 4420.93 3991.67 3557.01 6020414.50 572739.47 9.43 5346.53 8250.00 90.30 71.70 4478.88 4421.83 4003.80 3598.24 6020427.02 572780,58 11.26 5382.94 8295.00 90.40 66.40 4478.60 4421.55 4019.89 3640.25 6020443,49 572822.44 11.78 5422.83 8333.00 86.70 59.50 4479.57 4422.52 4037.15 3674.05 6020461.06 572856.08 20.60 5458.16 8363.00 88.60 58.00 4480.80 4423.75 4052.69 3699.68 6020476.85 572881.55 8.07 5486.79 8390.00 89.20 54.20 4481.31 4424,26 4067.75 3722.08 6020492.11 572903.81 14.25 5512.91 6420.00 87~70 50.00 4482.13 4425.08 4086.17 3745.74 6020510.74 572927.30 14.86 5542.38 8451.00 84.00 46.20 4484.37 4427.32 4106.80 3768.74 6020531.59 572950.11 17.08 5573.08 8480.00 83,50 42.80 4487.53 4430.48 4127.36 3788.95 6020552.33 572970.12 11.78 5601.87 8510.00 81.80 39.40 4491.37 4434.32 4149.78 3808,50 6020574,93 572989.46 12.59 5631.62 8540.00 82.30 35.50 4495.52 4438.47 4173.36 3826,57 6020598.67 573007.30 12.98 5661.25 8570.00 82.20 33,20 4499.56 4442,51 4197.90 3643.34 6020623.37 573023.85 7.60 5690.74 8600.00 83.50 31.50 4503.30 4446.25 4223.05 3859.26 6020648.66 573039.54 7.10 5720.12 8630.00 87.10 25.40 4505.76 4448.71 4249.32 3873.50 6020675.06 573053.52 23.55 5749.23 8660.00 87.10 23.50 4507.28 4450.23 4276.59 3885.90 6020702.44 573065.67 6.33 5777.67 8691,00 88,10 19.50 4508,58 4451.53 4305.41 3897.24 6020731.36 573076,75 13.29 5806.97 8720.00 87.70 16.60 4509.64 4452.59 4332.96 3906.22 6020758.99 573085.47 10.09 5833.55 8754.00 88.40 11.60 4510.80 4453.75 4365.90 3914.50 6020792.01 573093.44 14.84 5863.70 8782.00 88.10 5.60 4511.65 4454.60 4393.56 3918.68 6020819.70 573097.36 21.45 5887.19 8820.00 88.10 5.60 4512.91 4455.86 4431.36 3922.39 6020857.53 573100.72 0.00 5917.95 ALASKA OIL AND GAS CONSERVA~I~iON COPl~TISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit- MPE-30AL1 BP Exploration (Alaska) Inc. Permit No: 201-017 Sur Loc: 3853'NSL, 1923'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc. 4271'NSL, 166'EWL, Sec. 30, T13N, R11E, UM Dear Mr. Johnson: Enclosed is the 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 from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPE-30A, Permit No 201-011, API 50-029-22903-01. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount Commissioner BY ORDER OF THE COMMISSION DATED this / ~--~ day of February, 2001 dlf/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA t/t-'~/,.~ ALASKAi .AND GAS CONSERVATION COMM(' ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas ~, S~r~e Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KBi 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 57.05' Milne Point Unit / Kuparuk 3. Address 6. Property Designation River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 C£~'~'~,~ ADL047438 4. Location of well at surface 7. Unit or Prope-rt~ ]q'~rfl'& .~ 11. Type Bond (See 20 AAC 25.025) 3853' NSL, 1923' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 1643' NSL, 693' EWL, SEC. 19, T13N, R11E, UM MPE-30AL1 Number 2S100302630-277 At totcJ, depth .~..~ 9. Approximate spud date .,.. ~,N, uS<;/_~~= i,~ ,L' 3N, Amount $200,000.00 12. Distance to dearest property line 13. Distance to nearest well 14. Number of acres in property .15. Proposed depth (MD and TVD) -~,~,,¢/'~,"%DL.047.45~, 2~D/'t~,' ~) No Close Approach 2560 9775' MD / 4384' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6655' MD Maximum Hole Angle 105.70 ° Maximum surface 1400 psig, Attotal depth (TVD) 4000' / 1800 psig 18. Casing Program l Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Wei.qht Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 STL 3110' 6665' 4355' 9775' 4384' Uncemented Slotted Liner i'~ I'"_ t~l-' I V t- ~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. JAN Z ;~ ZUU1 Present well condition summary Total depth: measured 7200 feet Plugs (measured) Alaska Oil & Gas Cons. Commission true vertical 4744 feet Anchorage Effective depth: measured 7169 feet Junk (measured) Fish at 7086' true vertical 4725 feet Casing Length Size Cemented MD TVD Structural Conductor 84' 13-3/8" 250 sx Arcticset I (Approx.) 120' 120' Surface Intermediate Production 7135' 5-1/2" 747 sx Coldset III, 70 sx 'G' 7169' 4725' Liner Perforation depth: measured 6758' - 6778'; 6845' - 6865' true vertical 4474' - 4487'; 4528' - 4540' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby Certify that th_,e foregoing is tlr~and correct to the best of my knowledge ' / Signed Mark Johnson'~~0,. ~,~) -'~~. Title CT Drilling Engineer, Date [/~.0'~ }/~{ , .' .'": ..i ;.' ::: ".: .:' ..'..'.':."i. :..".: :..";"' .:.'..: :'"':::'.':.::.:~Z/:% i:':':": ;" "..'.:"'.'.!.'i::" '.com.m:lsSlonuse:OnlY.:~..:.?..'"'.....:::..':.;,': :::.;:: ..:~.i'.::;.!';., ;'.':....::.'... :!::.:.:.?:~:.. :'.....'..::'.[~...:: :,!:.....:' :::...?.;:.i:i::'..' :..'~ ..'..:.. ,,,, Permit Number I APl ~¢-nber I Approval. Date I See cover letter .,~/~ (.~/'~ 50-029-22903-60 ¢,~ '"/.z~_.. ~ / for other requirements ~;°nditions of Approval: Samples Required [] Yes ,1~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures .~ Yes [] No Directional Survey Required ~,~ [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,~3.5K psi for CTU Other: '. ', :~...;~l~'/.~,t.. ,:.i;l('i~hl~D l~\' by order of L'~edrrlou Rt --Approved By Commissione~' the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX Milne Point E-30a and E30a L1 Sidetracks - Coiled Tubing Drilling Summary 0f Operations: E-30 will be sidetracked with two horizontal wellbores (E-30a and E-30a L1 ) to target Schrader Bluff OA reserves. Coiled Tubing Ddlling (CTD) will perform the sidetracks. Pdor to CTD ardval, Nabors 4ES will pull the existing ESP completion and abandon the Schrader OA & OB perforation intervals (sundry form 10-403 submitted). ,CTD Drill and Complete E-30a pro.qram: Planned for February 15, 2001 1) Set whipstock at ~6750' (in 5 %" casing at 52° wellbore inclination) - service coil jb\\-~ 2) Mill window through 5 %" and mill 5' of openhole - service coil. 3) MIRU CTD dg - Drill horizontal sidetrack E-30a from window to TD targeting Schrader Bluff OA sand interval as per attached directional plan. 4) Complete with slotted liner from TD to ~10' inside of 5 %" casing. CTD Drill and Complete E-30a L! Lateral proaram: Planned for February 21,200! 5) CTD set flowthrough whipstock at 6655' (in 5 %" casing at 52° wellbore inclination) 6) Mill window through 5 %" and mill 5' of openhole 7) Drill horizontal lateral E-30a L1 from window to TD targeting Schrader Bluff OA sand interval as per attached directional plan. 8) Complete with slotted liner from TD to ~10' outside of casing Mud Program: , Steps 1&2: Seawater . Steps 3-8: FIo-Pro (8.9-9.4 ppg) Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to PBU DS-4 Grind & Inject · Class I wastes will go to Pad 3 for disposal. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Casing Program: · E-30a - 2 7/8", 6.16~, L-80, STL slotted/pre perforated liner will be run from TD to approximately 6740' · E-30a L1 - 2 7/8", 6.16#, L-80, STL slotted/pre perforated liner will be run from TD to approximately 6665' Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 'psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plans for E-30a & E-30a LI. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Resistivity logging in sections of the openhole Hazards · No significant faults are expected to be crossed, lost circulation risk is Iow. Res. pressure is 8.7 ppg. E-30 has not had a recent H2S reading due to long term shut-in. However, Milne Point production has historically been sweet. Highest H2S on the pad is 8 ppm (E-22). Reservoir Pressure · Res. pressure is approx. 1800psi @ 4000ss (8.7 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 1400 psi. E-30a and E-30a L I Potential Drilling Hazards Post on Rig . . Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut down the operation and discuss the situation before making the next operational move. SAFETY FIRST. H2S is not expected on this well. E-30 has not had a recent H2S reading due to long term shut-in. However, Milne Point production has historically been sweet. Highest H25 on the pad is 8 ppm (E-22). 3. BHP is expected to be approx. 1800psi (8.7ppg) @ 4000'ss. 4. Maximum anticipated well head pressure w/full column of gas is 1400psi. 5. Lost circulation risk is Iow with no significant faults expected to be penetrated. RECEIVED J/~N 1 ~ ;~001 ^la~ka Oil & Gas Cons. Commission Anchorage Tree: 29/16"-5M MPU E 30 Oi',g. DFElev.= 57.0' (N 27E) Wellhead: 7" 5M Varco ADRS-7 Weld on style -~"='r!"-. orig. GL Elev. = 23.2' DF to 7"' csg. hng. = 33.6' (N 27E) Tb,q. Hng: 2 7/8" x 11" FMC w/2 7/8"~! N~CT T&B and 2.5" CIW H BPV |[ ~ - ~ 7" 26 ppf L-80 Btrc. profile I 115' I 7"x 5.5" X-Over 13 3/8" 72 ppf, L-80 ~ / / KOP @ 500' ! Camco 2 3/8" x 1" Max. hole angle = 69 to 73 deg. ! sidepocket KBMM GLM I "~" I from 3950' to 5850' | Hole angle thru' perfs =~_ deg. / ~'Z° I 5.5" Port Collar Cementer ~ 1336'md ~ Centrilift heat trace 2 3/8" 4.70" ppf, J-55, 8 rd EUE tbg.. ! ( drift ID =1.995 ", cap. = 0.00387 bpf ) I / 5.5" 15.5 ppf, J-55, Btrc. prod. casing ! ( drift ID = 4.950", cap. = 0.0238 bpf ) ' / / Camco 2 3/8" x'l I sidepocket KBMM GLM I 6,509~6 ' 2-3/8" HES XN-Nipple ( 1.791" id ) KUDU 110TP/1800 PCP, 65L~~- Centrilift flex shaft intake tvd Stimulation Summary Centrilift seal section OA / OB Sands - Limited entry frac w/119.6 M# fst3dblresh6aflashsn of PropLoked 16/30 Badger prop. behind pipe. ' Centrilift FMH series, , 54 hp motor, 1020 v. / 35 amps. [ 9:01 Gear Box ] ,' , 6,569 Perforation Summary Centrilift PHD Ref lo.q: , I Two 5.5" x 20' short jts. f/6320' to 6359' md Size SPF Interval (TVD) I I 'OA' Sa.d I! 3 3/8" 0.6 6758'- 6778' (4475'- 4484') I I 'OB' Sand I ! I * fish - three 1" x 4" slip dies fish - 90 ea, 7/8 d~a., 1.3 E.g. ball sealers J k 5.5" float collar (PETE) 5.5" float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 08/05/98 JBF Drilled and Cased by Nabors 27E .WELL E-30 10/20/98 MDO Completion w/heat trace 4 ES APl NO: 50-029-22903 BP EXPLORATION (AK) RECEIVED JAN I 2 ZOO1 Alaska Oil & Gas Cons, Commission Anchorage M P -30a & L1 Proposal ESP completion installed by Nabors 4ES after CTD is .~ completed 2 7/8" Slotted Liner 6665'-9775' Whipstock at 6655' RECEIVED JAN Alaska Oil & Gas Cons. Commission Anchorage 5 1/2" 15.5# long string casing MPE-30a L'I TD 9775' 3.75" Openhole Whipstock at 6745' Existing Perfs 6758-6778' 6845-6865' CIBP at 6750' 2 7/8" Slotted Liner 6740'-10361' MPE-30a 3.75" Openhole TD 10361' MOJ 1/11/01 5 1/2" Float Shoe 7169' BP Amoco WELLPATH DETAILS Plan#2 MPE-301~ ,~ ~,~ t 500292290361 Parent Wellpath: MPE-30 Tie on MD: 6655.00 Vertical Section Origin: Slot- 30 (0.00,0.00) Vertical Section Angle: 130.00° Rig: Depth Reference: MPE-30:57.05 57.05ft Co-ordinate (N/E) Reference: Well Centre: MPE-30, True North Vertical ('EVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot- 30 (0.00,0.00) Measured Depth Reference: MPE-30:57.05 57.0 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Annotation 4307.02 6577.31 Te4n Point 4354.33 6~L55.00 Kick-off Point 4471.62 6992.12 1 4410.90 7419.18 2 4404.93 9O54.79 43 4391.68 8932.42 4384.00 9774.41 T D Azimuths to True North Magnetic North: 26.46° Magnetic Field Strength: 57447nT Dip Angle: 80.79° Date: 1/5/2001 Model: BGGM2000 Weapa~th: [MPE-30/P~3n#2 MPE-3OL21 C~ea~ed By: B,-ij Po(n~ Dale: 115/2001 m Plot 1/5/2001 3:27 PM ObP ,i BP Amoco 'l' /._l Baker Hughes INTEQ Planning Report i'~:i:'~'Q ....................... Company: BP Amoco Date: 1/5/2001 Time: 14:37:07 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPE-30, True North Site: M Pt E Pad Vertical (TVD) Reference: System: Mean Sea Level Well: MPE-30 Section (VS) Reference: Well (0.00E,0.00N,130.00Azi) Wellpath: Plan#2 MPE-3011~ O, l~ ~ Survey Calculation Method: Minimum Curvature Db: Oracle '-:~ --:- ........ ........ ::?-:-: ......... :7----~-_--:_--~---~-~--7 ...... .~w:-- ~--w-:- ....... - 7-:~---'~_- -- -~ ....... : ....... ~: ......... y':-?--~:_~;'T:.-'::'-_-'. · .:,,:'z:~:.;.~- -~-.~-:-7-_--_.--7:-T7..'_.:~--:_-:-£:-,_-,-::~_-~: ~ '7'~-'_-~ ~-_--:'-:-:----. -.: ?~ ,:~..~:-::7:-yz--: :2-:: ~:z~r:7.z':~: 7_'~ Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: M Pt E Pad TR-13-10 UNITED STATES · North Slope Site Position: Northing: 6013798.68 ft Latitude: 70 26 52.982 N From: Map Easting: 569440.72 ft Longitude: 149 26 0.655 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.53 deg Well: MPE-30 Slot Name: 30 MPE-30 Well Position: +N/-S 2593.85 ft Northing: 6016390.34 ft Latitude: 70 27 18.492 N +E/-W -196.55 ft Easting: 569220.04 ft Longitude: 149 26 6.428 W Position Uncertainty: 0.00 ft Wellpath: Plan#2 MPE-30L2 Drilled From: MPE-30 500292290361 Tie-on Depth: 6655.00 ft Current Datum: MPE-30:57.05 Height 57.05 ft Above System Datum: Mean Sea Level Magnetic Data: 1/5/2001 Declination: 26.46 deg Field Strength: 57447 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 130.00 2~'.~i~_-~,~ii-i~2~ "'~£2.~-~,.21~.~ .22..~2 '~ii~ ~i ~'__.~.-.22'~. ~i. ~' ~'_' Plan: Plan #2 Date Composed: 1/5/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ' . Name · · Description TVD +N/-S . '+E/-W · · Northing Easting Deg Min Sec 'Deg Min Sec :. .............._: ..... __2_/ ..... ~ ...................................................................................................................................................................... _2___.__:_. Ann tatio~! .~..~o n __~ i . ...... . . . .. .R .... ~ ..i'ft .ft . :.' .. . ..... : . ... 6577.31 4307.02 Tie-in Point JAN 1 g 001 6655.00 4354.33 Kick-off Point 6992.12 4471.62 1 7419.18 4410.95 2 Alaska Oil & Gas Cons. Commission 8054.79 4404.95 3 Anchorage 8932.42 4391.65 4 9774.41 4383.97 TD Plan Section Information MD". ' Incl: Azim "TVD +N/.S +E/-W' ' DLS' "BUild Turn TFO Target ft...: deg deg' ft ft ft · deg/100ft deg/100ft deg/100ft: deg · 6577.31 52.63 42.26 4307.02 2975.39 2530.22 0.00 0.00 0.00 0.00 6655.00 52.34 41.90 4354.33 3021.12 2571.52 0.52 -0.37 -0.46 224.45 6992.12 105.70 177.01 4471.62 2892.91 2770.96 40.00 15.83 40.08 106.60 7419.18 90.00 217.73 4410.95 2500.00 2645.00 10.10 -3.67 9.54 107.44 8054.79 90.96 153.68 4404.95 1900.00 2585.00 10.08 0.15 -10.08 -88.93 8932.42 90.42 241.49 4391.65 1143.00 2345.00 10.00 -0.06 10.01 89.62 9774.42 90.43 157.27 4383.95 418.35 2090.05 10.00 0.00 -10.00 -89.61 3S CTD BOP Detail ~ CT Injector Head Methanol Injection tis 7" WLA Quick onnect 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR % Stuffing Box (Pack-Off), 10,000 psi Working Pressure '~ I -- 7" Riser I 5000 psi working pressure IBlind/ShearI 12 3/8" Combi Pipe/Slil~ Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic 2" Side outlets I 2 7/8" Combi Pipe/Slip 2 3/8" Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve 2 flanged gate valves MOJ 12/29/O 0 Tubing Spool 7" Annulus 9 5/8" Annulus RECEIVED JAN 1 2 ;~001 Alaska Oil & Gas Cons. Commission Anchorage VENDOR ALASK^O I LA OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 100. O0 100. O0 122100 PYMT HANDL CK122100K :OMMENTS: Pee INST' S/H nit To D~ill - Sondea X4 -'ee 750 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. __ _ :~!.R. Slr':~,TI0..'~ .~.B A N I~:]~JF A$~D .':-~. '!!'i':~.~O.-:;!§'~::.1¢~12 iiii;~i;:.:':':::-;ii::~;:~-:~: ' ' ":;i;;i;i. :i-;:~.;: .:~!:i~!!!?'-':"::i::!i;..:.::.;::: ;"i.'}":'::-;; ;;i ';;:'::'!: '-'~ ''~: ~::~^~.o~ -:::;::'.:-,?.- -::~:~(~;.' '::'~:~;:..:~?::? :~:~: ;~:~;:?:; .... .::.~t:;: .... ~:~.-::~:::'~: .~;~:::;~ ::~:::~::~,.~ ....... :~.::.:~.;.:::;:.' --;.-..:::~:~::~:~:~¢'-;:. :::::::::::::::::::::: 412 . PAY' ~?~ '~:.~:;~?? :~;;;';~:;~;:" ';]-:~-":-':?:' '::'.~':;:-~ ";?:~:~:?:~? ' DATE ;]~:;~;;:.~.: '?:~}-:.-:?: ::':"': .::::"~'MouNT AND ]~;~:D~;:'~;-:- '-;-~ .: :.:::-;~ '.:.; .. ~::: .: AK 99501 ~ . .~ . .. , , WELL PERMIT CHECKLIST COMPANY INIT CLASS FIELD & POOL ADMINISTRATION 1. Permit fee attached.-~ .................... 2. Lease number appropriat~ ~'..~..~,;,/Q: '.~-~./ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available-in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can-be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 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 weilbore separation proposed ............. 23. If diverter required, does it meet regulations .......... ENGINEERING WELL NAME.~-~.) ~4. / PROGRAM: exp dev V redrll serv wellbore sag v' ann. disposal para req. ~V/ /¢'~_.~//_..... GEOL AR~ ' ~ UNIT~ ~/~~ ON/OFF SHORE ~ N . N (Y~ N . .~ I PR DATE I GEOLOGY 24. 25. 26. 27. 28. 29. 30. 31. 32. APPR DATE 33. Drilling fluid program schematic & equip list adequate ..... ~ N BOPEs, do they meet regulation ....... -'-' '" ......... BOPE press rating appropriate; test to ~.~-(~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable.. ............... Y N~ / ~. (/ i ' VV_ . Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones .... ......... Y N Seabed condition survey (if off-shore) ........... Contact name/phone for weekly.progress reports [expl~r, efory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not cimumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSIgN: ,~-L~ ,.v-,,,.... .... [~qS "' Commentsllnstructions: I§ I§ Z -4 "I- c:~r~soffice\wordian\diana\checklist (rev. 11101//00) 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 APPEN. DIXi ., No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 01/09/20 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/09/20 151686 01 1.75" NaviGamma - Gamma Ray Slim *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: WR3tP. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 6486.0000: STOP.FT 8820.0000: STEP.FT 0.5000: NULL -9~9.2500: COMP COMPANY: WELL WELL: FLD FIELD: LOC LOCATION: CNTY COUNTY: STAT STATE: SRVC SERVICE COMPANY: TOOL TOOL NAME & TYPE: DATE LOG DATE: API API NYUMBER: -Parameter Information Block #MNEM. UNIT SECT. TOWN N RANG PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 Value 25 : T1 3N : R1 0E : MSL : 0 : RKB : 57 : KB : 57 : N/A : N/A : N/A : DIRECTIONAL : CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing AbsenE Value BP Exploration, Inc. MPE-30A-L1-PB1 Milne Point Unit 3863' NSL, 1923' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 04-May-01 500292290371 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX,RPCHX,RACHX,RPCLX) presented is realtime data. (4) Well MPE-30A-L1-PB1 was drilled as a sidetrack of Well MPE-30. (5) The sidetrack began at 6657' MD (4355' SSTVD). (6) Baker Hughes INTEQ Runs 3 through 7 utilized the Orient Express with Ultra Multiple Propagation Resistivity (USMPR) services from 6674' MD (4365' SSTVD) to 8820' MD (4456' SSTVD) . (7) The interval from 8792' MD (4455' SSTVD) to 8820' MD (4456' SSTVD) was not logged due to sensor to bit offset. (8) The data presented here is final. Per BPX instructions the Gamma Ray from this log is the PDC and such it has not been depth shifted. (9) A Magnetic Declination correction of 26.35 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX ROPS TVD RACLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA N/A N/A N/A N/A DIRECTIONAL N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ! N/A No Depth Shift applied. Gamma Ray MWD is the PDC. Tape Subfile: 1 80 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD ..001 1024 *** INFORMATION TABLE: CONS MNEM VALU ............................ WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPE-30A-L1-PB1 FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR 2 ROP 3 RACH 4 P~ACL 5 RPCH 6 RPCL GRAX ROPS RACHX RACLX RPCHX RPCLX * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACH COMP 68 1 4 P~ACL COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 API F/HR 0.0 0,0 0.0 0.0 0.0 0.0 Total Data Records: 130 Tape File Start Depth = 6486.000000 Tape File End Depth = 8820.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 143 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/09/20 151686 01 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 **** REEL TRAILER **** MWD 01/09/20 BHI 01 Tape Subfile: 3 Minimum record length: 2 records... 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL 6486.0000 59.8100 -999.2500 -999.2500 6486.5000 61.0810 -999.2500 -999.2500 6500.0000 65.2130 -999.2500 -999.2500 6600.0000 52.5480 -999.2500 -999.2500 6700.0000 103.0020 -999.2500 -999.2500 6800.0000 92.4200 12.0840 11.7690 6900.0000 78.8000 14.5320 16.9460 7000.0000 69.1670 10.6510 12.1550 7100.0000 65.6720 14.3530 14.7210 7200.0000 62.9200 10.3330 10.7280 7300.0000 61.3840 16.4510 14.2470 7400.0000 63.6220 13.9020 14.0660 7500.0000 76.4670 10.5880 10.0590 7600.0000 107.2730 7.8720 7.2350 7700.0000 66.8440 9.2090 10.6740 7800.0000 62.3700 13.6790 13.7760 7900.0000 75.9400 14.9470 15.8480 8000.0000 73.8520 14.0860 15.3850 8100.0000 69.2560 8.2950 8.9040 8200.0000 66.5060 9.4610 8.7820 8300.0000 91.9160 4.3770 4.5060 8400.0000 102.2750 4.4070 4.5810 8500.0000 114.4960 3.4160 3.5860 ROP -999.2500 -999.2500 -999 2500 -999 2500 23 6940 51 8120 106 4060 146 4750 123 2050 89 8180 116.1740 78.2190 112.4860 29.1270 56.5120 124.3270 125.8270 60.3630 136.8070 123.8920 117.5230 123.6760 23.2040 RACH -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 11 8390 21 6060 13.2710 14.2760 11 3410 12 9660 14 7280 9 6130 7 0310 12 3350 13 6070 18 5070 16 4330 9 3300 8 6700 4 6510 4 6930 3.7360 RACL -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 10 7720 20 7020 14 5960 15 0310 11 0470 10 9710 13 5020 9 0580 6.9210 12.4900 13 9970 15 0780 16 5180 10 0430 7 9220 4 5490 4 7290 4 1280 8600.0000 83.1320 49.3200 7.3920 7.9140 8700.0000 57.0630 130.5520 9.7450 10.0840 8800.0000 -999.2500 134.8730 -999.2500 -999.2500 8820.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 6486.000000 Tape File End Depth = 8820.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 8.6760 10.3950 -999.2500 -999.2500 8.0790 10.0020 -999.2500 -999.2500 **** REEL HEADER **** MWD 01/09/20 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/09/20 151686 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 6485.0000: STOP.FT 9297.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC LOCATION: CNTY COUNTY: STAT STATE: SRVC SERVICE COMPANY: TOOL TOOL NAME & TYPE: DATE LOG DATE: API API NYUMBER: -Parameter Information Block #MNEM. UNIT SECT. TOWN N RANG PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 -Remarks Value ......................... 25 : T1 3N : R1 0E : MSL : 0 : RKB : 57 : KB : 57 : N/A : N/A : N/A : DIRECTIONAL : CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ............................... Starting Depth Ending Depth Level. Spacing Absent'Value BP Exploration, Inc. MPE-30A-L1 Milne Point Unit 3863' NSL, 1923' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 06-May-01 500292290360 Description ............................... Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GP~AX) and Resistivity data (RACLX,RPCHX,RACHX,RPCLX) presented is realtime data. (4) Well MPE-30A-L1 was drilled as an open hole sidetrack of the Well MPE-30A-L1-PB1. (5) The open hole sidetrack began at 8040' MD (4415' SSTVD). (6) Baker Hughes INTEQ Run 8 (open hole sidetrack) utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 8070' MD (4417' SSTVD) to 9297' MD (4425' SSTVD) . (7) The interval from 9262' MD (4422' SSTVD) to 9297' MD (4425' SSTVD) was not logged due to sensor to bit offset. (8) The data presented here is final. Per BPX instructions the Gamma Ray from this log is the PDC and such it has not been depth shifted. (9) A Magnetic Declination correction of 26.35 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX ROPS TVD RACLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA N/A N/A N/A N/A DIRECTIONAL N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ! N/A NO Depth Shift applied. Gamma Ray MWD is the PDC. Tape Subfile: 1 81 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ............................ WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPE-30A-L1 FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................... 1 GR GP~AX 0.0 2 ROP ROPS 0.0 3 RACH RACHX 0.0 4 RACL 5 RPCH 6 RPCL RACLX RPCHX RPCLX * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FP~AME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACH COMP 68 1 4 R3~CL COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 API 0.0 0.0 0.0 Total Data Records: 157 Tape File Start Depth = 6485.000000 Tape File End Depth = 9297.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 170 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/09/20 151686 01 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 **** REEL TRAILER **** MWD 01/09/20 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL 6485.0000 -999.2500 -999.2500 -999.2500 6485.5000 60.9230 -999.2500 -999.2500 6500.0000 65.2130 -999.2500 -999.2500 6600.0000 52.5480 -999.2500 -999.2500 6700.0000 103.0020 -999.2500 -999.2500 6800.0000 92.4200 12.0840 11.7690 6900.0000 78.8000 14.5320 16.9460 7000.0000 69.1670 10.6510 12.1550 7100.0000 65.6720 14.3530 14.7210 7200.0000 62.9200 10.3330 10.7280 7300.0000 61.3840 16.4510 14.2470 7400.0000 63.6220 13.9020 14.0660 7500.0000 76.4670 10.5880 10.0590 7600.0000 107.2730 7.8720 7.2350 7700.0000 66.8440 9.2090 10.6740 7800.0000 62.3700 13.6790 13.7760 7900.0000 75.9400 14.9470 15.8480 8000.0000 73.8520 15.0350 16.5020 8100.0000 70.1350 10.2090 9.1310 8200.0000 107.9750 4.5500 4.8060 8300.0000 61.3580 16.5810 16.6910 8400.0000 103.5710 4.3520 5.0180 8500.0000 62.9200 8.9390 10.0940 ROP -999.2500 -999.2500 -999.2500 -999.2500 23.6940 51 8120 106 4060 146 4750 123 2050 89 8180 116 1740 78 2190 112 4860 29 1270 56.5120 124.3270 125 8270 60 3630 55 1970 13 1490 138 9530 21 4370 124 0530 RACH -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11.8390 21.6060 13.2710 14.2760 11.3410 12.9660 14.7280 9.6130 7 0310 12 3350 13 6070 18 5070 18 0950 8 8800 4 9610 16 3330 5 4390 11 1280 RACL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10 7720 20 7020 14 5960 15 0310 11 0470 10 9710 13 5020 9 0580 6 9210 12 4900 13 9970 15 0780 17 2470 7.7760 5.7560 16,3490 6.4090 11.7590 8600.0000 80.4110 4.9340 22.6060 24.6300 8700.0000 69.5600 44.4020 24.0310 24.5250 8800.0000 63.6220 124.3270 22.7020 22.4850 8900.0000 63.2320 131.2340 23.5730 23.4540 9000.0000 76.7410 106.4060 18.0780 19.5940 9100.0000 64.7030 81.4550 16.3410 17.8680 9200.0000 50.4310 12.2470 31.7700 31.9380 9297.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 6485.000000 Tape File End Depth = 9297.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS 29 0250 27 4720 22 5440 24 1990 20 4950 19 1100 34 8180 -999.2500 25.2450 22.0000 19.0680 20.4840 21.7070 20.2800 25.3340 -999.2500