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Home My WebLink About201-0111a. 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 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6.4#4,422' 72#120' 6,673' 8,291' SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 16" If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): TUBING RECORD Uncemented Slotted Liner3-3/4" 2,246'2-3/8" 260 sx Arctic Set (Approx. 6-3/4"747 sx Coldset III, 158 sx Foamed, 70 sx 'G' 36' 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. 6,738' / 4,462'N/A N/A RES & GR 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, BOTTOM AMOUNT PULLED 3853' FSL, 1923' FEL, Sec. 25, T13N, R10E, UM 57.05' 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22903-01-00 MILNE PT UNIT E-30A MILNE POINT / SCHRADER BLUFF OIL ADL0025518, ADL0047437, ADL0047438 N/A8,626' / 4,458' 8,626' / 4,458' GL: 23.2' BF: April 27, 2001 April 24, 2001 1642' FSL, 693' FWL, Sec. 19, T13N, R11E, UM 170' FSL, 829' FWL, Sec. 19, T13N, R11E, UM Surface: x- 569220 y- 6016391 Zone- ASP4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 201-011 / 322-353Aband.: 1/24/2023 TPI: x- 571807 y- 6019484 Zone- ASP4 Total Depth: x- 571957 y- 6018013 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 9:41 am, Apr 06, 2023 Abandoned 1/24/2023 JSB RBDMS JSB 041123 xGDSR-4/14/23MGR03AUG2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 6,737' 4,462' 7,938' 4,472' 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. TPI (Top of Producing Interval). Top of Schrader 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 Authorized Name and Base of Scrader OA Formation Name at TD: 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 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 Schrader Bluff - OA Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.06 07:49:34 -08'00' David Haakinson (3533) 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-30A AOGCC 10-407 Submittal, PTD: 201-011 Date:Thursday, April 13, 2023 8:09:02 AM Morning James, After speaking with the geologist, the formation at TD is going to be the OA. Regards, Tom From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Wednesday, April 12, 2023 8:14 AM To: Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] FW: MP E-30A AOGCC 10-407 Submittal, PTD: 201-011 Hi, Can you tell me the name of the formation at TD ? thanx From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Thursday, April 6, 2023 8:47 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: MP E-30A AOGCC 10-407 Submittal, PTD: 201-011 Another 407 Kayla Junke Natural Resources Tech II AOGCC (907) 793-1225 From: Tom Fouts <tfouts@hilcorp.com> Sent: Thursday, April 6, 2023 8:34 AM 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-30A AOGCC 10-407 Submittal, PTD: 201-011 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. Hello, Please review the attached 10-407 submittal for Milne Point well MP E-30A Sundry No.: 322-353 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. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 2023-0124_Surface_Abandon_MPU_E-30A_ksj Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/24/2023 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment Petroleum Inspector MPU E-30A Hilcorp Alaska LLC PTD 2010110; Sundry 322-353 1/24/2023: I witnessed the surface abandonment of MPU E-30A after the surface cement job was complete. The PTD #, API #, Operator name, and well name were verified to be correct on the Marker Plate. The cut from all the pipe was clean and flush and the cement was hard in all wellbore spaces. This was verified by hitting with a hammer. The depth below tundra was determined to be at 3 feet below tundra by GPS. Welding went well and marker plate was fit as per regulations. No follow up needed. Attachments: Photos (4) 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.05 16:33:52 -08'00' 2023-0124_Surface_Abandon_MPU_E-30A_ksj Page 2 of 3 Surface Abandonment – MPU E-30A (PTD 2010110) Photos by AOGCC Inspector K. 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect Well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,626 feet 6,470 feet true vertical 4,458 feet N/A feet Effective Depth measured 6,470 feet feet true vertical 4,299 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / L-80 / EUE 8rd 2,223' 2,197' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 2,512' TVD 120' Oil-Bbl measured true vertical Packer 9,170'2-3/8" 8,291' WINJ WAG Water-Bbl MD 120' measured 4,462' 4,463' 4,472' 6,738' 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-011 50-029-22903-01-00 Plugs ADL0047438 / ADL0047437 / ADL0025518 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: David Gorm dgorm@hilcorp.com MILNE PT UNIT E-30A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured N/A Liner Casing Conductor Size Junk Length 1,553' Production Liner 13-3/8" 5-1/2" 2-7/8" 6,738' 120' 11,170psi 11,780psi Burst 5,380psi 4,810psi 10,570psi 11,200psi N/A N/A 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 2,670psi 4,040psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:19 am, Oct 09, 2020 Chad A Helgeson 2020.10.01 12:53:54 -08'00' SFD 10/12/2020 DSR-10/12/2020 Suspension MGR12OCT2020 RBDMS HEW 11/12/2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email:jon.arend@hilcorp.com If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 125 OA NA Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Location verified with pad map. Monobore well WBS Pictures Area map Yes Yes Onshore 09/18/20 Subsequent Good, Clean, no leaks Good, Clean STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Brian Bixby 09/20/20 Yes Jon ArendMPE-30A/MPE-30AL1 (907)240-4383 Follow Up Actions Needed: Hilcorp 201-011 / 201-017 Condition of Surrounding Surface Location: 07/28/12 312-286 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPE-30A Suspended Well Inspection 9-20-20 DATE REV BY COMMENTS 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-80 115' 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 ‘OA’ Sand Sqz’d 3 3/8” 0.6 6758’ - 6778’ (4475’ - 4484’) ‘OB’ Sand 3 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) 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”, 4.43 ft/# L-80 stl & 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’ ( north lateral ) ( south lateral ) 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 Suspended Well Inspection Review Report I nspectNo: susBDB200921135314 Date Inspected: 9/20/2020 ' Inspector: Brian Bixby Type of Inspection Well Name: MILNE PT UNIT E -30A - Permit Number: 2010110 Suspension Approval: Sundry P 312-286 - Suspension Date: 7/28/2012 Location Verified?❑ If Verified, How? Other (specify in comments) Offshore? ❑ Subsequent - Date AOGCC Notified: 9/18/2020 Operator: Hilcorp Alaska, LLC Operator Rep: Jon Arend Wellbore Diagram Avail? ❑� Photos Taken? ❑� Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 125 BPV Installed? ❑ OA: VR Plug(s) Installed? ❑ Wellhead Condition All of the valves on the appeared in good working order with working gauges on the Tubing, IA and OA. There are no VR Plugs or BPV installed. Condition of Cellar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. Surrounding Surface Condition Everything looked good. I did not see debris or sheen around the pad. ' Comments I verified the location using the pad map. No OA (monobore completion). Supervisor Comments Photos (3) attached 'TP ci(tiq Monday, September 28, 2020 Q 0 M W M >, N X m Q m Q N i O u 0 U Q m Q Qo cn � CoQ CUNT Q `n 0 3 O L NQ�a. U O b Q O M WE ►] • STATE OF ALASKA ALIIIA OIL AND GAS CONSERVATION COIVOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Inspect Well Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑✓ Exploratory❑ 201-011 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22903-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047438/ADL0047437/ADL0025518 MILNE PT UNIT SB E-30A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Rr " nru n Total Depth measured 8,626 feet Plugs measured 6,470 feet ' true vertical 4,458 feet Junk measured N/A feet C 1) Effective Depth measured 6,470 feet Packer measured N/A feetA ,,,,,/,,,, true vertical 4,299 feet true vertical N/A feet a ) :/l�r , Casing Length Size MD TVD Burst Collapse Conductor 120' 13-3/8" 120' 120' 1,661psi 5,380psi Production 6,738' 5-12" 6,738' 4,462' 4,810psi 4,040psi Liner 1,553' 2-7/8" 8,291' 4,463' 10,570psi 11,170psi Liner 2,512' 2-3/8" 9,170' 4,472' 11,200psi 11,780psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet ' ' D NOV 2' 6 2-i5 Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80/EUE 8rd 2,246' 2,220' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory E] Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numberor N if C.O.Exempt: ii VV 4 Contact Stan Porhola Email sporhola(C7hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature __ASI ��„„ ._ Phone 777-8412 Date 9/14/2015 "'`��`(RBDM SEPI 7 104 Form 10-404 Revised 5/2015g/ / ---- Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hilcorp.LLC Well Name: MPE-30A E3OAL1 Oper.Rep: Bill Kruskie PTD No.: 201-011 &201-017 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskie(Hthilcorp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 07/28/12 Type of Inspection: Subsequent Sundry No.: 312-286 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing NA IA 0 OA Condition of Wellhead: Good,No visable leaks and all gauges are installed , Well house on,Well Head sign installed, Full tree inplace.Tree is up out of landing ring see pics. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None. Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPE-30A E3OAL1 2015 Suspended Well Inspection Form • • Tree: 2 9/16" - 5M MPU E1-30A Orig. DF Elev. = 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 7" 26 ppf L 80 Btrc. 7"x 5.5" X-Over 117' and 13 3/8" 72 ppf, L-80 115' KOP @ 500' Max. hole angle = 69 to 73 deg. from 3950' to 5850' )tii,.,,,.1,,tia„..k,, (,),t: 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) 111 . 2-3/8"4.6#, L-80 EUE 8rd Tbg Mule Shoe 2223' and Two 5.5" x 20' short jts. f/ 6320' to 6359' and Cement Retainer 6470' and Pumped 60 BBL cement plug TOL @ 6511' (4.5"od. scoop guide ) 4.5"GS profile E-30a L-1 (north lateral ) 5.5" Baker whipstock top @ 6657' %..,.. i::::;11., Pre-Drilled 4 spf Window 6658'-666 1+ 2-3/8", 4.43 ft/# L-80 stl & f143 :':0I .OL (Oi D�:Oi RA @ 6666' ,... ...• r....... 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F Y $ S kA,,, 3`, ";'g';',;;11'.;;;!'-.,',1*::'''''f!..,:i!:,;.',1.1';;I:'''''''';':':i;.'j:f1'5'S'i;'4''':',',1';;:;;-,.11.l;:',1'::'„,'''il..,;.e4f;'''''':1::4!1'31!ii.-4t1:101!!4!;kil:11.i.!.4,11::!•;... }im. 4 ..!w ,, xy F, ryN V- wva- iq. v.N °F%+,as x+*•S , ..„x ` kw-,°x a`�,. _ <.�t.°..k.-., +r_. �, - r -: Ay, , ro; • • _ 0ooaoaoZ o gE0 > o -° " '" 0 0ofCi2 3 oaaCD0CDmo � a sCA n 10 Z3 a . — CO o c s "c a o o o @' a " a : ^' . , z- eti . r. n ^' iz ° to CO E 0I Cm MEM3 ec. a y a Ma s � # I et V M %v VI- ti 2 v t , E o,)i i o r} 9 r. {� i . '' 144 -4.' C ,A, ,, iic- } / ra t' 'V-''''. . CL S Oji ,.,4,‘,6,� ' f 1 ' # ! -let ,,, p., -4-- -4 "4 * Y tw,k �� it' a.e Hca CD cI o N C ; m �' ..i ,` 7 g a Q. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hillcorp Well Name: MPU E-30A Oper.Rep: Bill Kruskie - PTD No.: 2010110 Oper.Phone: 907-670-3387 - Location Verified? Yes Oper.Email: i-Milne-WellsiteSuoervisorsOhi If Verified,How? Other(specify in comments) - Onshore/Offshore: Onshore Suspension Date: 07/28/12 Date AOGCC Notified: 08/20/15 . Sundry No.: Well Completion Report " Type of Inspection: Subsequent ' Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing - Photos Taken? Yes IA 0 OA n/a Condition of Wellhead: Monobore,casing lifted off hanger. Full tree,SSV closed no flow line attached. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None Comments: Location verified by site map. Photos taken by operator available upon request. ' Attachments: none REVIEWED BY: Insp.Supry J 111501‘5 Comm SCANNED SEP 15 2016 PLB 06/2014 2015-0823_Suspend_MPU_E-30A_cs.xlsx ARKA OIL AND G STATE OF AS CONSERVATION COMAION RECEIVED REPORT OF SUNDRY WELL OPERATIONS V 1 9 2012 1. Operations Abandon Q Repair Well Plug Perforations U Perforate LJ Oth ell InsL Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown[] Stimulate - Other ❑ Re -enter Suspended Wele 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IS Exploratory ❑ -- 201 -011 -0 3. Address: P.O. Box 196612 Stratigraphie❑ Service ❑ Is. API Number: - Anchorage, AK 99519 -6612 50- 029 - 22903 -01 -00 7. Property Designation (Lease Number): 4 8. Well Name and Number: _ 1 8 ADL0047438 if 1 X37 9 {' 1 MPE -30A / MPE -30AL1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): l 10. Field /Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 8626 feet Plugs measured 6470 feet true vertical 4458.48 feet Junk measured None feet Effective Depth measured 6470 feet Packer measured None feet true vertical 4298.51 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 13 -3/8" 72# L -80 36 - 120 36 - 120 4930 2670 Surface None None None None None None Intermediate None None None None None None Production 6704 5 -1/2" 15.5# J -55 34 - 6738 34 - 4462.13 4810 4040 Liner 1618 2 -7/8" 6.4# L -80 6673 - 8291 4422.38 - 4462.78 10566 11165 Liner 2659 2 -3/8" 4.43# L -80 6511 - 9170 4323.65 - 4472.19 Perforation depth Measured depth 6673 - 8626 feet 6511 - 9290 feet True Vertical depth 4422.38 - 4458.48 feet 4323.65 - 4481.13 feet Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.6# L -80 32 - 2246 32 - 2199.66 Packers and SSSV (type, measured and true vertical depth) None None None Packer None None None SSSV 12. Stimulation or cement squeeze summary: SCANNED JAN 2 8 2013 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 74 3 16 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑✓ + Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil II Gas U WD$MJ GSTOR III WINJ • WAG ❑ GINJ II SUSP El - SPL 1111 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature al C Phone 564 -4424 Date 9/19/2012 RSDMS SEP 2 0 7012 40 1 Form 10-404 Revised 11/2011 A (W--4" Submit Original Only Daily Report of Well Operations ADL0047438 ACTIVITYDATE I SUMMARY • = • 1 uspen•e• we si e i `4 - c ion. 'Vi nessing waive. •y uc eve. WH is removed and well guard in place. No abnormalities encountered. Location is clean, no leaks found on or around the well. Monobore well. Report and photos sent to WIC. 8/25/2012 • • • • Milne Point Unit Well MPE -30A & MPE- 30AL1, PTD 2010110 & 2010170 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of MPE -30A & MPE - 30AL1 on 8/25/2012. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Report of Sundry Well Operations (10 -404) • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Chuck Shieve waived witnessing the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • MPE -30A & MPE -30AL1 were suspended on 7/28/2012. The work was documented in completion reports (form 10 -407) submitted 8/23/12. • MPE -30A & MPE -30AL1 are located on an active maintained pad and is accessible by the Milne Point road system • The strata through which the well was drilled is neither abnormally geopressured nor depleted. • The 5 -1/2" casing is partially collapsed at 400' • Producing zones of the well are secured with Class 'G' cement (est 6255'- 8626') • 55 barrels below and 5 barrels above a cement retainer at 6470' • The plug and casing wre pressure tested to 1500 psi. • Laterals E -30A and E- 30AL -1 are isolated and cemented below the retainer MD /M LB 09/18/12 Suspended Well Site Inspection Form • Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPE -30A Field /Pool: Milne Point Permit # (PTD): 201 -011 & 201 -017 API Number: 50- 029 - 22903 -01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 7/28/2012 Surface Location: Section: 25 Twsp: T13N Range: R10E Nearest active pad or road: E -Pad / Milne Point Road Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean / Wellhouse has been removed Pad or location surface: Good Location cleanup needed: NO Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: Nothing on pad Samples taken: No Access road condition: Good Photographs taken (# and description): Yes / Attached Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: All valves are in good working order and were left closed. Cellar description, condition, fluids: Good Rat Hole: None Wellhouse or protective barriers: Yes there is a well guard in place Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: 0 psi Wellhead Photos taken (# and description): Work Required: None Operator Rep (name and signature): Brian Bixby AOGCC Inspector: Chuck Shieve Waived Other Observers: No Inspection Date: 8/25/2012 AOGCC Notice Date: Time of arrival: 3:30 PM Time of Departure: 4:00 PM Site access method: Drive to location Tree: 2 9/16" - 5M S M PU E -30A Ori Elev. = 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 117' and I 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. P 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 2223' and Two 5.5" x 20' short jts. f/ 6320' to 6359' and Cement Retainer 6470' and .. Pumped 60 BBL cement plug TOL @ 6511' (4.5" od. scoop guide ) 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' r Window 6658' - 666 Pre - Drilled 4 spf ' :I 2 -3/8 ", 4.43 ft/# L -80 stl & fl43 RA @ 6666' TOL pbtd @ 9290' OL @ 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' i i :p Liner = 8,291' OA 108 Sands - Limited entry free wl 119.6 M# i i as of PropLoked 16/30 Badger prop. behind pipe. 9 . 'r1A' nand Sqz'd 3 3/8" 0.6 6758' - 6778' (4475' - 4484') � r� ... _u. �r.. =LIMA 3 3/8" 2 6845' - 6865' (4523' - 4560') 5.5" float collar (PBTD) 7086' and 6.5 "float shoe 7169'md DATE REV. BY COMMENTS MILNE POINT UNIT 10/20/98 MDO Completion w/ heat trace 4 ES WELL E-30A 05/21/01 MDO Sidetrack 3 -S and completion 4 -ES API NO: 50- 029 -22903 11/19/05 MDO 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) 7 , • kj\-( ,,..---7 / • ..... , „ , , , , „ ,,. „ „ f 1■ ,..,' , „ .44c ( , r ,..-.,,.. ' Enter/Exit 4 r r _ s lyrf:6 b (NI t C\J 1l110 o 3 ' 8 I _ . 33 A 2 C) 0 co 4 10 • -0— is 31 ir) Lo i 28 • CNI Ir a 4 22 • — KAVEA32-25 29 A ....... b A cy, 13 A A 5 26 A -• 30 168' 9 a ........ _ 33'i 25 • 2 21 11 • £ 7 18 --A 16 lir 30' 00 20' _ £ 23 CN I CO 24 -- ll 1 9 ,- 1 14 1 2 1 I 1 1 5 Iv I- - - — 1 i -04111-----11110- I 44 0 100' 138' : 99' 1 >„-----,\—\\)," ---'.. \\„// , 395' WFI I PROOLICER • C. 0 WFI I IWECTOR A DATE: 5130/2012 SCALE : 1" = 100 . MAP DATE : 201 M P Li - E PA D WELL SLOT W:CONDAJCTCP 0 ..... V" . ,� � MPU E Pad ,,, #µ July 6, 2011 Approximate Scale: 1 2011 - 19 c - 5 d6 k aerometric l r # ' Y t i ` • a i . ' ., '''''..- , . Za* .„'.. _ ,,,. , 7,,,, I 40.,..,/,°...., '` 0 , � � �. ad` I ♦ \ " t r ° # T # „1 ,. ,. t .. t # � _ + 4 if ..* 1R. { ♦ * "- *5*- ,,, - „ + r ♦ r > " * i Pe 1 s F a e .a - s, 'k v * . ' illigidlibt, ' it • I. rt r r . 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ERMIT i 'NG P i D.FILI... 1 . ------ .. . .,.. , 4 • , ... . iiiii �I�IMM...w....... y Ky lM 111:!_, iiim , ..1, 1 .r i .i ll .,...,,i_„.......:,..!: moimmi .v . i 11 11.11 1 griP ,,.. . ....,...., „,.:.....,.......,, Qt2. a , Vim: SM., ' al <y ... w.: ✓ a €art _ 11' :. I !, ' 1 _ .,,, , tattli vAllcikl: . . .r.: t Alice' ii t 'IC tit t't Pr' til E.30 RCL:CiVL L) • ` T • STATE OF ALASKA AUG 2 3 2012 ALASKA OIL AND GAS CONSERVATION COMMIS�If a DI & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT AND4jO clge 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended 1 b. 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 - 011 312 - 286 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 4/24/2001 50 029 - 22903 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 4/27/2001 M P E -30A 3853' FSL, 1923' FEL, Sec. 25, T13N, R10E, UM 8. KB (ft above MSL): 57.05' 15. Field / Pool(s): Top of Productive Horizon: 1642' FSL, 693' FWL, Sec. 19, T13N, R11E, UM GL (ft above MSL): 23.2' Milne Point / Schrader Bluff Total Depth: 9. Plug Back Depth (MD +TVD): 170' FSL, 829' FWL, Sec. 19, T13N, R11E, UM 8626' 4458' 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 8626' 4458' ADL 025518 & 047438 TPI: x- 571807 y- 6019484 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 571957 y - 6018013 Zone- ASP4 None 18. Directional Surve 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): y ❑ Yes ® No (Submit electronic and printed information per 20 AAC 25.050) N 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 6738' 4462' 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 -55 34' 6738' 34' 4462' 6 -3/4" 747 sx Coldset III, 158 sx Foamed, 70 sx 'G' 2 -7/8" 6.4# L -80 6673' 8291' 4422' 4463' 3 -3/4" Uncemented Slotted Liner 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 2 -3/8 ", 4.6 #, L -80 Kill String 2246' None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. c..+. - j DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6470' Cement Retainer 6255' - 8626' 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 ® 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 # AUG 2 2012 Form 10-407 Revised 12/2009 7 1- t 5.. .1 L CONTINUED ON REVERSE , r g�n� my G -.; 4 %i L JiI ` i1 L. 44971 2LOGIC MARKERS (List all formations a arkers encountered): 30. FORMATION TESTS NAME D TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top of Schrader OA 6737' 4462' None Base of Schrader OA 7983' 4472' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Reports, Well Schematic Diagram 32. I hereby certify that the going i rue d correct to the best of my knowledge. Signed: Joe Lastufk J , ___1 Title: Drilling Technologist Date: 8/2.,;//2_- MPE-30A 201 -011 312 -286 Prepared ByName/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: TPI (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 e Common Well Name: MPE -30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 1 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 — 1 PRE MOVE OFF OF MPE -19 j- 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 I 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 -.,- Common Well Name: MPE -30 l 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 • TINUE T• : • • . :41• 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" pe 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 -. 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 j 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 THE WELL FOR 15 MINUTES. STRING THE ROPES THROUGH THE SHEAVE AND BLOW DOWN THE CHOKE MANIFOLD. 01:00 - 12:00 11.00 PULL P DECOMP Pt II I Ol IT OF THE HOI F WITH THE 7 -3 /R" F11� 4 6# .I-55 FSP COMP! FTION FROM M76' TQ 3500' -- OL15 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 SEEINr ,J t 1D-15K OVFRPIII I TOP OF MOTOR C e LOCATED AT 305' AND CENTRALIZER LOCATED AT 394' WHEN REMAINING TUBING P eiicc, HUNG UP. NOTIFICATIONS CALLED AND C 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; ANn CFNTRAI I7ER WFRF I FFT IN THE HOI F 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 SHEAVE AND CLEAN AND CLEAR THE FLOOR 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 , 1 Z . 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 RAP 2 -3/8" WTS-6 TUBING INTO THE PIPESHE ST D 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 HOI F WITH THE RAKFR FISHING BHA TO 368'. - P/U WT 45K. S/O Wf 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, PJSM FOR L/D FISHING BHA. - COMPLETE POST JARRING DERRICK INSPECTION AS PER DDI SOP. 13:00 - 15:00 2.00 FISH C DECOMP POH, L/D 2 3/8" TBG AND 9 DRILL COLLARS. 15:00 - 15:30 0.50 FISH C DECOMP PULL LFIk[IQ SI IRFACF - RECOVERED ALL ESP MOTOR PARTS. - GAUGE CENTRILIZER ON BOTTOM OF MOTOR ASSY. 4.75" TIGHT, 15:30 17:30 E 2.00 FISH C DECOMP L/D FISH AND FISHING BHA. 1- CLEAR RIG FLOOR. 17:30 - 18:00 0.50 EVAL C DECOMP DEC 151Q1y,)-$Q n T WN MAD TOR 1N PDS CALIPER - 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 , .-n. ti ,_ r ` .m. !Al I t _ . 3 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 1 NPT Depth Phase Description of Operations (hr) (ft) 23:15 - 00:00 0.75 EVAL C DECOMP i • _ - r I I • - USE CONTINUOUS HOLE FILL DOWN VA. - 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 MOW g R PAM 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 I Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 EVAL 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 IIIM 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' NOGO - P/U WITH NO RESTRICTION. - MAKEAN• • : q■ 1 d ••' T DO3K,_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 DECOMP VULL.E AITING ON BAKER INFLATABLE 2.5" CEMFNT 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 ro,:t9;f2.4,7mmwmfgerwtiezoin4tetmitsco .t 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. j 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" RAKER INFI ATARI F RFTAINFR RHA - 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/O 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. 1,416 ,ET DOWN 2 5K RETAINE- 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. 1 - 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' - LFT RFMAING 5 BE S CEMENT FAi LABOOVE.. 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 18.5 PPG SEAWATER. Printed 8/7/2012 2:41:09PM ..s }" , . y Bs fir, ++ .,_ . _ �,. ; OW-U:4 4,:*ii0=0.41SeRigi4VitAtAr 74'; ,, 4t. a$. ee 1.;,,,t,* a le X 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 L/D 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' - L/D 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 TFST PASSFf) 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 KII I STRINn - 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- - 1BPM @ 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 23/8" TBG AND LAND WITH 23/8" LANDING JOINT. - ORIENT TBG HANGER TO CAMERON REPS SPECIFICATIONS. - RILDS. - NEXT WELL WILL BE MPE -14 NOT MPE -31. PREP -WORK STARTS ON WELL CELLAR AND 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 71'4"1;4 4°M, 4.1*;445KA S,44 41,43444 ;NOW0 4 1"Virt*S.I'Vti*W'''',4109* .ef&Attik:44,et, 4,03r-I'lgt**Aletigtip:4;x4:4479,4**Atk,-41:10%;444,0471004#00414:44gatr"144tr,;':.*A4441104104Ng i$44$1414 Common Well Name: MPE-30 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2012 I 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 i N!D ROPE 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 I 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, WIT CAMERON_REP 2 9/1 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 • 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 F 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. • - PA HA OVER WITH MPU ERFORM WELL FCE OPSTO , OF FACE MPE -30. ND - COMPLETE WELL WORK TRANSFER FORM WITH PAD OPERATOR ON MPE -14. - ALL VALVES SECURED. -RIG RELEASED AT 12:00 HRS FOR MOVE TO 1 MPE -14. Printed 8/7/2012 2:41:09PM Tree: 2 9/16" - 5M • Orig. Elev. = 57.0' (N 27E) Wellhead: 7" 5M Varco ADRS -7 M P U E �3� Orig. GL Elev. = 23.2' Weld on style 1 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 1 117' and I 13 3/8" 72 ppf, L -80 115' I 7 KOP @ 500' . Max. hole angle = 69 to 73 deg. from 3950' to 5850' Hole angle thru' perfs = 73 deg. 0 5.5" Port ollarCementer I 1336' and 5.5' 15.5 ppf, J -55, Btrc. prod. casing t (drift ID = 4.825 ", cap. = 0.0238 bpf) (cap. w/ 2 3/8" tbg inside = 0.0183 bpf) r ' 5 " as c ii ed at OO Ef ' 0 0, + , 2 3/8" 4.6# ppf, L-80, 8 rd EUE tbg. t 3 , 3l (drift ID = 1.995 ", cap. = 0.00387 bpf) = "'' ii 2 -3/8" 4.6 #, L -80 EUE 8rd Tbg Mule Shoe E ,µr 5 88' 04 r Two 5.5" x 20' short jts. f/ 6320' to 6359' and Cement Retainer 1 6470' and `� Pumped eo BB . cethent plug. f G•'` r TOL @ 6511' (4.5" od. scoop guide ) r ,, 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' Window 6658' - 666 '. Pre- Drilled 4 spf ,x;; „' ,,,•;,, 2 -3/8 ", 4.43 ft/# L -80 stl & f143 RA @ 6666' : "' TOL pbtd @ 9290' OL @ 6673' Liner = 9170' I I 4.6" GS profile E -30a (south lateral ) 5.5" Baker whipstock @ 6737' Window 6738' - 6744' . vro ;, I ;.. 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 frac w/ 119.6 M# II of PropLoked 16/30 Badger prop. behind pipe. T 4 'nA' Sand Sqz'd 33/8" 0.6 6758' -6778' (4475'- 4484') !�!!• - -- 'OH'Sand 3 3/8" 2 6845' - 6865' (4623' - 4560') 5.5" float collar (PBTD) 7086' and 5.5 "float shoe 7169'md DATE REV. BY COMMENTS MILNE POINT UNIT 10/20/98 MDO Completion w/ heat trace 4 ES WELL E -30A 05/21/01 MDO Sidetrack 3 -S and completion 4 -ES API NO: 50- 029 -22903 11/19/05 MDO 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) • p / � " yyy ! SEAN PARNELL, GOVERNOR ems; -��.' €w �$ 1J Li U a�d _. �� ALASKA AND GAS �A OI 333 W. 7th AVENUE, SUITE 100 CONSERQATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader O ( J BP Exploration (Alaska), Inc. •\.° P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPE -30A Sundry Number: 312 -286 Dear Mr. Reem: SI:,A NED AUG 0 2012 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, Cathy. Foerster Chair DATED this Di day of July, 2012. Encl. , v)444-- • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COM SSION APPLICATION FOR SUNDRY APPROVAL JUL 2 6 2012 20 AAC 25.280 '�` 1. Type of Request: POGGC ❑ 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 1 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Development ❑ Exploratory 201 -011 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22903 -01 -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 -30A Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 025518, 047437 & 047438 Milne Point / 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): 8626' 4458' 8626' 4458' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 13 -3/8" 120' 120' 4930 2670 Surface 6704' 5 -1/2" _ 6738' 4462' 7000 4990 Intermediate Production Liner 1618' 2 - 7/8" 6673' - 8291' 4422' - 4463' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section & Open Hole: 6679' - 8626' 4426' - 4458' 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 ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Name David Reem Title Engineering Team Leader Prepared By Name /Number: Signature 0-C ..... R ej z .i.. „ ..... . L.„ Phone 564 - 5743 Date 7/264b2.. Joe Lastufka, 564 -4091 Commission Use Only Con ns of approval: Notify Commission so that a representative may witness �` 2 n r� Sundry Number (- L Plug Integrity ❑ BOP Test Le Mechanical Integrity Test ❑ Locatio Other: l 7 Subsequent Form Required: / 6 --q o7 APPROVED BY � V7� Q 9(1x.e.4,04.......... �7 �_ '7 __ — App oved By: /„ / qm THE COMMISSION Date / • d 1 1 Submit In Duplicate -) S 012012 e 7 z 7iz • • 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 OP f� 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 • b6 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 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 loss 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 Toss 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(nflatable Cement Re ai er nd 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 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 WeII: MPE -30 Version: 1 4 Suspend Well Tree: 2 9/16" 5M N Ori = 57.0' ( N 27E) Wellhead: 7" 5M Varco ADRS -7 M P U E-30 I��ri GL Elev 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. 1 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 W e l l 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) 2 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 Cement Retainer set at 6500' Cement plug below the retainer TOL @ 6511' (4.5" od. scoop guide ) b ° 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' v.,. _ Window 6658' - 666 :' •»X Pre- Drilled 4 spf m.: ......., 2 -3/8 ", 4.43 ft/# L -80 stl & f143 RA @ 6666' ... iWI �NG pbtd @ 9290' TOL @ 6673' <( p51'� - 91 36.) Liner = 9170' 1 1 4.6" GS profile E -30a ( south lateral ) 5.5" Baker whipstock @ 6737' Window 6738' - 6744' Pre - Drilled 4 spf :::::......... RA @ 6746' " "t "t:'• :'t• _ 2-7/8 ", L -80 stl 6.16#, EZSV @ 6754' W/ Cement below St-0 dot pbtd @ 8,626' !! 0,04 i32- Liner = 8,291' OA / OB Sands - Limited entry frac w/ 119.6 M# ® �� of PrapLoked 16/30 Badger prop. behind pipe. AAAAAAAAAAAAAAAAAAAAAA 'OA' Sand Sgz'd ii : i.i :i ii. 3 3/8" 0.6 6758' - 6778' (4475' - 4484') ..... ,i'i: : :: � ae! e! eO• o • �... 1013' Sand 3 3/8" 2 6845' - 6865' (4523' - 4560') 5.5" float collar (PBTD) 7086' and 5.5 " float shoe 7169' ,,d DATE REV. BY COMMENTS MILNE POINT UNIT 08/05/98 JBF Drilled and Cased by Nabors 27E WELL E -30A/P -1 10/20/98 MDO Completion w/ heat trace 4 ES API NO: 50- 029 - 22903" 014ra 05/21/01 MDO Sidetrack 3 -S and completion 4 -ES Ore 0/k-I . 5a - ozq- 2.2103'(00"'du 11/19/05 MDO ESP RWO 4 -ES Change tree size 10/02/07 REH ESP RWO by 4ES BP EXPLORATION (AK) Page l of l • • 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 welibore. 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 • Orig• Elev. = 57.0' (N 27E) Wellhead: 7" 5M Varco ADRS -7 M P U 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. 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) )0' of cement above retainer Two 5.5" x 20' short jts. f/ 6320' to 6359' and ,e ;ement Retainer set at 6500' (t.16, s.� Cement plug below the retainer o TOL @ 6511' (4.5" od. scoop guide ) 4.5" GS profile E -30a L -1 ( north lateral ) 5.5" Baker whipstock top @ 6657' ;•r.,... Window 6658' - 666 •„I„ , Pre-Drilled L-80 4 spf k J: 0): *X..4:• 2 -3/8 ", 4.43 ft/# L -80 stl & fl43 RA @ 6666' . ...e.....:. 0.404 TOL @ 6673' L = 9290' Liner = 9170' I 11 4.6" GS profile E -30a ( south lateral ) 5.5" Baker whipstock @ 6737' Window 6738' - 6744' :V:.::,•e4. Pre - Drilled 4 spf RA @ 6746' ■"'!"""-"•"••"'•••••"• 2 -7/8 ", L -80 stl 6.16 #, EZSV @ 6754' W/ Cement below pbtd 8,626' ii ° n p Liner = 8,291' OA/ 08 Sands - Limited entry frac w/ 119.6 MS ii II of PropLoked 16/30 Badger prop. behind pipe. OA'Sand Sgz'd ii " " ":i•�'ii iiii.' ✓ii' 3 3/8" 0.6 6768' -6778' (4476' - 4484') •..tii...... • iN)WW.W•ii' 'oB' Sand 3 3/8" 2 6846' - 6866' (4623' - 45601 5.6" float collar (PBTD) 7086' and 5.6 "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 -ES 11/19/05 MDO ESP RWO 4 -ES Change tree size 10/02/07 REH ESP RWO by 4ES BP EXPLORATION (AK) io r • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Q Mr. Tom Maunder e , 30/1 Alaska Oil and Gas Conservation Commission IT 333 West 7 Avenue Anchorage, Alaska 99501 s'_ Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Maunder, ea au der, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir j. 2 �� BPXA, Well Integrity Coordinator « 5 1) FEB } • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE-05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE-08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 ------ . MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) ;� Sent: Thursday, December 29, 2011 1:34 PM 7J Zc (' • f1 To: 'McLaughlin, Sean M' MPF 'ACS h- 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 ) F a (: ale!, 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 • • Alf 0[F A ILA [I(KA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. t P.O. Box 196612 a(� 0[[ Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Pool, MPE -30A Sundry Number: 311 -384 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, Daniel T. eamount, Jr. Chair DATED this2 day of December, 2011. Encl. A r"tiitlie . ,.., _ STATE O F ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL , Oil & Gas s. Commission 20 AAC 25.280 1. Type of Request: Aitt.11CT O ❑ 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 -011 . 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22903 -01 -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: MPE40A Spacing Exception Required? ❑ Yes ® No 9. Property Designation: . 10. Field / Pool(s): ADL 025518, 047437 & 047438 Milne Point / 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): 8626' ' 4458' • 8626' 4458' None None Casino Length Size MD TVD Burst Collapse Structural Conductor 84' 13 -3/8" 120' 120' 4930 2670 Surface 6704' 5 -1/2" 6738' 4462' 7000 4990 Intermediate Production Liner 1618' 2 - 7/8" 6673' - 8291' 4422' - 4463' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section & Open Hole: 6679' - 8626' 4426' - 4458' 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 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 15, 2012 ® 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 Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature &g-12-1... Phone 564 - 5743 Date /2- /3 -2c// Terrie Hubble, 564 -4628 Commission Use Only Conditions of approval: N ' Commission so that a representative may witness Sundry Number 3 \' " n Q y ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: $ 3 S 0 6 ®S t. & v p �,p1_ 1) G 0C'''' & . og rid( /ego r id. s- i oft , Subsequent Form Required: /a— y eyf O / APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date /2.1Z7 I t 1 Form 10-403 Revised 01 /HB f MS DEC 2 8 201M49 R 1 G 1 / z- /(®.4' Submit In Duplicate ,y9 �' 1 AL , �L /��4/ '7;�s . • • • BP xploration Alaska Inc. by MPE -30A 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 —10 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'. cs 4 2oo0 w S 4. Run test packer to 6500'. Test Casing to 1.2X the SICP. -- 5. Set storm packer —60'. Test storm packer to 1000 psi.' 2:14/43 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. t Tree: 2 9/16" - 5M • Orig. DF A I. = 57.0' (N 27E) . Wellhead: 7" 5M Varco ADRS -7 M P U 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 0 N : 7 26 ppf L - Btrc. 0 , 'm 7 "x 5.5" X -Over 117' and i 13 3/8" 72 ppf, L -80 115' 0 ' � 1 Camco 2 3/8" x 1" KOP @ 500' 0 ` - sidepocket KBMG GLM 126' angle = 69 to 73 deg. 0 Max. hole an 9 9 from 3950' to 5850' Hole angle thru' perfs = 73 deg. / / O 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" II sidepocket KBMG GLM 6,280' 6 OK ; 2 -3/8" HES XN- Nipple 6,356' (1.875" polish bore, 1.791" No-go ) ' Centrilift Upper tandem 6,399' PMSXD 1:6 35 P 10; `. PMSXD 1:6 192 P 10 Centrilift Lower Tandem 0- FPMSSD 1:4 27 G 12 j i Gas Separator: 6,433' FRSTX FER NH6 AR 0111111. Centrilift Tandem seal Section FSB3DBUTFERSB /SBPFSA 1 6,438' NM FSB3DBH6FERSSCVHLSB /SB Two 5.5" x 20' short jts. f/ 6320' to 6359' and " Mt - Centrilift Motor: 1 6,450' Ma FMHG 132hp./2220 volt/39 amp ME 1111 Centrilift DH Sensor XTO 6,473' Centralizer 6,475' TOL @ 6511' (4.5" od. scoop guide ) 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' 1.. •;:: :: :• TOL @ 6673 pbtd @ 9290' Liner = 9170' 1 1 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 - III pbtd @ 8,626' Liner = 8,291' OA 1 OB Sands -Limited entry frac w/ 119.6 MO i i Ili of PropLoked 15/30 Badger prop. behind pipe. Boa' send Sgz'd 1 3/8" 0.6 6758' - 6778' (4475' - 4484') !'.' ` ^ "• "" `" " ICIELSand 3 318" 2 6845' - 6865' (4523' - 4550') 5.6" float collar (PBTO) 7086' and 5.5" float shoe 7169' Ind 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 Chg. tree size 10/02/07 REH ESP RWO by 4ES BP EXPLORATION (AK) , Page 1 of 1 • 1 Schwartz, Guy L (DOA) From: Bjork, David [David.Bjork @bp.com] Sent: Monday, December 19, 2011 9:23 AM To: Daniel, Ryan Cc: Schwartz, Guy L (DOA); Reem, David Subject: FW: MPE -30A and MPE -30AL1 (PTD 201 -01 and 201 -017) Ryan, Can you address the question regarding the casing pressure test. thanks, Dave From: Schwartz, Guy (DOA) mailto: u .schwartz @alaska. ov Y L ( )[ 9 Y 9 l Sent: Friday, December 16, 2011 9:45 AM To: Bjork, David Subject: FW: MPE -30A and MPE -30AL1 (PTD 201 -011 and 201 -017) Guess you are looking at this in Sean's absence. Can you help out? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday, December 16, 2011 9:43 AM To: 'McLaughlin, Sean M' Subject: MPE -30A and MPE -30AL1 (PTD 201 -011 and 201 -017) Sean, I was reviewing the Sundry application for the ESP workover and wellhead changeout. I had a question regarding pressure testing the casing to 1.2 X SICP in step 4. What value are you going to use? Normally casing should be tested to' /2 the BOP equipment rating (2500 psi) which is pretty standard. This is a monobore so there is increased risk if the casing is not competent in this completion. I am also asking for photo documentation of the wellhead install ( sliplock) for our own records. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 12/20/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~E~~~~~r MARI~2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q .~~ ter ~ C i0(1S. COI~ft11SSrvr Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ItChorage Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-ente Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 201-0110 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-22903-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Numb r: ~ ADLO-047438 MPE-30A 10. Field/Pool(s): MILNE POINT FIELD SCHRADER BLFF OIL POOL 11. Present Well Condition Summary: Total Depth measured 8626 feet Plugs (measured) None feet true vertical ~ 4458.48 feet Junk (measured) None feet Effective Depth measured 8626 feet Packer (measured) true vertical 4458 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 84 13-3/8" 72# L-80 36 - 120 36 - 120 4930 2670 Surface 6704 5-1 /2" 15.5# J-55 34 - 6738 34 - 4462 7000 4990 Intermediate Production Liner 1618 2-7/8" 6.16# L-80 6673 - 8291 4422 - 4463 10570 11160 Liner Perforation depth: Measured depth: SL 6673 - 8626 True Vertical depth: 4422.38 - 4458.48 = - - - Tubing: (size, grade, measured and true vertical depth) 2-3/8" 4.7# L-80 SURFACE - 6469 SURFACE - 4298 Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 165 36 26 180 Subsequent to operation: 173 37 24 184 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 6. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 3/18/2010 inn ~v-~rv'* n~gcu ~iwv~ • ~VV.-.S ~I7/, ii ~ ~lo~~. ~ ~' ......., .,. .../~ 1 ~ ca ~y • MPE-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/5/2010jT/I/O=0/0 Assist CTU Pump 110 bbls 140*F diesel down coil to clean out iTbg to the ESP. Pump 29 bbls amb diesel, 10 bbls Diesel/Xylen down coil ;and flush coil w/ 30 bbls diesel. FWHP=O/0 Coil has control of well @LRS departure. 3/5/2010 CTU #9 w/1.50" OD CT. Job scope -MIRU, Acidize ESP. «< Interact publishing »> MIRU. RIH w/1.70" od JSN assy. Could not get any deeper than 2,333' due to thick crude in well. POOH jetting tubing w/ambient WO LRS. RU LRS and pump hot diesel down to tag at 6387' ctmd. Pumped Geovis pill, more hot diesel & diesel xylene. SLB tractor broke down at 2.7 bbls of diesel xylene out the nozzle. Cannot repair tractor, called LRS to complete job. RU LRS @ 21:00 hrs. Squeezed 7 .3 bbls Diesel Xylene through pump. Continued on WSR 03/06/2010 3/5/2010 Assist CTU with Acid job. Pumped 6.4 bbls of methanol down coil. ***Job continued on 3-6-10 WSR*** 3/6/2010:' *"*Job continued from 3-5-10 WSR*** Assist CTU with Acid job. Pumped down coil; 8 bbls 60/40, 12 bbls acid, 3 i bbls 60/40, 27 bbls diesel, 3 bbls 60/40. _. _W_ _ ~ . ~. _ ~ ____ 3/6/2010 CTU #9 w/1.50" OD CT. Job scope -Acidize ESP. «< Interact publishing ; »> Continued from WSR 03/05/2010. Squeeze Diesel Xylene treatment through ESP @ .2 bpm @ 3000 psi.. Squeeze 10 bbls 12 % DAD acid_ ~throuah ESP. Finial ini rate .8 bpm 846 psi. Started pump in forward and 'reverse w/8 bbls acid injected past ESP. POOH running ESP. Park at surface and allow well to clean up to OT tank. Ph at 6 and well is flowing to the facility, flush lubricator & RDMO ****Job Complete"*"* FLUIDS PUMPED BBLS 80 60/40 METH 381 DIESEL 10 GEOVISC 20 XYLENE/DIESEL MIXTURE 23 12A% HCL 3 ACID TITRATION= 12.4 IRON=<50PPM 514 Total Tree: 2 9/16" - 5M ~ Wellhead: 7" 5M Varco ADRS-7 Weld on style Tba. 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' pen`s = 73 deg. 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' and 5.5" Baker whipstock top @ 6657' Window 6658' - 666 RA @ 6666' 5.5" Baker whipstock @ 6737' Window 6738' - 6744' RA @ 6746' EZSV @ 6754' W/ Cement below OA / OB Sands • Limited entry fret wl 719.6 M# of PropLoked 16/30 Badger prop. behind pipe. 'oA c_An.f Bgz'd 3 3/9" 0.6 6758' - 6778' (4475' -4484') .AR' Sand 3 3/9" 2 6845' • 6865' (4523' - 4560') 5.5" float collar (PBTD) 7086' and 5.5 "floe! shoe 7169' and DATE REV. BY COMMENTS 08/05/98 JBF Drilled and Cased by Nabors 27E 10/20/98 MDO Completion w/ heat trace 4 ES 05/21/01 MDO Sidetrack 3-S and completion 4-ES 11/19/05 MDO ESP RWO 4-ES Chg. tree size 10/02/07 REH ESP RWO by 4ES 5.5" Port CollarCementer 1336' and Centrilift heat trace @ 3240' Camco 2 3/8" x 1" sidepocket KBMG GLM 6,280' 2-3/8" HES XN-Nipple 6 356' (1.875" polish bore, 1.791" No-go ) Centrilift Upper tandem 6'399 PMSXD 1:6 35 P 10; PMSXD 1:6 192 P 10 Centrilift Lower Tandem FPMSSD 1:4 27 G 12 433' 6 Gas Separator: , FRSTX FER NH6 AR Centrilift Tandem seal Section FS63DBUTFERS6/SBPFSA 6,438' FS63DBH6FERSSCVHLS6/SB Centrilift Motor: 6 450' FMHG 132hp./2220 volt/39 amp Centrilift DH Sensor XTO 6'473 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 TOL @ 6673' 4.5" GS profile pbtd @ 9290' Liner = 9170' E-30a (south lateral ) Pre-Drilled. 4 spf 2-7/8", L-80 stl 6.16#, pbtd @ 8,626' I Liner = 8,291' MILNE POINT UNIT WELL E-30A API NO: 50-029-22903 BP EXPLORATION (AK) M P U E ~~ O/k1 Orig. GL EI~ = 23.2' (N 27E) DF to 7" csg. hng. = 33.6' (N 27E) 7" 26 ppf L-80 Btrc. 7"x 5.5" X-Over 117' and Camco 2 3/8" x 1" sidepocket KBMG GLM 126' STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS /~r3' 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Q ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ ~ Exploratory 201-0110 3. Address: P.O. Box 196612 Stratigraphic Service a. 6. API Number: Anchorage, AK 99519-6612 50-029-22903-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 57.05 KB ~ MPE-30A 8. Property Designation: 10. Field/Pool(s): ADLO-047438 MILNE POINT Field/ SCHRADER BLFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 8626 - feet Plugs (measured) None true vertical 4458.48 - feet Junk (measured) None Effective Depth measured 8626 feet true vertical 4458 - feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 84' 13-3/8" 72# L-80 36' - 120' 36' - 120' 4930 2670 SURFACE 6704' 5-1/2" 15.5# J-55 34' - 6738' 34' - 4462' 7000 4990 LINER 1618' 2-7/8" 6.16# L-80 66 7 - 8291' 4422' - 4 63' 10570 11160 3 ' 4 ~ ~} ~ t , ~~ Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-3/8" 4.7# L-80 SURFACE - 6469' 0 0 - Packers and SSSV (type and measured depth) NONE 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): .t ((11 MM Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 873 103 0 217 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ''~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' - Gas WAG !`~', GINJ ~'~' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble S~ ~`~~` O~~- " 1 1 Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 11/5/2008 Form 10-404 Rev' ed 04/2006 ,; ~-»~ Submit Original Only <<~~~ M PE-30A 201-011 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas De th Base Tvd Depth Top Tvd De th Base MPE-30A 5/21/01 SL 6,673. 8,626. 4,422.38 4,458.48 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • MPE-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY ~ 10/29/2008,T/1=70/150 (Assist CTU) Heated 90 bbls Diesel to 110"F and pump down CT while taking returns up tubing. FWHP=10/100 CTU still on well upon !departure. 10/29/2008CTU #9 (1.5" OD CT), FCO/Tubing Wash. <InterACT not publishing> Road :unit from shop to MPU. Pump 1.0" ball to drift coil. Perform weekly BOP test. RIH with 1.50" JSN. Ran into thick crude at 4600' ctmd. Worked down to 4850' ctmd. Could not work pipe deeper. Call for hot oil pumpers and load of diesel. :Begin pumping preheated diesel. Wash from 2150' to 6396' camd 100' diesel. Circulate bottoms up. Dry tag at same depth of 6396' ctmd (to of um :Mobilize equipment for acid ~o . '`'`* Job continued on WSR 10/30/2008 *'`* 10/30/2008CTU #9 w/1.50" CT. Acidize ESP. **" Continued from WSR 10/29/2008 *** <InterACT not publishing > Pump 5 bbls of 80:20 diesel/xylene and 10 bbls of :90:10 12% DAD acid per program. Squeeze 1.5 bbls of 80:20 diesel/xylene :through pump_at 3000 psi: Due to freezeing considerations of CT, circulate acid to ESP by taking returns holding 2000 psi WHP. Once acid reached the top of :the pump, a major change in pressure falloff was noted. Stage/soak and ;squeeze acid through pump, then over displace to perfs. Start sequence ESP as per program. ESP had normal start up. Flow well to tank to clean up. When pH reached 7, turnover well to plant. RDMO CTU. Final T/I = 200/275 ', *** Job complete *** FLUIDS PUMPED BBLS 64 60/40 METH 15 12% 90:10 DAD ACID 6 80/20 DIESEUXYLENE WITH 5% U067 & 0.2% F103 50 FRESH WATER WITH 2OPPB SODA ASH 135 TOTAL ~ic~~V ~. ' STATE OF ALASKA ~`'?+~~ ALA OIL AND GAS CONSERVATION COMI~IOt~ 0 2Q08 REPORT OF SUNDRY WELL RiA~E~~&IS. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate nC orage Other ~ ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory ~~~. 201-0110 3. Address: P.O. Box 196612 StratlgraphlC SerViCe ~~' 6. API Number: Anchorage, AK 99519-6612 50-029-22903-01-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 57.05 KB ~ MPE-30A- 8. Property Designation: 10. Field/Pool(s): ADLO-047438 - MILNE POINT Field/ SCHRADER BLUFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 8626 ~ feet Plugs (measured) None true vertical 4458 ~ feet Junk (measured) None Effective Depth measured 8626 feet true vertical 4458 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 84' 13-3/8" 72# L-80 36' - 120' 36' - 120' 4930 2670 SURFACE 6704' 5-1/2" 15.5# J-55 34' - 6738' 34' - 4462' 7000 4990 LINER 1618' 2-7/8" 6.4# L-80 6673' - 8291' 4422' - 4463' 10570 11 f 60 ~~~~ JUN ~ ~ 200$ Perforation depth: Measured depth: SLOTTED LINER 6679' - 8256' True Vertical depth: SLOTTED LINER 4426' - 4463' Tubing: (size, grade, and measured depth) 2-3/8" 4.7# L-80 - 6469' r: ,__. _ _ __ .__ Packers and SSSV (type and measured depth) NONE 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure; 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 87 22 30 0 165 Subsequent to operation: SHUT IN 0 0 0 0 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ ,, WINJ u' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number o~ N/,A~ .O. Exempt: /-/ Contact GARY PREBLE Printed Name GARY PREBL Title DATA ENGINEER 'z^~~3~ Signature p Phone 564-4944 Date 5/29/2008 Form 10-404 Revised 04/2004 ' k ~ ~~~, ,JEj~! ~ ~ d~d~ Submit Original Only • MPE30A • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIV(TYDATE I SUMMARY 5/23/2008 ( Acid Treatment) T/I/0= 325/340/120 Pump 10 bbls dead crude down TBG followed by 10 bbls Acid then 55 bbls dead crude for Acid Treatment. FWHP= 350/360/120 !: FLUIDS PUMPED BBLS 10 DEAD CRUDE 10 ACID 55 DEAD CRUDE 75 Total Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well F-48 G-19A NGI-13 MPE-30A F-11 B W-12A 11-27 02-22A 01-16 01-14 L5-05 D-21 14-15 D-18A 14-05A 1-23/0-15 S-03 1-09A1L-21 P2-19A OWDW-NW K-01 11-32 3-25B/L-27 Job# 11846815 11890315 11890313 11855817 11649954 11418301 11637127 11216214 11630486 11801086 11767129 11626119 11221550 11695074 11813055 11846802 11223120 11849930 11649963 11211370 11695073 11630498 11630490 ~~~ED OCT 3120D7 Lo!! Description USIT 1'1 1- ()7 ./'> USIT 1'1'1 - to:'" USIT 1 YI.f'_ t -=t",... -OCt I US IT ~O I - 0 It MCNL ;} cf-1 - 1 c £.1. I è").::I -r-5 MCNL JC\-7r -1"¡Jg ... 15::~Lf RST j~ {" - IY1f ~ I ..ç-:,\--:}(., MCNL ::IN' - h ~D¡ ~ I."''''' .r - + RST I....~"ir - DCYx 1", "=\f\ j...,;? RST¡ /l ~ - (')'+ -:¡ .. I ~-5 +'-t MCNL ¡"Í( '"::} _(')("q *. ~~ 0 RST I ~ ;::) - I"'~.::J ... ,,,,,,"'- . i RST 11r I - 6~LI ~ 155""'k:1 RST 0/')/- lh"? ¢- I ~ "'"\ ?S' RST /D¡~ -(10 I .. l~-g «> RST d"'.(\. lOt'-1 '-¡::!-5r ¢ 1-::"'5155 RST li¡rl - ¡l\,' 'CttfÇ~~L( RST I 0, ~ - ('~,9q 'it- I ~s- --:+ '5" MCNL ~')()~_ ()Id ~ 15"5?d RST l J-r¡\ ._" -V/~ ;1 t5:':;-=f1 RST 1~3- ,;:JI ....'00t1J RST D¡Lj- I~ I #" /5:"Ç"("C RST .::k~~ - 1'\:;) I .., ~<:7 - ~ - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Date 10/12107 09/30/07 09/30/07 10/01/07 03/22/07 09110/06 06/05/07 10102/06 06/28/07 07/07/07 06/17/07 09/12/07 03/07106 08/28/07 06/11107 08111107 06/13/06 08/04107 04122/07 02/28/06 08127/07 09/03/07 07/26/07 NO. 4459 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milno Pt.,lisburnE BL Color 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 :~.::~ AK '''''It Received by: C1 ,,¡ . 10/23/07 . . STATE OF ALASKA A • OIL AND GAS CONSERVATI NCO ~~~ O ~SION ~#~ ~ REPORT OF SUNDRY WELL OPERATIONS ~~`~~~!~~~~~~~~~~ ~~ fi, f~~ 1. Operations Performed: e 4 ^ 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 201-011 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22903-01-00 7. KB Elevation (ft): 57.05' - 9. Well Name and Number: MPE-30A 8. Property Designation: 10. Field 1 Pool(s): ADL 047438 ' Milne Point Unit !Schrader Bluff ` 11. Present well condition summary Total depth: measured 8626 ~ feet true vertical 4458 'feet Plugs (measured) None Effective depth: measured 8626 feet Junk (measured) None true vertical 4458 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 13-3l8" 120' 120' 4930 2670 Surface 6704' 5-1/2" 6738' 4462' --•-• 7000 4990 Intermediate Production Liner 1618' 2-7l8" 6673' - 8291' 4422' - 4463' 10570 11160 vt.:+~-Si'~9 ~~~ ~ ~ ~'~~~ Perforation Depth MD (ft): Slotted Liner 6679' - 8256' Perforation Depth TVD (ft): Slotted Liner 4426' - 4463' Tubing Size (size, grade, and measured depth): 2-3/8", 4.7# L-80 6477' 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 We11 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 if C.O. Exempt: Contact Frank Roach, 564-4373 N/A Printed Name Sondra Stewman Title Drilling Technologist Si ature ,.. Prepared By Name/Number Phone 564-4750 Date (®._'~.'~~ Sondra Stewman, 564-4750 Form 10-404 Revised 04/20 ~ Submi n 'nal Only Tree: 2 9/16" - 5M Wellhead: 7" 5M Varco ADRS-7 Weld on style Tbg. 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 1D =1.995 ", cap. = 0.00387 bpf ) Two 5.5" x 20' short jts. f1 6320' to 6359' 5.5" Baker whipstock top @ 6657' Window 6658' - 666 RA @ 6666' 5.5" Baker whipstock @ 6737' Window 6738' - 6744' RA @ 6746' EZSV @6754' W/ Cement below OA / OB SarMS - Llrhited entry frac w/ 119.6 Mp of PropLOked 16/30 Badger prop. behirW pipe. ron' sand Sgz'd 3 3/8" 0 .6 6758' - 6778' (4475' -4484') 'OR' S d an 3 3I8" 2 6845' -6865' (4523' -4560') 5.5" float collar (PB7D) 7086' and 5.5 ^ float shoe 7169' and DATE REV. BY COMMENTS 08!05/98 JBF Drilled and Cased by Nabors 27E 10/20/98 MDO Completion wJ heat trace 4 ES 05/21/01 MDO Sidetrack 3-S and completion 4-ES 11/19/05 MDO ESP RWO 4-ES Chq. tree size Orig~DF Elev. = 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' Centrilift 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' Centrilift Upper tandem 399' 6 PMSXD 1:6 35 P 10; , PMSXD 1:6 192 P 10 Centrilift Lower Tandem FPMSSD 1:4 27 G 12 433' 6 Gas Separator: , FRSTX FER NH6 AR Centrilift Tandem seal Section ' FSB3OBUTFERS6lSBPFSA 6,438 FS63DBH6FERSSCVHLS6/SB Centrilift Motor: 6,450' FMHG 132hp./2220 volU39 amp 473' 6 Centrilift DH Sensor XTO , 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 fU# L-80 stl & fl43 vw c~ uu ~~ •~. 141 f --'1+7.r~b1d @ 9290' TOL @ 6673' Liner = 9170' 4.5" GS prorle E-30a (south lateral ) Pre-Drilled 4 spf 2-7/8", L-80 stl 6.16#, t_~ec~ {,~,~Fr" pbtd @ 8,626' n~~' - ~ Liner = 8,291' ~~~ MILNE POINT UNIT WELL E-30A~~ API NO: 50-029-22903--x( 1REH ESP RWO by 4ES BP EXPLORATION (AK) • PRE PRE 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 f Rig Release: 10/2/2007 Rig Name: NABORS 4ES Rig Number: Date. ~ From -'To ~ Hours ~ Task ~ Code f NPT ~ .Phase 7/3/2007 100:00 - 03:00 I 3.00 I RIGD 1 P 03:00 - 04:30 1.50 ~ MOB I P 04:30 - 11:00 6.50 RIGU P 11:00 - 00:00 I 13.001 RIGD I C 9/28/2007 03:00 - 11:QO 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 I 1.001 KILL I P PRE PRE POST • Description of Operations Rig down off of well slot MPJ-24. Lower and scope Derrick. Continue RD of Modules off of well slot MPJ-24. Back Carrier off of well with Pad Operator, WSL and Tourpusher present. Move the Rig and Modules from MPJ-24 to MPE-30. 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. Service & repair rig. Received orders from Anchorage to move to MPL-O6. 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 PR same to 500-psi. No leaks. Pull BPV. 17:30 - 18:30 1.00 KILL P DECOMP Take on 130 degree seawater. 18:30 - 19:00 0.50 KILL P DECOMP Hold PJSM & Pre-spud meeting w/ all hands. Pressure test lines to 3600 psi. 19:00 - 20:30 1.50 KILL P 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. SID TP & AP dropped to 0 psi. Open well, tubing & annulus on vacuum. 20:30 - 21:30 1.00 KILL P DECOMP Monitor well. R/D lines. 21:30 - 22:00 0.50 WHSUR P DECOMP Set TWC per Cameron Rep. 22:00 - 23:00 1.00 WHSUR P 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. 23:00 - 00:00 1.00 WHSUR P DECOMP R/D test equip. Blow down lines. Drain tree. 9/29/2007 00:00 - 00:30 0.50 WHSUR P DECOMP Bleed hanger void. N/D tree. 00:30 - 01:00 0.50 BOPSU P DECOMP Install DSA & test spool. 01:00 - 03:30 2.50 BOPSU P DECOMP N/U BOPE, Choke & kill lines. 03:30 - 07:00 3.50 BOPSU P DECOMP Pressure test BOPE as e . BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Annular 250/3500 psi. BOP test witnessing waived by Chuck Sheve w/ AOGCC. 07:00 - 08:30 1.50 BOPSU P DECOMP Rig down and stow BOPE test equipment. Prepare to upland tubing hanger 08:30 - 09:30 1.00 PULL P DECOMP BOLDS. PUMU landing jt. with TIW valve. Screw into tubing Printed: 10/25/2007 1:23:01 PM • • BP EXPLORATfON Page 2 of 3 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 Date ,From - To ~ Nours ~ Task I Code I NPT 9/29/2007 109:30 -108:00 I 8.501 PULL I P 18:00 - 18:30 f 0.501 PULL I P 18:30 - 21:30 I 3.00 PULL l P 21:30 - 23:30 I 2.001 PULL I P 23:30 - 00:00 0.50 PULL P .9/30/2007 00:00 - 00:30 0.50 PULL P 00:30 - 01:00 0.50 CLEAN P i i 01:00 - 05:00 4.00 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 06:30 0.50 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 00:00 - 06:30 6.50 EVAL P 06:30 - 08:30 2.00 EVAL P 08:30 - 09:30 I 1.00 I EVAL ! P 09:30 - 12:30 3.00 EVAL P 12:30 - 13:00 0.50 EVAL P 13:00 - 16:00 3.00 EVAL 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 Spud Date: 7/25/1989 Start: 7!212007 End: 10/2/2007 Rig Release: 10/2/2007 Rig Number: Phase I 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 2 318" 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 1 112' 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. L/D elephant trunk. DECOMP MIU 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 2 318" tubing, PtU 10 singles & tagged 4-112" 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" scraper/muleshoe BHA. BO/LD same. DECOMP PJSM. PUMU Halco 5-1 J2" RBP. DECOMP RIH wi5-112" RBP and set @ 6,448'. DECOMP P/T RBP and casing to 1500-psi for 30-charted inutes to veri R P is competent mechanical barrier and: verify casing 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 log USIT. Logged from 3985' to surf. Repeat thru areas of corrosion. DECOMP RDMO SWS a-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. DECOMP RIH wi5-1/2" RBP retrieving tool on tubing from derrick. DECOMP PUMU single jt, w/TIW valve. Tag top of RBP @6444' wlretrieving tool. Release RBP. Hole on vacuum. DECOMP POH L/D 9jts. tubing 1x1 through pipe shed. POH standing 68 stds. tubing in derrick. LD RBP and retrieving tool. DECOMP Break out & L!D RBP & setting tool. Clear & clean rig floor. RUNCMP PUMU Centrilift ESP assembly per running order. RUNCMP Crew Change. Inspect derrick. Check PVT alarms. RUNCMP PlU, 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 3!8" 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 • • $P EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPE-30 Common Well Name: MPE-30 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING '~ Rig Name: NABOBS 4ES .Date .From - To Hours l 'Task L Code I NPT 10/2/2007 00:00 - 06:00 6.00 `` BUNCO `` 06:00 - 06:30 I 0.501 RU 06:30 - 12:30 I 6.00 12:30 - 13:30 I 1.00 13:30 - 18:30 I 5.00 18:30 - 19:00 I 0.50 19:00 - 20:00 I 1.001 WHSUR l P 20:00 - 21:00 I 1.001 BOPSUf~P 22:00 - 23:00 I 1.001 WHSUR P 23:00 - 00:00 I 1.001 WHSUR I P Spud Date: 7/25/1989 Start: 7/212007 End: 10/2/2007 Rig Release: 101212007 Rig Number: Phase) Description of Operations RUNCMP Check conductivity every 2000'. Pump thru pump every 2000', 1 BPM @ 1800 psi. RUNCMP Crew change out, rig maintenance, derrick inspection and checl PVT alarms. RUNCMP RIH w/ 2 3/8" ESP completion. M/U torque = 1290 ft-Ibs. Check conductivity every 2000'. Pump thru pump every 2000', 1 BPM @ 1800 psi. RUNCMP PUMU tubing hanger w/landing joint and TIW valve. Install penetrators in hanger. RUNCMP Make final field splices in ESP power cable & heat trace cable. Ttest & meg splices. Install final Cannon clamp. RUNCMP Land 2 3/$" 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 Clamp & 5 - 314" SS bands. RUNCMP Install TWC. Test from top wl 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 7/8" 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 PJU lubricator & test to 500 psi, pull TWC. Install BPV. UD lubricator. Secure tree. & clean cellar. RELEASE RIG @ 24:00 hrs, 10-2-2007. Printed: 10/25/2007 1:23:01 PM . _,1; 1 RECEI\/E~ STATE OF ALASKA rÞ7Î'0 j ~ N 1.-0 "~9"OIL AND GAS CONSERVATION COMM.N I' ,¡., REPORT OF SUNDRY WELL OPERATIONS 1. Operations -, LJ l.Ons. BOJImIMlID'D Plug Perforations D Stimulate D Other 0 ACID TREATMENT/ Performed: Alter Casin!\@1orage Pull Tubing D Perforate New Pool D WaiverD Time Ext~nsion D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P / Exploratory 201-0110 ,/ 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22903-01-00 ./ 7. KB Elevation (It): 9. Well Name and Number: 57.05 KB J MPE-30A / 8. Property Designation: 10. Field/Pool(s): ADLO-047438 J MILNE POINT Field/ SCHRADER BLUFF OIL Pool ./ 11. Present Well Condition Summary: Total Depth measured 8626 feet Plugs (measured) None true vertical 4458 feet Junk (measured) None Effective Depth measured 8626 feet true vertical 4458 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 84' 13-3/8" 72# L-80 36' - 120' 36' - 120' 4930 2670 SURFACE 6704' 5-1/2" 15.5# J-55 34' - 6738' 34' - 4462' 7000 4990 LINER 1618' 2-7/8" 6.4# L-80 6673' - 8291' 4422' - 4463' 1 057j 11160 SCANNED JAN 1 1 200 Perforation depth: Measured depth: 6679' - 8526' - - - - True Vertical depth: 4426' - 4463' - - - - , Tubing: (size, grade, and measured depth) 2-3/8" 4.7# L-80 - 6469' Packers and SSSV (type and measured depth) NONE 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~BDMS 8F' ,) ~.'"r" ~ c. '<./ "',, ~" 1 1 20D7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 87 22 30 0 165 Subsequent to operation: SHUT IN 0 0 0 0 14. Attachments: 15. Well Class alter croposed work: Copies of Logs and Surveys Run Exploratory Development P Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil P Gas r WAG r GINJ r WINJ r W DS P L r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. - _ISUndry Number or N/A if C.O. Exempt: Contact GARY PREBLE Printed Name GARY PREBLE /") Title DATA ENGINEER Signature c4 -'~ Phone 564-4944 Date 1/9/2007 Form 1 0-404 ~ised 04/2004 " , . Submit Ori inal Onl o R t G \ I~ p\ ßBDMS 8Fl J 1 *~ho g y ~. . . MPE-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 00. (Acid treatment). Pump 10 bblscrude down tbg for injectivity test. Pump 10 bbls 12% DAD acid. Displace acid w/11 bbls crude. Let soak for 10 minutes. Pump 5 bbls crude @ .5 bpm while rinning ESP in forward. Pump 30 crude & 10 bbls 60/40 meth for overflush. Turn well over to DSO. FWHP=0/100. FLUIDS PUMPED BBLS 10 12% DAD ACID 13 60/40 METH 56 CRUDE 79 TOTAL e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs_ Inscrts\Microfilm _Marlœr.doc STATE OF ALASKA ALASKA. AND GAS CONSERVATION CcA1ISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONSAN 03 Z006 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 047438 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend !HI Repair Well !HI Pull Tubing chan~~tMl3W8 o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver !HI Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: !HI Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To rill Number: 201-011 6. API Number: 50-029-22903-01-00 99519-6612 57.05' 9. Well Name and Number: MPE-30A 10. Field / Pool(s): Milne Point Unit / Schrader Bluff 84' 6704' 8626 feet 4458 feet Plugs (measured) None 8626 feet Junk (measured) None 4458 feet Size MD TVD 13-3/8" 120' 120' 5-1/2" 6738' 4462' 2670 4990 Burst Collapse 4930 7000 1618' 2-7/8" 6673' - 8291' 4422' - 4463' 10570 11160 ,~(('Æ\\~~\Ì1¡i;,,;;\) I ,~vlt~t\ ~(l \'~'. "d' 6679' - 8256' 4426' - 4463' 2-3/8",4.7# L-80 6469' 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 pressure: RBDMS 8Ft .IAN 0 4 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Re resentative Dail Avera e Production or hection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure o Copies of Logs and Surveys run !HI Daily Report of Well Operations !HI Well Schematic Diagram 15. Well Class after proposed work: o Exploratory !HI Development 0 Service 16. Well Status after proposed work: !HI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: 17. Printed Name Sondra Stewman Title Technical Assistant _ Prepared By NameINumber: )-{)S Sondra Stewman, 564-4750 Submit Original Only Phone 564-4750 Date Tree: 29/16" - 5M . Wellhead: 7" 5M Varco S-7 Weld on style Tba. Hna: NSCT T&B 2" CIW H BPV profile Or~g_ Elev.: 57.~' (N 27E) ongW Elev. - 23.2 OF to 7" csg. hng. = 33.6' (N 27E) 7" 26 ppf L-80 Btrc. 7"x 5.5" X-Over 1117' md I MPU E-30A DATE REV. BY COMMENTS 08/05/98 JBF Orilled and Cased by Nabors 27E 10/20/98 MOO Completion wI heat trace 4 ES OS/21/01 MOO Sidetrack 3-S and completion 4-ES - ir ~ "~ 133/8" 72 ppf, L-80 115' KOP @ 500' Max. hole angle = 69 to 73 deg. from 3950' to 5850' Hole angle thru' perfs = 73 deg. 5.5" 15.5 ppf, J-55, Btrc, prod. casing ( drift 10 = 4.950", cap. = 0.0238 bpf) 23/8" 4.70" ppf, J-55, 8 rd EUE tbg ( drift 10 =1.995 ", cap. = 0.00387 bpf ) Two 5.5" x 20' short jts. fl 6320' to 6359' md 5.5" Baker whipstock top @ 6657' Window 6658' - 66E RA @ 6666' 5.5" Baker whipstock @ 6737' Window 6738' - 6744' RA @ 6746' EZSV @ 6754' WI Cement below OA I OB Sands 6 Limited entry frac w/119.6 M# of PropLoked 16/30 Badger prop. behind pipe. ~d Sqz'd 3 3/8" 0.6 6758' - 6778' (4475' - 4484') .:ca:.sacd 3 3/8" 2 6845' - 6865' (4523'·4560') \ 5.5" float collar (PBTD) 7086' md 5.5 It float shoe 7169' md Cameo 23/8" x 1" sidepocket KBMM GLM 130' 5.5" Port Collar Cementer 1336' md Centrilift heat trace @ 3240' Cameo 2 3/8" xi" side pocket KBMM GLM 6,284' I 2-3/8" HES XN-Nipple ( 1.875" id ) I 6,361' I Centrilift Upper tandem 124 stage FC925 FPMTAR 1:1 Centrilift lower tandem 6,412' 21 stage FCNPSH FPMTAR 1:1 Centrilift 400 series Tandem gas 6,433' section FRSTXAR Centrilift 400 series Tandem seal I 6,437' section FST3DBHlPFS AF/HSN Cl5 Centrilift FMH 77 hp motor, 2130 v. / 24 amps. 6,449' 6,463' 6,469' PumpMate Centralizer TOl @ 6511' ( 4.5" od. scoop guide) 4.5" GS profile E-30a L-1 ( north lateral) pbtd @ 9290' Liner = 9170' ( south lateral) pbtd @ 8,626' Li ner = 8,291' MILNE POINT UNIT WELL E-30A API NO: 50-029-22903 t BP EXPLORATION Operations Summary Report Legal Well Name: MPE-30 Common Well Name: MPE-30 Event Name: WORKOVER Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 4ES Rig Number: Date I From - To : Hours Task Code I NPT i Phase i .J_...._.__.___.._.... - ------------ 11/13/2005 12:00 - 14:00 2.00 RIGD P 14:00 - 15:00 1.00 RIGD P 15:00 - 20:00 5.00 MOB P 20:00 - 00:00 4.00 RIGU P 11/14/2005 00:00 - 01 :30 1.50 RIGU P 01 :30 - 03:00 1.50 RIGU P 03:00 - 04:00 1.00 RIGU P 04:00 - 07:30 3.50 KILL P 07:30 - 08:00 0.50 KILL P 08:00 - 10:30 2.50 KILL P Page 1 of 3 11 /8/2005 11/18/2005 Spud Date: 7/25/1989 End: Description of Operations .--.-.-----... PRE PJSM. Rig down rig components. Scope down & layover derrick. PRE Finish RID & Prep to move. PRE Move from MPL-01a to MPE-30a. PRE Spot in Rig sub over MPE-30a wellhead. Had difficult time due to MPE-5 well location. Took 3 attempts to get spotted in so Pipe Shed misses MPE-5. PRE Spot Rig Sub, Pits, Pipe Shed, and Camp. PRE Raise and Scope Derrick. PRE ACCEPTED RIG @ 0300 hrs. R/U lines to Tree and to Tiger Tank. DECOMP P/U Lubricator and pull BPV, UD same. Take on 120 F Seawater to Pits. DECOMP Pre-Job Safety meeting with Rig Crew, Tool Pusher, and Co-Man. 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. P/U TWC and set in Hanger. N/D Tree and Adaptor Flange. Make check for fit for the replacement TreenOkay. N/U Test Spool and Adaptor. CIO Pipe Rams to 2-3/8". R/U test equipment, fill stack and Choke Manifold, prepare to test BOPE to 250 Low, 3500 high. 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. Drain stack. P/U lubricator & pull TWC. UD TWC & lubricator. Had trouble pulling due to frozen plug. M/U landing jt into tubing hanger. BOLDS. Pull hanger to floor wI 46K. Unplug ESP cable & check conductivity. UD hanger & landing jl. Pull ESP cable & Heat Trace over sheave & attach to reel in spooling unil. 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 BIO and UD ESP. Clear and clean Rig Floor. RID Elephant Trunk. Place old ESP components in shipping boxes. Conduct Rig Safety audil. M/U new ESP Pump and Motor; Centralizer, Sensor, Motor FMH, Lower Tandem Seal, Upper Tandem Seal, Gas separator, Pump, Pump, Discharge head. PJSM for running of ESP. Make up flat head motor cable with splice between discharge head and 10' pup. Test conductivity. TIH and tag top of 5-1/2" liner top. POH, find bottom protector on MLE to be 4.95" O.D. Removed and installed flat bands, reinstall guards. TIH 2-3/8" ESP completion checking conductivity every 2000'. 10:30 - 11:00 0.50 KILL P DECOMP 11 :00 - 12:30 1.50 WHSUR P DECOMP 12:30 - 15:00 2.50 BOPSU P DECOMP 15:00 - 16:30 1.50 BOPSU P DECOMP 16:30 - 18:00 1.50 BOPSU P DECOMP 18:00 - 21 :30 3.50 BOPSU P DECOMP 21 :30 - 23:00 1.50 WHSUR P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 11/15/2005 00:00 - 01 :30 1.50 PULL P DECOMP 01 :30 - 13:00 11.50 PULL P DECOMP 13:00 - 14:30 1.50 PULL P DECOMP 14:30 - 16:00 1.50 PULL P DECOMP 16:00 - 16:30 0.50 PULL P DECOMP 16:30 - 18:00 1.50 RUNCO RUNCMP 18:00 - 19:30 1.50 RUNCO RUNCMP 19:30 - 20:00 0.50 RUNCO RUNCMP 20:00 - 22:00 2.00 RUNCO RUNCMP 22:00 - 00:00 2.00 RUNCO RUNCMP Printed: 11/21/2005 11 :47:27 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date _._--~._- - 11/15/2005 11/16/2005 01 :30 - 02:30 02:30 - 04:00 04:00 - 06:00 06:00 - 08:30 08:30 - 14:00 14:00 - 15:30 15:30 - 18:00 BP EXPLORATION Operations Summary Report 2.00 2.50 DFAL RUNCMP MPE-30 MPE-30 WORKOVER NABORS ALASKA DRilLING I NABORS 4ES Fro~__~ ~_~__!_~~urs Task I Code NPT '_~h~_~~ 22:00 - 00:00 2.00 RUNCO 00:00 - 01 :30 1.50 RUNCO RUNCMP RUNCMP 1.00 RUNCO RUNCMP 1.50 RUNCO RUNCMP DFAL RUNCMP DFAL RUNCMP 5.50 DFAL RUNCMP 1.50 RUNCMP 18:00 - 19:30 1.50 RUNCMP 19:30 - 20:30 1.00 RUNCMP 20:30 - 00:00 3.50 RUNCMP 11/17/2005 00:00 - 09:00 9.00 RUNCMP 09:00 - 10:00 10:00 - 16:30 16:30 - 23:00 11/18/2005 23:00 - 00:00 00:00 - 02:30 02:00 - 06:00 1.00 6.50 RUNCMP RUNCMP 6.50 RUNCO HMAN RUNCMP 1.00 RUNCO 2.50 BOPSU P 4.00 WHSUR P RUNCMP RUNCMP RUNCMP Page 2 of 3 Start: Rig Release: Rig Number: Spud Date: 7/25/1989 End: 11 /8/2005 11 /1 8/2005 Description of Operations Flushing pump wI 0,1 bbls at 900 psi. 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. R/U Heat Trace line through sheaves and install 100 jts above bottom GLM, check cable, flush pump, keep hole full. 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. POOH with ESP completion. SIB 2-3/8" tubing in Derrick. Remove Flat Guards. Find damage to ESP Cable within Hoot 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. Splice ESP Cable to new Pigtail assembly. Service Pump and Motor. Motor checks out electrically. 8/0 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, 8/0 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. 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-55 production casing. Spooler Generator problems, machanic came and fixed RIH Esp completion testing every 2000' (20 stds) cable, flush pump .1 bbl at 900 psi. Continue RIH to 33 stda and 1 single R/U Heat Treat line and test cable and HIT, flush pump Good continue running ESP. 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 5-flat guards per joint and a short guard across each coupling. P/U #2-GLM and 3-singles from PIS and continue RIH. M/U Hanger to string and get parameters: P/U wt 46,000 Ibs, SIO wt 36,000 Ibs. Used 5-Protectolizers, 3-Flat Guards, and 3-bands on the Pump/Motor 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. 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. Land Tbg. Hanger RILD Set TWC and test 3500 psi. Change rams and Nipple Down BOPE. Replace L.D.S on Well Head. N/U Lock Down Flange, Tubing Printed: 11/21/2005 11 :47:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION 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: Date ! From - To Hours i Task' Code I NPT Phase I ! ". _.._._______n_________. _.________ .____. __ _.....;....... _.__. _._ ___.... . _m_.' 11/18/2005 02:00 - 06:00 4.00 WHSUR P Page 3 of 3 Spud Date: 7/25/1989 End: Description of Operations -- -. ......-.------.---.... RUNCMP Head Adaptor, and Tree. Test Tree and Tubing Head Adaptor to 5,000 psi. Pull TWC with Lubricator and install SPY. Milne Point Operations will freeze Protect the well. Release rig @ 0600 hours. Printed: 11/21/2005 11:47:27 AM Permitto Drill 2010110 DATA SUBMITTAL COMPLIANCE REPORT 61312003 Well Name/No. MILNE PT UNIT SB E-30A Operator BP EXPLORATION (ALASKA) INC MD 8626 -~ TVD 4458 ~ Completion Dat 5/20/2001 '~ Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_9o Sample N.._9o Directional Survey N._9o APl No. 50-029-22903-01-00 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt E.D--~C~ .... Cn See Notes Interval Log Log Run OH I Name Scale Media No Start Stop CH 1 300 8000 Case (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments 4/24/2002 ~--..~lJ38~ell report ti' ~j!.. ~. 4~24~2002 ¢~--0~62~-XcDNGIset U~TU~ CSAT~t~,~, See Notes Ver LIS Verification T T Cn e -ED~-~3 ........ Cn See Notes ~,- ~ R~-'''''~ ~ ~3ir~ecti6'~i Survey ~~' ~ MWD Su~ey -- ~~ 10326 ~- ~ ~Wellbore Profile ~ ~ ~Resistivi~ / OR ~ ~ ~esistivi~ / GR Ve,,ca ,o. 1 1791 7994 Case 1 6465 8626 Open 198 13552 Open 6465 7144 Open 1 1780 7257 Case 1 0 1792 Case FINAL FINAL OH FINAL 6465 7144 OH FINAL 6757 7144 OH FINAL 6757 7144 CH FINAL 6757 7144 OH FINAL CH 7/9/2001 9/24/2001 /-~26 9/24/2001 9/23/2001 9/24/2001 8/23/2001 4/18/2002 ,~ 0759 5/21/2001 ~r~"--"~r~-~ /t/"~'-~r( 9/24/2001 ~ro326 6465-7144 4/24/2002~mation Evaluation Logs and Surveys 4/24/2002 ~0~- AITDENS1TT-NEEI-T~ON Directional MWD Survey 6465-7144 Digital data ¢ 6757-7144 BL, Sepia 6757-7144 BL, Sepia 6757-7144 BL, Sepia Lis Verification Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 6~3~2003 Permit to Drill 2010110 Well Name/No. MILNE PT UNIT SB E-30A Operator BP EXPLORATION (ALASKA) INC MD 8626 'I'VD 4458 Well Cored? Y I'~ Chips Received? .~~ Analysis R~.ceived? Completion Dar 5/20/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~.~ N Formation Tops ~_~ APl No. $0-029-22903-01-00 UIC N Comments: Compliance Reviewed By: Date: • • Maunder, Thomas E (DOA) From: Sent: To: Cc: sup;eat: a~~^~3'~ Attachments: jack_hartc.vcf (2 KB) Bill, a©1- ~c~3 I reviewed the proposal regarding circulation of water through the annuli of wells at MPU and found it to be a reasonable approach to handle the problems that were outlined. The type of completion employed in these wells did not require a packer, so there were no regulatory issues that required a permit. We agree with your proposal to circulate water to improve pump efficiency. It looks like a novel approach to an unexpected problem. Let us know if you have any questions. Jack Hartz "Mathews, William L" wrote: > Morning Jack, > > I don't have any velocity concerns with what we are proposing. At 750 > bwpd in the 7" x 2-7/$" annulus we are moving water at 17.25 ft/min. > Compare this to some of our current jet pump applications where we are > moving up to 2000 bwpd down a 7" x 3-112" annulus (well MPJ-23). This equates to 52.5 ft/min. > Flow rates at S-pad will be even higher as we plan to use up to 4000 > bwpd down a 7-5/8" x 4-112" annulus giving us 106 ftlmin. > Bill > > -----Original Message----- , > From: Jack Hartz [mailto:jack hertz@admin.state.ak.us] > Sent: Tuesday, April 02, 2002 8:43 AM > To: Mathews, Bill > Subject: [Fwd: [Fwd: Milne Pt. Well I-12]] > Bill, > I left a message on your machine earlier this a.m., regarding the > proposal to circulate water thru the well annuli. My only question is: > are there any velocity issues or concern about erosion? The rates you > suggest appear nominal. I don't think there are any other questions > from here. > > Thanks, > > Jack Hartz > 793-1232 ~I G ~~~~ ~~,h~ ,. `~ 1 II ~~ ` O Jack Hartz (jack hertz@admin.state.ak.us} Wednesday, April 03, 2002 5:49 PM Mathews, William L Thomas E Maunder Milner a Pt._I,-11, I-12 and E-30~ ular water circulation jack_hartz.vcf 1-C~ l~, • • Maunder, Thomas E (DOA From: Jack Hartz (jack_hartz cLDadmin.state.ak.usj Sent: Tuesday, April 02, 2002 11:08 AM To: Daniel T Seamount JR; CamiiCe Taylor Cc: Thomas E Maunder Subject: Ad}udication Meeting 4!2/2002 -MPU I-11, t-12 and E-30A Attachments: jack hartz.vcf jack_hartz.vtf (2 KB) Subject: Milne Pt. Unit - Schrader Bluff - Water circulation down annuli of wells to provide heat and volume to pumped fluids. BPX has requested approval to circulate water down the annulus of 3 MPU Schrader Bluff wells. The purpose of the water circulation is to heat wellbore produced fluids and increase the efficiency of the ESPs installed in these wells. Lower API gravity in this area has caused lower rate compounded by higher viscosity making the pumps oversized for the rates being produced. No heat trace was installed initially because they anticipated higher gravity and higher rates (warmer production conditions). The circulating water substitutes as a different type of heat trace. Circulating water down the annulus will increase the pump efficiency by heating the fluids and adding volume to the pump. The Schrader Bluff wells will not flow on their own and have been completed without packers to allow more efficient separation of the gas from the well stream. There are no mechanical, velocity, erosion or reservoir issues to inhibit their doing this procedure. Recommendation: I recommend we acknowledge their proposal and indicate our agreement. In my opinion, they don't need approval to conduct this operation. Let me know if there are any questions, etc. Jack (Following is a copy of the Emails from BPX on the subject. I'll bring the mechanical diagrams to the meeting.) -jdh Subject: RE: [Fwd: [Fwd: Milne Pt. Well I-12]] Date: Tue, 2 Apr 2002 12:07:50 -0600 From: "Mathews, William L" <MathewWL@BP.com> To: "'Jack Hartz"' <jack hartz@admin.state.ak.us> Morning Jack, I don't have any velocity concerns with what we are proposing. At 750 bwpd in the 7" x 2-7/8" annulus we are moving water at 17.25 ft/min. Compare this to some of our current jet pump applications where we are moving up to 2000 bwpd down a 7" x 3-1/2" annulus (well 1 MPJ-23). This equates to 52.5 ft/min. Flow rates at S-pad will be even higher 4-1/2" annulus giving us 106 ft/min. Bill • as we plan to use up to 4000 bwpd down a 7-5/8" x -----Original Message----- From: Jack Hartz [mailto:jack hartz@admin.state.ak.us] Sent: Tuesday, April 02, 2002 8:43 AM Ta: Mathews, Bill Subject: [Fwd; [Fwd: Milne Pt. Well I-12]] Bill, I left a message on your machine earlier this a.m., regarding the water thru the well annuli. My only question is: are there any velocity issues or concern about erosion? The rates nominal. I don't think there are any other questions from here. Thanks, Jack Hartz 793-1232 proposal to circulate you suggest appear »»»» » » »»» »»»»»»»»»»»»»»»»»»»»»»»»» Subject: [Fwd: Milne Pt. Well I-12] Date: Fri, 22 Mar 2002 16:10:47 -0900 From: Tom Maunder <tom maunder@admin.state.ak.us> To: John D Hartz <jack hartz@admin.state.ak.us> Jack, FXI. I think this is a good idea. Water should be less problematic than heat trace. What do you think? Tom Subject: Milne Pt. Well I-12 Date: Fri, 22 Mar 2002 13:45:38 -0600 From: "Mathews, William L" <MathewWL@BP.com> To: "'tom_maunder@admin.state.ak.us"' <tom maunder@admin.state.ak.us> Tom, Milne Pt. well I-12 was drilled and completed in December of 2001 as a multi-lateral producer in the Schrader Bluff OA and OB sands. The well was expected to come on line at >1500 bopd, but due to poorer than anticipated oil quality (17 deg API/200+cp versus an expected 21 deg API/22 cp), has failed to produce up to expectation. Initial rates were around 800 bopd and quickly fell off to less than 300 bopd. Since the well completion was designed around the higher rates, heat trace was not installed in the well. As rates fell, wellbore fluids cooled off, making it difficult to keep the well on production. The well would have eventually died due to the high viscosity and cooler temperture of the crude. To prevent this, a temporary water line was installed to allow operations to slip stream 500-1000 bwpd down the annulus in an effort to warm up the well and improve the ESP efficiency. This was successful, allowing the well to stay on production at -350 bopd. The well was shut in pending an acid stimulation and appraisal for a more permanent water installation. A foam divert acid stimulation was performed in 2 i • early March. The well came back on line and has so far been able to sustain an oil rate of 500-700 bopd with a water slip stream of 750 bwpd. BP is requesting approval to permanently tie-in this well to the injection water header to allow us to continue to slip-stream water down the annulus at 500-1000 bwpd. A more permanent installation will provide a cost effective way to keep this well on line. In addition to well I-12, there are two more wells that may benefit from a similar installation. These are well I-11 (recently drilled well adjacent to I-12 and now shut in) and well E-30A which was drilled last year along the northern periphery of the Schrader Bluff field. BP is requesting approval to permanently tie these wells in should it be necessary to maintain their ability to produce at economical rates. I've attached wellbore schematics and a production plot for MPI-12 for your consideration. Please give me a call if you would like to discuss this in more detail or have any questions. Bill Mathews Schrader Bluff Completion Engineer 564-5476 440-8496 cell «MPI-12 Schematic.ZIP» «MPI-11 Schematic.ZIP» «MPE-30A Schematic.pdf» «MPI-12 Well Tests.doc» 3 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-PB 1 Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-G,R print I Borehole Profile Sent By: Jos, efBerg Received ~23~ ~~''-''''-''~-''' I Date: Sept 18, 2001 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 RECEIVED SF.P 2.4 2001 Alaska 0il & Gas Cons. Commi~ion Anchorage i~ STATE OF ALASKA ( ALAS OIL AND GAS CONSERVATION COMMisSION 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. 201-011 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22903-01 4. Location of well at surface ~' ............ l~;-,-v..~./l~,~-~ 9. Unit or Lease Name 3853' NSL, 1923' WEL, SEC. 25, T13N, R10E, UM 1 Yr'~tliiO ' Milne Point Unit At top of productive interval 106' NSL, 678' WEL, SEC. 24, T13N, R10E, UM At total depth t~ ~,,,?~'i':~',-:¥- "! i St~ '~ 10. Well Number 169' NSL, 828' EWL, SEC. 19, T13N, R11E, UM t,_~..~_~iI ..! J.~,H~I MPE-30A ""~' 'I"~'~" ........ ~' 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 57.05' ADL 047438 12. Date Spudded 113. DateT.D. Reached114. Date Comp., S/usp., or Aband. 115. Water depth, ifoffshore .16. No. of Completions 4/24/2001 4/27/2001 5. ,,/~7~/20~0/12 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV setI 21. Thickness of Permafrost 8626 4458 FTI 8626 4458 FTI [] Yes [] NoI None MDI 1800' (Approx.) 22. Type Electric or Other Logs Run RES, GR 23. CASlNG~ 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' 6738' 6-3~4" ~'47 sx Coldset III, 158 sx Foamed, 70 sx 'G' 2-7/8" 6.4~ '1_-80 6673, 8291' " 3L'3/4, LJncemented Siotted 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 6679' - 8256' 4426' - 4463' 8291' - 8626' 4463' - 4458' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 47 Bbls of Diesel 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 6/27/2001 6 TEST PERIOD 822 369 1I 449 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 lithol0gy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED. JUL Jt 0 001 Alaska Oil & Gas Cons. Commission 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 6737' 4462' Base of Schrader OA 7983' 4472' RECEIVED JUL .1. O ZOO/ Alaska Oil & Gas Cons. Commission Anchorage 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 TerrieHubble ,-'~~~'"~- ' ~ 'Title TechnicalAssistant Date MPE-30A 201-011 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 OR!GiklAL. BP EXPLORATION Page 1 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 #4 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 BOPSUF P PROD1 Safety meeting. 06:30 - 13:30 7.00 BOPSUF P PROD1 PT BOPE. Test H2S and LEL alarms. AOGCC witness Chuck Scheve. 13:30 - 15:30 2.00 BOPSUF 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 BOPSUF 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 WEXIT 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 WEXIT 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 WEXIT TIH w/window milling BHA. 01:45 - 02:30 0.75 STWHIP P WEXIT Open circ-sub. Displace hole to 9.3 ppg KCL. Close circ-sub. 02:30 - 07:00 4.50 STWHIP 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. ReP 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 WEXIT ~ Ream and backream window 2.8/3400. 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 3.2/3150. 11:30 - 12:30 1.00 STWHIP P WEXIT 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 eXP. POOH. Replace eXP. 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 Fie-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 2.3/3600 slow with Printed: 5/24/2001 3:02:49 PM BP EXPLORATION Page 2 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 4/24/2001 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 #4 (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 f/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 2.25 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 +/- 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/BH^#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 I 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 idrilling. RIH wt. 6-8K#, drilling w/3k# string wt 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 I Short trip to window. 15:35 - 18:20 2.75 DRILL P PROD1 I Drill ahead following dip. 2.4 bpm. Drilled to 7520'. 18:20 - 19:45 1.42 DRILL P PROD1 IWiper trip to window. 19:45 - 20:25 0.67 DRILL P PROD1 I Drilling ahead. 2.4 bpm 3625 psi 4k# wob. Drilled to 7570 20:25 - 21:40 1.25 DRILL N RREP PROD1 i Pop-off valve on Nabors 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 O^ 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 Summar 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 P PROD1 no weight bobbles. 11:15 - 17:15 6.00 DRILL P 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 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 fl 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 f/8009' 100-120/fph lk# 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 i 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, f/ 8220' to 8330' md 4406' tvdss. 4/27/2001 00:00 - 00:45 0.75 DRILL P PROD1 Continue drilling in OA sand f/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' tvdss. 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 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 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 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 P PROD1 P/U 1 1/4" CSH. Make up Baker deployment tools. 22:00 - 22:15 0.25 DRILL 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: 5/24/2001 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 OA 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 FIopro. 17:30 - 20:30 3.00 DRILL P PROD1 OOH. 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 LID 1 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 off21' of coil. Find cable wadded up in coil. Cut cablewas 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 RIH w/BHA #8. DS-49, 1.4 deg. motor, eXP. 15:50 - 17:30 1.67 DRILL P PROD1 Log GR tie in f/6600'. (-4') Also fill "gap" in GR log by logging to 6750' GR depth. Set down 6673'. Repeats solid. Good weight transfer, getting 6k# WeB. Must be top of liner. 17:30 - 18:30 1.00 DRILL N DF^L 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 we Baker whipstock. Pump across coil min rate. 23:45 - 00:00 0.25 DRILL N DFAL PROD1 P/U BHA #9 (77.70') wi 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 GR tie 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 Ip 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 BH^ 3464psi annular pressure at BHA 2392psi, pump pressure 3740,WEB 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 1.00 DRILL P PROD1 Adjust motor to 1 degree, add resistivity tool, test tool 02:30 - 03:40 1.17 DRILLP PROD1 RIH to 6545' 03:40 - 04:15 0.58 DRILL P PROD1 Tie in -11' 04:15 - 05:00 0.75 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# web 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 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 P 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 orienter/OXP. 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 BH^ 3119 psi annular pressure at BH^ 2477. Pump pressure 3171 at 2.5 bpm. ROP 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 OA. Shales above the O^ 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 f/7570', 50R TF. Back into OA sand at 7577'md 4421' tvdss 95 deg @ bit leveling off and plan to decrease angle following OA. Drilled to 7720'. Swapping out old FIo-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 WOB. 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 0.831 DRILL P PROD1 Wiper trip to window. 15:35 - 17:30 1.921 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 1.501 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 DF^L 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 rop, 3350 CT psi, 2.3bpm. Dropping angle to 82-83 deg. 10-20' rop. 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' rop 90-100'/hr 2-3k# wob 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 RIHto Iog 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: 5/24/2001 3:02:49 PM BP EXPLORATION Page 7 of 8 Operations Summar 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 11.00 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 web, -10k string wt. Drill into shale @ 8330'. ReP @ 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, lk# WeB. ReP 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. ReP 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 BHA. 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 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 5/7/2001 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 1 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 SICP 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 P COMP P/U LUBRICATOR & PULL 5 1/2" TWC. LID SAME. 01:30 - 02:30 1.00 WHSUR P COMP M/U X-OVER & PULL FALSE BOWL. LID SAME. 02:30 - 03:00 0.50 RUNCOI~ COMP PJU TO RUN 2 3/8" TBG. 03:00 - 06:30 3.50 RUNCOI~ COMP RIH W/2 3/8" TBG TO 3500'. 06:30 - 08:30 2.00 RUNCOI~ COMP R/U CIRCULATE OUT FREEZE PROTECTION. MONITOR WELL. 08:30 - 10:00 1.50 RUNCOI~ COMP PULL OUT OF HOLE & STAND BACK TBG. 10:00 - 11:00 1.00 RUNCOI~ COMP PJSM. R/U TO RUN COMPLETION. CHANGE OUT ESP SHEAVE. 11:00 - 14:00 3.00 RUNCOI~ COMP M/U, SERVICE & TEST ESP. 14:00 - 15:30 1.50 RUNCOI~ 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 R/U 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 RUNCOr~ 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 RUNCOI~ 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 RUNCOr~ COMP SPLICE NEW HEAT TRACE PIGTAIL. 23:30 - 00:00 0.50 RUNCOI~ COMP LAND TBG HANGER. P/U WT 43K, S/O VVT 33K. RILDS 5/20/2001 00:00 - 00:30 0.50 RUNCOI~ COMP SET TWC. DRAIN BOP & HARD LINES. 00:30 - 03:00 2.50 BOPSUF 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: 5/24/2001 3:03:10 PM MILNE POINT, ALASKA TO: J.BIXBY/SMITH FROM: O'Malley WELL# MPE-30 Main Category: Maint Sub Category: Freeze protect Operation Date: 5/22/01 Pump Objective: Frz. Protect the well after 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 after re-completion. SIWHP= 0# IA= 0 Diesel Used 1 47 AFE# 337234 9335-070-725 AFE# 337234 9335-070-780 OA= Diesel = $1974 HB&R = $ 875 Methanol Used lnone Obp BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Field: Milne Point Site: M Pt E Pad Well: MPE-30 Wellpath: MPE-30A Bate: 6/19/2001 Time: 10:20:36 Page: 1 Ce-ordhate(Ng) Reference: Well: MPE-30, True North Vertical (TVD) Reference: MPE-30:57.05 57.0 Section (VS) Reference: Well (0.00N,0.00E,200.00Azi) SuFvey Coicuhtiou Metliod: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map:Zone: Alaska, Zone 4I ECEIV n Coordinate System: Well Centre Geomagnetic Model: BGGM2001 ,JUL 09 ?OOl. lll3~Ra 0il & Gas COns. Commissio 52.982 0.655True W Anchorage 0.53 deg 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 Latitude: 70 26 569440.72 ft Longitude: 149 26 North Reference: Grid Convergence: 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 ff Easting: 569220.04 ff Longitude: 149 26 6.428 W Position Uncertainty: 0.00 ft Wellpath: MPE-30A Drilled From: MPE-30 500292290301 Tie-on Depth: 6737.00 ft Current Datum: MPE-30:57.05 Height 57.05 ff Above System Datum: Mean Sea Level Magnetic Data: 4/9/2001 Declination: 26.37 deg Field Strength: 57448 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0,00 0.00 200.00 Survey: MWD Start Date: 4/27/2001 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD ' , , 6737.00 4461.52 KOP 8626.00 4458,48 TD Survey MD 'Inci Azim TVD SSTVD N/S E/W MapN ,MapE ' DLS VS deg: deg' ff fi' . ff : ff ff : deg/100ff ff 6737.00 52.31 42,39 4461.52 4404.47 3069.30 2614.98 6019483.51 571806.14 0.00 -3778.57 6767.70 61.50 42.40 4478.27 4421.22 3088.27 2632.30 6019502.64 571823.29 29.92 -3802.33 6797.60 78.40 46.50 4488.48 4431.43 3108.21 2651.93 6019522,75 571842.73 57.96 -3827.77 6827.30 87.60 61.20 4492.12 4435.07 3125.50 2675.67 6019540.26 571866.30 58.03 -3852.14 6857.30 89.20 75,10 4492.96 4435.91 3136.63 2703.43 6019551.65 571893.96 46.62 -3872.10 6887.30 93.50 90.40 4492.25 4435.20 3140.41 2733.09 6019555.70 571923.57 52.95 -3885.79 6917.50 95.10 107.10 4489.97 4432.92 3135.85 2762.75 6019551.42 571953.27 55.39 -3891.65 6949.00 92.70 125.40 4487.81 4430.76 3122.00 2790.81 6019537.64 571981.45 58.45 -3858.23 6978.00 93.80 132.00 4486,16 4429.11 3103.91 2813.39 6019519.96 572004,20 23,04 -3878.96 7008.00 90,30 132.30 4485,09 4428.04 3083.79 2835.61 6019500.05 572026.61 11,71 -3867.65 7040.00 86,60 132.20 4485,96 4428.91 3062.29 2859.29 601 9478.77 572050.48 11.57 -3855.54 7068.00 87.90 138.30 4487.30 4430.25 3042.44 2878.97 6019459.10 572070.34 22.25 -3843.62 7098.00 88.00 141.60 4488.37 4431.32 3019.49 2898.26 6019436.34 572089.84 11.00 -3828.65 7128.00 87.20 145.70 4489.63 4432.58 2995.35 2916.02 6019412.37 572107.83 13.91 -3812.05 7158.00 87.60 148.90 4490.99 4433.94 2970.14 2932.21 6019387.31 572124,25 10.74 -3793.89 7188.00 88.00 152.10 4492.14 4435.09 2944.05 2946.97 6019361.36 572139.25 10,74 -3774.42 7218.00 87.90 156.40 4493.22 4436.17 2917.05 2959,99 6019334.49 572152.52 14.33 -3753,51 7248.00 89.30 158.00 4493.95 4436.90 2889.41 2971.61 6019306.95 572164.39 7.09 -3731.50 BP Amoco ~ _~ bp '~-~" Baker Hughes INTEQ Survey Report INTEQ Compaay: BP Amoco Dale: 6/19/2001 Time: 10;20:36 Page: 2 Fl~l: Mllne Point Co-e~llaal~(Ng) Reference: Well: MPE-30, True Norlh Site: M Pt E Pad Vertlml (13rl)) Referemce: MPE-30:57,05 57,0 Well: MPE-30 Seelloa (rS) RefereBce: Well (0,00N,0,00E,200,00Azi) Wellpat~: MPE-30A SB~ey Cmicalatlem Metkod: Minimum Cunratura Db: Oracle Survey MD Iici Aztm T'v3) &~TVD N/S E/W MapN MapE DLS VS ft deg deg n ft ~t ft ~ ft deg/lOOft ft 7278,00 89,40 159,20 4494,29 4437,24 2861.48 2982.55 6019279,13 572175,60 4,01 -3709,00 7308,00 89,70 162,40 4494.53 4437.48 2833,15 2992.42 6019250.90 572185,72 10.71 -3685.76 7338,00 90.30 164,80 4494.53 4437.48 2804,37 3000,89 6019222,20 572194,46 8.25 -3661,61 7367,00 91.20 166,20 4494.15 4437.10 2776,30 3008,15 6019194.20 572201.98 5.74 ~3637,72 7398,00 91.70 169,90 4493,36 4436,31 2745.99 3014.56 6019163,95 572208,67 12.04 -3611.43 7429,00 90,40 171,30 4492,79 4435,74 2715,41 3019,63 6019133,43 572214,02 6.16 -3584,42 7459,00 89,90 173,70 4492,72 4435,67 2685,67 3023.64 6019103,73 572218.21 8,17 -3557,82 7489,00 89,30 178,00 4492,93 4435,88 2655,76 3025,71 6019073,84 572220,66 14,47 -3530,45 7519,00 91,90 183,90 4492,61 4435,56 2625,78 3025,22 6019043,86 572220,44 21,49 -3502,11 7550,00 93,10 185.80 4491.26 4434,21 2594,92 3022,60 6019012,98 572218,11 7,24 -3472,22 7580,00 89,10 189,40 4490.68 4433,63 2565,20 3018,63 6018983,23 572214,42 17,94 -3442,93 7610,00 90,60 194,60 4490,76 4433,71 2535,87 3012,40 6018953,84 572208.46 18,04 -3413,23 7640,00 91,70 200,20 4490,16 4433,11 2507.26 3003,43 6018925,15 572199,76 19,02 -3383,28 7670,00 90,20 203,60 4489,66 4432,61 2479,43 2992,24 6018897,23 572188,83 12,39 -3353,31 7700,00 88,40 208,70 4490,03 4432,98 2452,51 2979,03 6018870,19 572175,87 18,03 -3323,50 7730,00 88,40 210,50 4490,87 4433.82 2426.44 2964,22 6018843,98 572161.30 6,00 -3293,93 7760,00 88,50 215,40 4491,68 4434,63 2401,28 2947,91 6018818,68 572145,23 16,33 -3264,71 7790,00 93.00 220,00 4491,29 4434,24 2377.56 2929,58 6018794.79 572127,12 21,45 -3236,15 7820,00 96,40 221,30 4488,83 4431,78 2354,88 2910,10 6018771,93 572107,86 12,13 -3208,18 7850,00 96,40 217,00 4485,48 4428,43 2331,76 2891,29 6018748,64 572089,26 14,24 -3180,02 7680,00 95.90 212.40 4482,27 4425,22 2307,25 2874,31 6018723,97 572072,52 15,34 -3151,18 7910,00 95,90 206,40, 4479,18 4422,13 2281.26 2859,67 6018697,85 572058.12 19,89 -3121,75 7940,00 96,00 202,00 4476,07 4419,02 2254,05 2647,44 6018670,53 572046,14 14,59 -3092,00 7970,00 95,60 196,20 4473,03 4415,98 2225,86 2837,68 6018642,26 572036.64.. 19,28 -3062,17 8000,00 94,40 191,70 4470,42 4413,37 2196,86 2830,48 6018613,20 572029,71 15,47 -3032,46 8030,00 91,60 194,80 4468,85 4411,80 2167,71 2823,61 6018583,98 572023,12 13,91 -3002,71 8062,00 92,20 188.80 4467.79 4410,74 2136,42 2817.07 6018552,63 572016,87 18,83 -2971,07 8092,00 91,50 183,70 4466,82 4409,77 2106,62 2813,81 6018522,81 572013,89 17,15 -2941,96 8119.00 90,90 178,10 4466,25 4409.20 2079.64 2813,39 6016495,83 572013,71 20,85 -2916,46 8150,00 91,30 171,20 4465,65 4408,60 2048,80 2816.27 6018465,02 572016,89 22,29 -2888,47 8180,00 91,60 165,60 4464,90 4407,85 2019,44 2822,30 6018435,72 572023,19 18,69 -2862,93 8212,00 92,10 163,70 4463,86 4406,81 1988,59 2830,77 6018404,96 572031,94 . 6,14 -2836,85 8242.00 90.80 167.80 4463.10 4406.05 1959.53 2838.15 6018375.97 572039.59 14.33 -2812.06 8274.00 90,20 171.80 4462.82 4405.77 1928.05 2843.81 6018344.54 572045.55 12.64 -2784.41 8319.00 89.90 178.40 4462.78 4405.73 1883.24 2847.66 6018299.77 572049.80 14.68 -2743.62 8349.00 89.90 182.20 4462.84 4405.79 1853.24 2847.50 6018269.78 572049.93 12.67 -2715.38 8379.00 90.10 189,90 4462.84 4405.79 1823.43 2844.34 6018239.94 572047.04 25.68 -2686.29 6409.00 90.70 193.20 4462.63 4405.58 1794.04 2838,33 6018210,50 572041,31 11,18 -2656,62 8443,00 92,20 194,60 4461,77 4404,72 1761,05 2830,17 6018177,44 572033,45 6,03 -2622,82 6470,00 92,50 201,20 4460,66 4403,61 1735,39 2821,88 6018151,71 572025,41 24,45 -2595,88 8500,00 91.90 202,60 4459.51 4402.46 1707,58 2810,70 6018123,80 572014,49 5,07 -2565,92 8530,00 92,00 204,90 4458,49 4401,44 1680,14 2798,63 6018096,25 572002,67 7.67 -2536.00 8580.00 91,40 208,80 4457,60 4400,55 1653,39 2785.08 6018069,38 571989,38 13,15 -2506,23 8586.00 88,70 210,90 4457,57 4400,52 1630,84 2772.15 6018046,71 571976.65 13.16 -2480.62 8626,00 88,70 210.90 4458,48 4401.43 1596.53 2751,61 6018012,21 571956,43 0,00 -2441,35 5705~ 26OO 2OO 4OO 6OO 8OO IOO0 1200 140O 1600 1800 2000 2700 2400 2600 280O 3000 3200 3400 3600 3800 4000 420O 4400 4600 48OO 50£ azu~ West(-)/East(+) [20Oft/in] 6/1912001 10:22 BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 71312001 Time: 16:39:37 Page: 1 Field: Milne Point Coordinate(NE) Reference: Well: MPE-30, True North Site: M Pt E Pad Vertical (TVD) Reference: MPE-30:57.05 57.0 Well: MPE-30 Sectieu (~S) Reference: Well (0.00N,0.00E,44.44Azi) We#path: MPE-30APB1 Sum/ey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Gee Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ~. ~YS Dakin.m_!....Me_an~_e_a~_L_e_v_e! ...................................................... .G?? ~ _a? e_t?~ _M_ °_d_e l_'' ......... BG__G_M_ ?_01__ 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 Lasting: 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:well Position:MPE-30MPE-30+E/_w+N/-S 2593.85.196.55 ftft Lasting :N°rthing: 6016390.34569220.04 ftft SIOtLatitude:Longitude:Name: 14970262730 18.4926.428 wN ~ sitlo_n__ .U_.~ ??._ta.!_n_~! ...................... 0.00 ft Wellpath: MPE-30APB1 Drilled From: MPE-30 500292290370 Tie-on Depth: 6737.00 ft Current Datum: MPE-30:57.05 Height 57.05 ft Above System Datum: Mean Sea Level Magnetic Data: 7/3/2001 Declination: 26.31 deg Field Strength: 57464 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 44.44 Survey: MWD Start Date: 4/24/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation Survey 6887.30 93.50 90.40 4492.25 4435.20 3140.41 2733.09 6019555.70 571923.57 52.95 4155.78 6917.50 95.10 107.10 4489.97 4432.92 3135.85 2762.75 6019551.42 571953.27 55.39 4173.29 6949.00 92.70 125.40 4487.81 4430.76 3122.00 2790.81 6019537.84 571981.45 58.45 4183.06 6978.00 93.80 132.00 4486.16 4429.11 3103.91 2813.39 6019519.96 572004.20 23.04 4185.96 7008.00 94.90 133.90 4483.89 4426.84 3083.53 2835.28 6019499.78 572026.28 7.30 4186.74 7038.00 96.20 135.70 4480.99 4423.94 3062.49 2856.47 6019478.94 572047.66 7.38 4186.55 7068.00 96.60 138.30 4477.64 4420.59 3040.69 2876.80 6019457.33 572068.19 8.72 4185.22 7098.00 94.80 139.30 4474.66 4417.61 3018.23 2896.46 6019435.06 572088.06 6.86 4182.96 7106.00 94.80 140.60 4473.99 4416.94 3012.13 2901.59 6019429.01 572093.25 16.19 4182.19 7144.00 94.80 140.60 4470.81 4413.76 2982.87 2925.63 6019399.97 572117.55 0.00 4178.13 6737.00 52.31 42.39 4461.52 4404.47 3069.30 2614.98 6019483.51 571806.14 0.00 4022.31 6767.70 61.50 42.40 4478.27 4421.22 3088.27 2632.30 6019502.64 571823.29 29.92 4047.99 6797.60 78.40 46.50 4488.48 4431.43 3108.21 2651.93 6019522.75 571842.73 57.96 4075.97 6827.30 87.60 61.20 4492.12 4435.07 3125.50 2675.67 6019540.26 571866.30 58.03 4104.93 6857.30 89.20 75.10 4492.96 4435.91 3136.63 2703.43 6019551.65 571893.96 46.62 4132.32 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser THRU: Tom Maunder ~dr(~.~~ P.I. Supemisor 'q l>h FROM: Chuck Scheve Petroleum Inspector NON~ CONFIDEN~L DATE: April 22. 2001 SUBJECT: Blowout Preventer Test Nabors 3S BPX MPU E-30A 201-011 Milns Point I MPU Operator Rep.: John McMullen Contractor Rep.: RoRer Smith Op. phone: 659-7086 Rig phone: 659-7020 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 250/,3500 Annular: 250~2500 Choke: 25013500 PIF PIF Quantity PIF Location Gen.: P Well Sign P Upper Kelly., NIA ..... Housekeeping: P Drl. Rig . P Lower Kelly, ,N/A , , . PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted , p , Inside BOP BOP STACK: Quantity Size/Type PIF MUD SYSTEM: Visual Alarm Stripper.. Trip Tank N/A Annular Preventer 1 7 1116" P Pit Level Indicators P P #1 Rams 1 Blind/Shear P Flow Indicator P P #2 Rams I 2 318" combi P Meth Gas Detector P P #3 Rams 1 2 718" combi P H2S Gas Detector P P #4 Rams I 2 3~8" combi P #5 Rams Quantity PIF Choke Ln. Valves 1 2 1/16 P Inside Reel valves HCR Valves 1 2 1/16 P Kill Line Valves 2 2 1116 P ACCUMULATOR SYSTEM: Check Valve I P Time/PresSUre P/F System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2400 P Quantity P/F 200 psi Attained 13 sec P No. Valves 13 P Full Pressure Attained 30 sec P Manual Chokes 1 P Blind Switch Covers: All P Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2100 average I traveled to E Pad in the MPU to witness the initial BOP test on well E-30A by the coil tubing drilling rig Nabors 3S. The testing went well with two failures observed. Valve #3 on the choke manifold failed to pressure test, this valve was serviced and retested OK. During the accumulator test the lower 2 3/8 rams were accidently closed on the 2 7/8" test joint, these rams were replaced and the new set tested. All pressure tests were held for 5 rain on the low test and 10 rain on the high pressure test. The Rig was very clean and all related equipment appeared to be in good condition. Total Test Time: I...Q Number of failures: 1,:. CC: Attatchments: none BOP Nabors 3S 4-22-01 CS 4126/01 ALASIL~ 0IL AND GAS CONSERVATION COMP~ISSION TONY KNOWLES, GOVERNOR 333 W. 7*" 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 Re: Milne Point Unit- MPE-30A BP Exploration (Alaska) Inc. Permit No: 201-011 Sur Loc: 3853'NSL, 1923'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc. 4105'NSL, 2859'EWL, Sec. 19, T13N, RilE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced'well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount Commissioner BY ORDER OF TIlE CO.M. MISSION 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 -- ALASKA Oi~ ,ND GASpERMiTCONSERVATIONTo DRILL COMMIS{' ,N /"'~' 20 AAC 25.005 la. Type of work [] Ddll [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Sen~ice [] Development Gas [~ S.~e Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE - 57.05' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ~-z~"5'/~ ~'~.DL 047438 4. Location of well at surface 7. Unit or""Property Name 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, R11 E, UM MPE-30A Number 2S100302630-277 At total depth 9. Approximate spud date l~¢'~ ~,~EWL, 19, T13N, R11E, UM Amount $200,000.00 ,,,/~, ;z-~,~'¢/~'~ ~. SE~E.C. 02/15/01 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047437, ¢,P~d"' MDz~..CJI ¢{~ No Close Approach 2560 10361' MD / 4459' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6750' MD Maximum Hole Angle 100 o Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Weiqht Grade Couplinq Len,qth MD TVD MD TVD (include stare data) 3-3/4" 2-7/8" 6.16# L-80 STL 3621' 6740' 4405' 10361' 4459' Uncemented Slotted Liner II '~, i...,.. '~.,~ ~.-.. · 19. To be completed for Redrill, Re-entry, and Deepen Operations. J.~N '[ Present well condition summary Total depth: measured 7200 feet Plugs (measured) true vertical 4744 feet Alaska Oil & Gas Cons. Gommission 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 Goldset 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, 564-4?50 21. I hereby certify that the fore_going is tru~ and corrl~,~rlo the best of my knowledge ,,. Signed Mark Johnson ,.,~~., ~,.~~1~e CT~"--~- Drilling Engineer. Date..~'/, /( / 'i :.':: .... ' ""; ".:" !i'" "' '.': :' ':, :': :,':' ';."' '"::.": ':' "'~',;' :." :'.;"..:'.,, ';::. :.,,;:.'. :";':' ;" '~'/~ i~ ;': ':':COmmiS~iO"",:'U~'b:OriiY'::'?:i"':.' ':.~':: .'~, .;~ ,,:;.."'; :.: ~.:!..,.,,: ':.: :'".' :. :. :. ~.,.~.. ;' :' ',;: ..:..! .:'.' ,:"::'? ~:' ':,~ :..:.'..:: "?' : '? ':i ,: :":,:' !'..:: ', Permit Number . I APl Number /~ '} ' Approval Date'. ' t See c(~v'er le'tter ' ~ / - ~///~ 150- 029-22903-01 I ~'~¢//~'- ~ I for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures ~.Yes [] No Directional Survey Required ~Yes [] No Required Working Pressure for BOPE 1-12K []3K 1"I4K []5K []10K []15K ~.5KpsiforCTU Other: ,Op, IGii4AL SIGt4[-~D BY by order of Approved By F~ Taylor Seamount Commissioner 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 of Operations: E-30 will be sidetracked with two horizontal wellbores (E-30a and E-30a L1 ) to target Schrader Bluff OA reserves. Coiled Tubing Drilling (CTD) will perform the sidetracks. Pdor to CTD arrival, 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 2) Mill window through 5 %" and mill 5' of openhole - service coil. 3) MIRU CTD rig - Drill horizontal sidetrack E-30a from window to TD targeting Schrader Bluff OA sand interval as per attached directional plan. from TD to ~10' inside of 5 %" casing. CTD Drill and Complete E-30a L1 Lateral pro.qram: Planned for February 21, 2001 ") 5) CTD set flowthrough whipstock at 66~5' (in 5 %" casing at 520 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. , ~10 outside of casing_g_.._____,,,, Mud Program: · Steps l& 2: Seawater · Steps 3-8: Flo-Pro (8.9-9.4 ppg) RECEIVED 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. JAN 1 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/fi) to surface is 1400 psi. E-30a and E-30a L1 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 H2S 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 JAN I 2 2001 Alaska Oil & Gas Cons. Commission Anchorage Tree: 2 9/16" - 5M Wellhead: 7" 5M Varco ADRS-7 Weld M PU E'30 O,~. ~ _.,. = Orig. GL Elev. = 23.2' on style --r iil ~ to 7- csg. hng. = 33.6 (N 27E) Tbg. Hng: 2 7/8" x 11" FMC w/2 7/8" ! NSCT T~,B and 2.5" CIW H BPV [~ Iii ---- ""' profile I 115' ''! ~ i, 7-x5.5"X-Over ~ 13 3/8" 72 ppf, L-80 ~ / ' / KOP @ 500' ! Blll~,, Camco 2 3/8" x 1" Max. hole angle = 69 to 73 deg. ! sidepocket KBMM GLM I 120' I Iii from 3950' to 5850' / Hole angle thru' perfs =,~deg. / il {~ 5.5" Port Collar Cementer ~ 1336'md J ~ Centrilift heat trace 2 3/8" 4.70" ppf, J-55, 8 rd EUE tbg.. ! ( drift ID =1.995 ", cap. = 0.00387 bpf )/ / 5.5" 15.5 ppf, J-55, Btrc. prod. casing ~ ( drift ID 4.95O", cap. 0.0238 bpf ) / / ~ll ~,, : Camco 2 3/8" x'l" , , , ~lt'lI~ sidepocket KaUU GEM !11 I ~lml~ KUDU 110TP/1800 PCP, 16536'1. ~~1 Centrilift flex shaft intake tvd Centrilift seal section 6 5 0' Stimulation Summary ~ fst3dblresh6aflashsn OA / OB Sands - Limited entry frac w/119.6 M# of PropLoked 16/30 Badger prop. behind pipe. ~ Centriliff FMH series, , ~ 54 hp motor, 1020 v./35 I'6,584I ~ amps. [ 9:01 Gear Box ] ~ , perforation Summary ~ Centriliff PHD Ref Ioq: , .Siz.e.. SPF Interval .. i (TVD) 'o^, san~ II 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" dia., 1.3 s.g. ball sealers ~ ~. 5.5" float collar (PBTD) 5.5" float shoe 7'169' md 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) I II RECEIVED JAN J- 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' 5 1/2" 15.5~ long string casing RECEIVED JAN _l ?~ ZOO1 Alaska Oil & Gas Cons. Commission Anchorage MPE-30a L1 TD 9775' 3.75" Openhole Whipstock at 6745' Existing Peds 6758-6778' 6845-6865' ClBP 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 500292290360 Parent Wellpath: MPE-30 Tie on MD: 6750.00 Vertical Section Origin: Slot- 30 (0.00,0.00) Vertical Section Angle: 40.83° Rig: Depth Reference: MPE-30:57.05 57.05ft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: MPE-30, True North Vertical (TVD) 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 'rVD MDAnnotalJo~ 4365.09 6672.61 Tie-in Paint 4412-42 6750.OO Ir, Jc~-ofl Point 4464.89 6914.OO 1 4456.O7 7014.00 2 4417.92 7432.99 ~ 442~.oa 7035.:$o 4453.95 8851.06 5 4458.95 g688.07 6 4458.90 10361.29 TD Azimuths to True North Magnetic North: 26.46° Magnetic Field Strength: 57447nT Dip Angle: 80.79° Date: 11412001 Model: BGGM2000 W~path: (MPE-3Ofi:'iar~2 MPE-30L1) C~eated By:. ~ij Po~nis DNe: 1/5"2001 ,' :. _ ~ ~: ,. ~ ~. : : :. . - : 58o0:..:-4-:-.:~..~- .............. ~-: - ",. -,-~ -! ......... ~ -':;'- - ~ ~" T ...:..........:~ ....... ~ ........ !...~............~...~ ..... ~ ...... :. s~----:~:-F:----.-----~ .......... :/ ;~? ": ~ ~X ~ ~'":~ ~ ~ :. : ~::~.:/ ....... 5~--:2 ~' '''::''j''':':':':'''L'-'''::'" ~ ;::: ..~ ....... · :. j '. ; ~.~ ........ ; .......... : ....... ... ~ : ~ .. ,. ~ ;:;- - .F :: ': ::.:' ~. · - i .... ; ~. ~ : : , ~ · : : .: .... ..... .... : ; ;:~-:?.' . ~ / ..: ~'~ ~ :X~ : : : ~ : ~ ~ - _ . ; . : : ~ · · ~ . ; '~ :~: ._ _~- _.-:'.- ~- .. ~ :..f : ~ : ~ - : ~ ; : ~ ~---.: "t .... :' ':. ~4~--:--?-----.-----?---~--: '~:: ............. ._ .: ......... ~ ............ ,¥.. '. . ;' ~ · ~ . ; _ ~ . : : ~- . . ~.:~ .-; :. I~~ ~ : ~ ; ' . .... ~ '"'- '" :' ~. ~~ ..... ~ :: x :. - ~ .:' ': ' ; : ; : ; ~ "'k: ' : -.f. .... ..... .-, .: ~ .:- ~ . I ~~ : : : ,'~: , . ~.:~ -~.-,. -~ · : .,:...~, -: · , . 3~4 T" ~ ~ .... ~.. : ":' ':' ~"x': '' a -'- · : j - ~-.] .... ~ · -(: ............... - 6 ":~ ' .~ ~ ~ ..... ~ ..... ~ ... '.. ; .'... IMPR.13~MPR-I~k - 2 )~ ~'~'~'~"~'~'?~'T'?'?'?'?'~'r'~?~"r'~'~'. ~.. ~T?~T~?'?'~T]'~T~?~'~'r'~"?T?~ 12~ 14~ 16~ 18~ 2~ 22~ 24~ 26~ 28~ 3~ West(-)/East(+) [20~in] m © m m Plot 1/5/2001 3:17 PM Obp BP Amoco £-i'__; m t. Baker Hughes INTEQ Planning Report ................. Company: BP Amoco Date: 1/5/2001 Time: 10:25:40 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,40.83Azi) Wellpath: Plan#2 MPE-30C-~ O,.,. Survey Calculation Method: Minimum Curvature Db: Oracle 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 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-30L1 Drilled From: MPE-30 500292290360 Tie-on Depth: 6750.00 ft Current Datum: MPE-30:57.05 Height 57.05 ft Above System Datum: Mean Sea Level Magnetic Data: 1/4/2001 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 40.83 Plan: Plan #2 Date Composed: 1/4/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ......................................................................... . Map Map <--- Latitude ---> <--- Longitude .... >] Name . DesCription· TVD .' +N/-S ' +E/-w Northing Easting . Deg Min SeC .' Deg Min' Sec / · . Annotation 6672.61 4365.09 Tie-in Point 6750.00 4412.42 Kick-off Point 6914.00 4464.88 1 JAN 1 g Z001 7014.00 4456.06 2 7432.99 4417.95 3 Alaska Oil & Gas Cons. Commission 7935.39 4426.95 4 8851.06 4453.95 5 /~nO~agu 9686.07 4458.95 6 10361.29 4458.95 TD Plan Section Information Inci . ...... Azim TVD. +N/'S i +E/-w · DLS · BUild "TUrn TFO Target · ...ft deg 'deg ft ft . . ft deg!100ft.deg/100ft deg/100ft deg 6672.61 52.28 41.82 4365.09 3031.50 2580.82 0.00 0.00 0.00 0.00 6750.00 52.32 42.51 4412.42 3076.89 2621.92 0.71 0.05 0.89 86.02 6914.00 90.00 61.83 4464.88 3167.47 2743.47 25.41 22.98 11.78 29.84 7014.00 100.00 84.86 4456.06 3195.94 2838.10 25.00 10.00 23.03 65.75 7432.99 90.00 43.69 4417.95 3374.00 3205.00 10.06 -2.39 -9.83 -101.22 7935.39 88.08 353.46 4426.95 3835.00 3360.00 10.00 -0.38 -10.00 -92.50 8851.06 89.30 85.50 4453.95 4467.72 3881.52 10.05 0.13 10.05 90.77 9686.07 90.14 1.97 4458.95 5019.00 4409.00 10.00 0.10 -10.00 -89.78 ObP BP Amoco Baker Hughes INTEQ Planning Report [~:Yti~-~ ....................... Company: BP Amoco Date: 1/5/2001 Time: 10:25:40 Page: 2 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,40.83.a. zi) Wellpath: Plan#2 MPE-30t~I' O... Survey Calculation Method: Minimum Curvature Db: Oracle 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 10361.29 89.86 69.77 4458.95 5534.78 4781.99 10.04 -0.04 10.04 90.20 Survey MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ff ft deg 6672.61 52.28 41.82 4365.09 3031.50 2580.82 6019445.40 571772.34 0.00 3981.18 0.00 MWD 6675.00 52.28 41.82 4366.55 3032.91 2582.08 6019446.82 571773.59 0.00 3983.07 0.00 MWD 6700.00 52.29 42.07 4381.84 3047.62 2595.30 6019461.65 571786.67 0.78 4002.84 86.02 MWD 6725.00 52.31 42.29 4397.13 3062.28 2608.58 6019476.43 571799.81 0.71 4022.62 85.87 MWD 6750.00 52.32 42.51 4412.42 3076.89 2621.92 6019491.16 571813.01 0.71 4042.39 85.73 MWD 6775.00 57.89 46.24 4426.72 3091.52 2636.27 6019505.93 571827.22 25.41 4062.84 29.84 MWD 6800.00 63.56 49.53 4438.94 3106.12 2652.44 6019520.68 571843.26 25.41 4084.47 27.71 MWD 6825.00 69.29 52.51 4448.94 3120.52 2670.25 6019535.23 571860.93 25.41 4107.01 26.09 MWD 6850.00 75.08 55.28 4456.59 3134.53 2689.48 6019549.42 571880.02 25.41 4130.18 24.90 MWD 6875.00 80.89 57.89 4461.79 3147.98 2709.88 6019563.06 571900.30 25.41 4153.70 24.05 MWD 6900.00 86.72 60.43 4464.49 3160.72 2731.21 6019575.99 571921.51 25.41 4177.28 23.51 MWD 6914.00 90.00 61.83 4464.88 3167.47 2743.47 6019582.86 571933.70 25.47 4190.40 23.20 MWD 6925.00 91.13 64.34 4464.77 3172.45 2753.28 6019587.93 571943.46 25.00 4200.58 65.75 MWD 6950.00 93.68 70.05 4463.72 3182.13 2776.29 6019597.82 571966.38 25.00 4222.95 65.77 MWD 6975.00 96.20 75.79 4461.57 3189.44 2800.09 6019605.35 571990.11 25.00 4244.04 66.01 MWD 7000.00 98.66 81.59 4458.33 3194.31 2824.38 6019610.44 572014.35 25.00 4263.61 66.51 MWD 7014.00 100.00 84.86 4456.06 3195.94 2838.10 6019612.20 572028.05 24.99 4273.81 67.18 MWD 7025.00 99.78 83.76 4454.17 3197.01 2848.88 6019613.38 572038.83 10.06 4281.68 258.78 MWD 7050.00 99.28 81.26 4450.03 3200.23 2873.33 6019616.82 572063.24 10.06 4300.09 258.59 MWD 7075.00 98.75 78.77 4446.11 3204.51 2897.64 6019621.33 572087.51 10.06 4319.22 258.18 MWD 7100.00 98.21 76.29 4442.42 3209.85 2921.78 6019626.89 572111.60 10.06 4339.05 257.79 MWD 7125.00 97.66 73.81 4438.97 3216.24 2945.70 6019633.50 572135.45 10.06 4359.52 257.42 MWD 7150.00 97.09 71.34 4435.76 3223.66 2969.35 6019641.14 572159.03 10.06 4380.60 257.08 MWD 7175.00 96.51 68.88 4432.81 3232.11 2992.70 6019649.80 572182.29 10.06 4402.25 256.76 MWD 7200.00 95.91 66.42 4430.10 3241.56 3015.68 6019659.47 572205.19 10.06 4424.43 256.47 MWD 7225.00 95.31 63.96 4427.66 3252.00 3038.26 6019670.12 572227.67 10.06 4447.09 256.20 MWD 7250.00 94.69 61.52 4425.48 3263.41 3060.40 6019681.73 572249.70 10.06 4470.20 255.96 MWD 7275.00 94.07 59.07 4423.57 3275.76 3082.05 6019694.28 572271.23 10.06 4493.70 255.75 MWD 7300.00 93.44 56.63 4421.93 3289.03 3103.17 6019707.74 572292.22 10.06 4517.55 255.56 MWD .,~25.00 92.80 54.20 4420.57 3303.20 3123.72 6019722.10 572312.64 10.06 4541.71 255.40 MWD ~50.00 92.16 51.76 4419.49 3318.24 3143.66 6019737.32 572332.43 10.06 4566.12 255.27 MWD ,~75.00 91.51 49.33 4418.69 3334.11 3162.95 6019753.38 572351.58 10.06 4590.75 255.17 MWD .7._40~.00 90.87 46.90 4418.17 3350.80 3181.56 6019770.23 572370.02 10.06 4615.54 255.09 MWD ;~;~2~00 90.21 44.47 4417.93 3368.26 3199.44 6019787.86 572387.74 10.08 4640.45 254.91 MWD ~3~99 90.00 43.69 4417.95 3374.00 3205.00 6019793.65 572393.25 10.08 4648.42 254.89 MWD ?~5~. 00 89.93 41.99 4417.96 3386.47 3216.57 6019806.23 572404.70 10.00 4665.42 267.50 MWD Z~75.00 89.82 39.49 4418.02 3405.41 3232.88 6019825.32 572420.83 10.00 4690.42 267.50 MWD ~00.00 89.71 37.00 4418.12 3425.04 3248.35 6019845.09 572436.12 10.00 4715.39 267.51 MWD ~7~5.00 89.60 34.50 4418.27 3445.33 3262.96 6019865.51 572450.54 10.00 4740.29 267.52 MWD 0.00 89.49 32.00 4418.47 3466.24 3276.66 6019886.54 572464.05 10.00 4765.07 267.53 MWD 7575.00 89.39 29.50 4418.71 3487.72 3289.44 6019908.14 572476.63 10.00 4789.68 267.55 MWD 7600.00 89.28 27.00 4419.00 3509.74 3301.28 6019930.26 572488.25 10.00 4814.08 267.58 MWD 7625.00 89.18 24.51 4419.34 3532.25 3312.14 6019952.87 572498.90 10.00 4838.21 267.61 MWD 7650.00 89.08 22.01 4419.72 3555.22 3322.01 6019975.93 572508.56 10.00 4862.04 267.64 MWD 7675.00 88.98 19.51 4420.15 3578.59 3330.87 6019999.38 572517.20 10.00 4885.52 267.68 MWD 7700.00 88.88 17.01 4420.62 3602.32 3338.70 6020023.18 572524.81 10.00 4908.60 267.72 MWD 7725.00 88.78 14.51 4421.13 3626.38 3345.49 6020047.29 572531.37 10.00 4931.24 267.77 MWD 7750.00 88.69 12.01 4421.68 3650.70 3351.22 6020071.67 572536.88 10.00 4953.39 267.82 MWD 3S CTD BOP Detail 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 ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I - 7" Riser I I I 1 Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure I Blind/Shear I 2 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 Standpir. manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE I I Manual over Hydraulic TOT 2" Side outlets 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/OO Tubing F Spo~ 7" Annulus 9 5/8" Annulus RECEIVED JAN 1 2 Alaska Oil & Gas Cons. Commission Anchorage H 181289 DATE 1~1oo PYMT HANDL INVOICE / CREDIT MEMO CK122100d :OMMENTS: Pee~ NC INST: S/H DESCRIPTION -ee z50 ~it To Deill - Sondea X4 100.00 THE ATrACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVF- GROSS 01/03/01 0018128c) DISCOUNT NET 100. O0 ANCHORAOE AK c)~501 No.. :~H ..,.:.:.::.-.1. 8:128 9 CONSOLIDAirED COMMEFICIAE:AccOUNT '%0 ~":i~.*'~:~ ::'':~: '"" 120 DAYS " ..:-. :!' '.. ?:, :¥.;:.!. :.:?,:.:::.:: :,._:.,~-:: .o~:,.v.,.,c,.,.~. :~,::,;i::.:~:.':~::;: i-:-i:::::" -!::! !'!: :.:::.:-:? -:i:i-:::;. .i:ii':i!!]. .i!ii: :! ::'fir:::"': " : WELL PERMIT CHECKLIST COMPANY ~'~-' WELL NAME. ~:--.,,~/Or PROGRAM: exp FIELD & POOL ,.-~--~- ~'"//-/~--d_") INIT CLASS _~~ _,~'~ / L__ GEOL AREA ADMINISTRATION 1. Permit fee attached ....... ~.~..~.~, ...... .,~.,/.. 2. Lease number appropdate.,~ ~. '! .'.. ,.-~ ~. / ,¢~.- ~. i . . 3. Unique well name and number .................. APPR DATE 12. ~/~ /,/'?.L~" 13. ENGINEERING dev -' reddl v' serv wellbore seg ann. disposal para req ,~"~¢O UNIT# D///..~,.~ ON/OFF SHORE ~)/7 GEOLOGY 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 ddlling 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 ........ Permit can.be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. J APPJ~ DATE I ,,? 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 circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: Y N~') . ' Y N --~ If diverter required, does it meet regulations .......... - ¥ Ddlling .fluid program schematic & equip list adequate ..... ~) N . BOPEs, do they meet regulation ............... L.-YJ N BOPE press rating appropriate; test to ,'~_.~,.~r,.~ psig. ~ N ~-,~,~ \~-k(~L._~ ~ t ~'J~-%~,J.;.~'~,%, ~-~~~ Choke manifold complies w/APl RP,53 (May 84) ........ Work will occur without operation shutdown ....... .... ~_1~. , ~., , , , ' ~ ~ p ~\ (-, ~-~-"'~'"'"'~.' ~..-""~'""~.~ "~ Is presence of H2S gas probable ................. y ~ '~._~~\% ~-.,~¥ ¥~,~5~-~',./ ~--~',,~3~o,.¥,~--¥,,;)_~.. ,,-~,,~, ~ ~----~,,~ ,,~(r..o ~'~-~ ]i Permit can be issued wlo hydrogen sulfide measures ..... Y('N~ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ......... Seabed conditiOn survey' (if off-shore) ............ ..,/~'~' Y N ' ' Contact name/phone for weekly progress reports [explor/eXd~ only] Y N ' GEOLOGY: UlC/Annular COMMISSION: Comments/Instructions: Z O --I c:\msoffice\wordian\diana\checklist (rev. 11/011/00) 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 APPENDIXl. No 'special'effort has been made to chronologically ,o organize this category of information. o/--oll **** REEL HEADER **** MWD 01/09/18 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/04/24 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 6465.0000: STOP.FT 7144.0000: 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 R3~NG 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-PB1 Milne Point Unit 3863' NSL, 1923' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 24-Apr-01 500292290370 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-PB1 was drilled off a whipstock on well MPE-30. KOP @ 6747' MD (4410' SSTVD) . (5) Baker Hughes INTEQ Runs 1-2 utilized the Orient Express service to mill casing window from 6740' MD (4406' SSTVD) to 6747' MD (4410' SSTVD) and drill 10 ft formation. (6) Baker Hughes INTEQ Runs 3-4 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 6747' MD (4410' SSTVD) to 7144' MD (4414' SSTVD) . (7) The interval from 7114' MD (4416' SSTVD) to 7144' MD (4414' 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 26.31 degrees has been applied to the Directional Survel,~. MNEMONICS: GPJIX ROPS TVD RACLX RPCLX PuACHX 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 DIRECTIONAL N/A N/A N/A N/A 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 83 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ............................ WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPE-30A-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 ODFP 1 GR GRAX 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: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FP~AME 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 RACL COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 API F/HR 0.0 0.0 0.0 Total Data Records: 38 Tape File Start Depth = 6465.000000 Tape File End Depth = 7144.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 51 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/04/24 151686 01 **** REEL TRAILER **** MWD 01/09/~8 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape Subfile 2 is type: LIS DEPTH GR ROP RPCH RPCL 6465.0000 62.9370 -999.2500 -999.2500 -999.2500 6465.5000 62.2170 -999.2500 -999.2500 -999.2500 6500.0000 76.5390 -999.2500 -999.2500 -999.2500 6600.0000 61.0050 -999.2500 -999.2500 -999.2500 6700.0000 -999.2500 -999.2500 -999.2500 -999.2500 6800.0000 59.1940 131.2340 -999.2500 -999.2500 6900.0000 62.6900 124.3270 -999.2500 -999.2500 7000.0000 70.6160 147.0250 14.2080 14.5580 7100.0000 57.4460 53.6860 -999.2500 -999.2500 7144.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 6465.000000 Tape File End Depth = 7144.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet RACH -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 15 0950 -999.2500 -999.2500 RACL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.3380 -999.2500 -999.2500 /0'7..59 **** REEL HEADER **** MWD 02/03/26 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/26 151686 01 1.75" NaviGamma - Gamma Ray 1.20 Datum *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!! !!!!!!!! Extract File: ldwg.las ~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION WRAP. NO: ~Well Information Block %MNEM.UNIT Data Type %- STRT.FT STOP FT STEP FT NULL COMP WELL FLD LOC CNTY STAT. SRVC. TOOL. DATE. API . 6465.0000: 8626.0000: 0.5000: -999.2500: COMPANY: WELL: FIELD: LOCATION: COUNTY: STATE: SERVICE COMPANY: TOOL NAME & TYPE: LOG DATE: API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value % - One line per frame Information __ Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. MPE-30A Milne Point Unit 3863' NSL, 1923' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 27-Apr-01 500292290301 Description SECT. 25 TOWN.N Ti 3N RANG. Ri 0E PDAT. MSL EPD .F 0 : Section : Township : Range : Permanent Datum : Elevation Of Perm. LMF . RKB : Log Measured from Bushing Floor Level FAPD.F 57.05 : DMF . KB : EKB .F 57.05 : Feet Above Perm. Datum Drilling Measured From Elevation of Kelly EDF .F N/A : Elevation of Derrick EGL .F N/A : Elevation of Ground CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) and Resistivity data (RACLX, RPCHX, RACHX, RPCLX) presented is realtime data. (4) Well MPE-30A was drilled as an open hole sidetrack on well MPE-30A-PB1. KOP @ 7020' MD (4428' SSTVD). (5) Baker Hughes INTEQ Runs 1 utilized the Orient Express service from 6747' MD (4410' SSTVD) to 8626' MD (4401~ SSTVD). (6) The interval from 8564' MD (4401' SSTVD) to 8626' MD (4401' 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 26.37 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX = Gamma Ray MWD-API [MWD] (MWD-API units) ROPS = Rate of Penetration, feet/hour TVD = Subsea True Vertical Depth (SSTVD), (feet) RACLX = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) RPCLX = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], ohm-m) RACHX = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], ohm-m) RPCHX = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], ohm-m) TCDX = Borehole Temperature (deg F) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ~ N/A No Depth Shift applied. Gamma Ray MWD is the PDC. Tape Subfile: 1 75 records... Minimum record length: Maximum record length: 14 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 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 not been depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve GR ROP RACH RACL RPCH RPCL TCD *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GRAX 0.0 ROP ROPS 0.0 RACH RACHX 0.0 RACL RACLX 0.0 RPCH RPCHX 0.0 RPCL RPCLX 0.0 TCD TCDX 0.0 * FORMAT RECORD (TYPE% 64) Data record type is: 0 Datum Frame Size is: 32 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: 31 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 7 Curves: Name Tool Code Samples Units 1 GR MWD 2 ROP MWD 3 RACH MWD 4 RACL MWD 5 RPCH MWD 6 RPCL MWD 7 TCD MWD 68 1 API 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 DEGF Total Data Records: 140 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 28 Tape File Start Depth = 6465.000000 Tape File End Depth = 8626.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 154 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/03/26 151686 01 **** REEL TRAILER **** MWD 02/03/26 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 999.25 6465.0000 00 -999.2500 62.9370 -999.2500 999.25 6465.5000 00 -999.2500 62.2170 -999.2500 6500.0000 999.2500 -999.2500 76.5390 -999.2500 6600.0000 999.2500 -999.2500 61 0050 -999 2500 6700.0000 999.2500 -999.2500 -999 2500 -999 2500 6800.0000 12.7670 11.8930 59 1940 12 8660 6900.0000 10.9360 12.3540 62 6900 12.1660 7000.0000 15.3380 14.2080 63 3770 14 5580 7100.0000 13.6230 12.9070 57 9740 13 2070 7200.0000 11.9140 11.3420 62 4240 11 7000 7300.0000 10.2060 12.4960 59 3970 11.4460 7400.0000 11.8320 7.9030 70 2890 9 2110 7500.0000 7.2760 6.4860 61.5090 6.6600 7600.0000 4.0540 4.3290 102.9530 4.1060 ROP TCD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 27.0000 -999.2500 30.0000 -999.2500 -999.2500 131.2340 22.0000 124.3270 24.0000 147.0250 22.0000 146.4180 22.0000 140.0520 23.0000 138.3530 24 0000 19 4900 25 0000 97 2100 26 0000 32 3890 28 0000 RACH -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 14 6460 12 5910 15 0950 14 0210 12 1540 11 2170 9 8620 6 8610 3 8440 RACL 7700.0000 4.4140 4.3590 7800.0000 4.4070 4 3320 7900 0000 4.8660 4 5580 6.5120 8000 0000 7 4470 8.1360 8100 0000 8 9740 7.8100 8200.0000 8.1900 7.8510 8300.0000 7.9500 84OO.OOOO 9.9660 12.4200 8500.0000 9,3370 9.8570 8600.0000 999.2500 -999.2500 8626.0000 999.2500 -999.2500 101.4350 4.4130 101.6740 4.3780 92.2650 4 6460 57 0760 6 9780 61 2310 8 6550 64 1010 7 9660 58 0860 7 9060 52 8640 11 5140 57 5410 9.6420 -999.2500 -999.2500 -999.2500 -999.2500 38 0270 29 0000 13 7340 29 0000 18 2470 28 0000 98 0170 30.0000 131 2340 29 0000 130 5090 30 0000 131 2340 29 0000 130 7490 29 0000 130 7010 29 0000 107 7990 30.0000 -999.2500 -999.2500 4.6640 4. 5670 4.8150 6.8690 9.0050 7.9440 8.0470 11.3450 9.8590 -999.2500 -999.2500 Tape File Start Depth = 6465.000000 Tape File End Depth = 8626.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS