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Home My WebLink About204-135Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 InspectNo:susKPS250809175340 Well Pressures (psi): Date Inspected:8/9/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:4/17/2020 #320-158 Tubing:300 IA:0 OA:250 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/4/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT I-19 Permit Number:2041350 Wellhead Condition All Valves in good working order and with working gauges on the tbg, IA and OA Surrounding Surface Condition All looks good no debris or trash and no visible sheen Condition of Cellar No water in cellar no visible sheen and no trash or debris Comments Location verified from pad map Supervisor Comments Photos (3) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, September 22, 2025               2025-0809_Suspend_MPU_I-19_photos_ksj Page 1 of 2 Suspended Well Inspection – MPU I-19 PTD 2041350 AOGCC Inspection Rpt # sus250809175340 Photos by AOGCC Inspector K. StJohn 8/9/2025 2025-0809_Suspend_MPU_I-19_photos_ksj Page 2 of 2 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type MPU C-04 500292080100 182-126 2/27/2021 Wipestock MPU I-07A 500292260201 221-010 5/8/2021 Perf Record MPU L-06 500292200300 190-010 5/18/2021 Wipestock MPU S-21 500292306500 202-009 6/3/2021 Perf Record MPU F-116 500292365000 219-133 1/25/2020 Perf Record MPU I-19 500292321800 204-135 4/10/2020 CCL Please include current contact information if different from above. eceived By: 07/22/2021 37' (6HW By Abby Bell at 3:14 pm, Jul 22, 2021 1. 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 9,720 feet N/A feet true vertical 4,088 feet N/A feet Effective Depth measured 9,720 feet feet true vertical 4,088 feet feet 2,838' 7,428' 1,696' Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6#, L-80 5,460' 3,470' Packers and SSSV (type, measured and true vertical depth)N/A See Above 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: 3,580psi 6,890psi 8,430psi 2,090psi 4,790psi 7,500psi4-1/2" 2,999' 7,428' 7,355' 2,549' 4,075' 4,063' TVD 112' Oil-Bbl measured true vertical Packer 9,720'4-1/2" 12,199' HRD-E ZXPN, HES HRD ZXP, Baker ZXP WINJ WAG Water-Bbl MD 112' measured 161' 4,045' 4,088' 161' 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 204-135 50-029-23218-00-00 Plugs ADL0025906 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 I-19 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured 2,405' N/A Slot Liner 'OB' Casing Conductor Size Junk Length 5,012' Surface Slot Liner 'OA' 20" 10-3/4" 4-1/2" Surface Intermediate 10-3/4" 7-5/8" Senior Engineer: Senior Res. Engineer: Collapse 520psi 2,470psi N/A N/A Burst 1,530psi 5,210psi Liner 5,456', 7,144', 7,326' 3,468', 4,000', 4,056' 777-8333 2. Operator Name N/A N/A 112' 161' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.10.07 16:18:21 -08'00' By Samantha Carlisle at 11:24 am, Oct 09, 2020 MGR12OCT2020 RBDMS HEW 11/12/2020 SFD 10/12/2020 DSR-10/12/2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: 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 0 OA 100 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Location verified by Pad map 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 ArendMPI-19L1 (907)240-4383 Follow Up Actions Needed: Hilcorp 204-136 Condition of Surrounding Surface Location: 04/08/20 320-159 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPI-19L1 Suspended Well Inspection 9-20-20 _____________________________________________________________________________________ Revised By: TDF 5/12/2020 SCHEMATIC Milne Point Unit Well: MPU I-19 Last Completed: 3/06/2020 PTD: 204-135 “OB”TD =9,720’(MD) / TD =4,088’(TVD) 20” Orig. DF Elev. = 69.10’ / Orig. GL Elev.= 24.80’ 7-5/8”9, 10, 11, 12,13 1 5 8 6,7 5 “OA” Lateral PBTD = 9,720’(MD) / PBTD =4,088’(TVD) “OB” Lateral 10-3/4” 2 3 4 TOC @6,620’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A N/A Surface 112' N/A 10-3/4” Surface 45.5 / L-80 / BTC-M 9.950 Surface 161’ 0.0962 10-3/4” Surface 45.5 / K-55 / BTC-M 9.950 161’ 2,999’ 0.0962 7-5/8" Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,428’ 0.0459 4-1/2” Liner 12.6 / L-80 / IBT 3.958 5,456’ 7,355’ 0.0152 4-1/2” Slotted Liner “OA” 12.6 / L-80 / IBT 3.958 7,187’ 12,199’ 0.0152 4-1/2” Slotted Liner “OB” 12.6 / L-80 / IBT 3.958 7,315’ 9,720’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / EZGO-HT 3.958 Surface 5,460’ 0.0058 JEWELRY DETAIL No Depth Item 1 32.82’ 4-1/2” Tubing Hanger 4-1/2” 2 5,449’ Top of Locator Sub on 10’ Seal Assembly stabbed into ZXP 3 5,456’ HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" : 4 5,476’ Flex Lock LNR Hanger 7-5/8" x 5-1/2" 5 7,144’ HES HRD ZXP Liner Top Packer 6 7,187’ 4-1/2” x 7-5/8”Baker LEM #1 7 7,187’ 4-1/2” Hook hanger inside casing (outside hook point 7,204’) 8 7,263’ 2-7/8” XN Nip, ID= 2.323” 9 7,310’ L-1 Non-Locating Seal Assembly 10 7,315’ Baker Tie Back Sleeve 11 7,326’ Baker ZXP Liner Top Packer 12 7,332’ Baker HMC Liner Hanger 13 7,340’ Baker Sealbore extension OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42” Hole 10-3/4”468 sx of Class Lite and 254 sx Class “G” in 13-1/2” Hole 7” 757 sx Class “G” in 9-7/8” Hole 4-1/2” OA 97 bbl of 15.8 ppg Class G cement; TOC @ 6,620’ MD 4-1/2” OB 35 bbl of 15.8 ppg Class G cement; Est TOC @ 7,380’ MD WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 75 deg. @ 6,450’, 50+ deg. from 2,500’ MD GENERAL WELL INFO API: 50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 - 9/13/2004 ESP RWO by Nabors 4ES – 2/12/2005 ESP RWO and Install LEM by Nabors 3S – 10/17/2008 ESP RWO by Nabors 4ES – 1/10/2010 ESP RWO by Doyon 16 – 2/14/2013 ESP RWO by ASR#1 – 10/8/2017 ESP RWO by ASR#1 – 3/06/2020 COIL TUBING CEMENT PLUGBACK – 4/17/2020 LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 7,192’ to 7,204’ Well Angle @ Window =72 deg. WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 11” 5M Gen. FMC Gen 5, 4-1/2” FMC tubing hanger, 4-1/2” H563 on top & 4-1/2” 4-1/2” H521 bottom, 4” CIW=H BPV Profile Suspended Well Inspection Review Report }nspectNo: sus8DB200921142415 Date Inspected: 9/20/2020 ' Inspector: Brian Bixby' Type mfInspection Well Name: M|LNEPTUNIT |-l9 - Permit Number: 2041350 Suspension Approval: Sundry - # 320'158 ' Suspension Date: 4/17/2020 ' Location Verified? 11-11 If Verified, How? Other (specify in comments) Offshore? El Initial Date AO6[CNotified: 8/18/2020 Operator: Hi|corpA|aska, LLC Operator Rep: Jon Arend � Wellbore Diagram Avail? Photos Taken? Well Pressures (pai): Tubing: O ' Fluid in Cellar? |A: 0 ' BPy/nstaUed? �1 OA: 100 ' VRP|ug(s)Installed? E1 Wellhead Condition All ofthe valves onthe appeared ingood working order with working gauges onthe Tubing, |Aand OA. There are noVR ' Plugs o/8PVinstalled. Condition ofCellar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. Surruunding Surface Condition Everything looked good. | did not see debris or sheen around the pad. Comments | verified the location using the pad map. , Supervisor Comments .' Photos(Z)attached L All, Monday, September 28,2U2O 0)V- an 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: 2 Service Stratigraphic Test 2. Operator Name: 3. Address:7.Date Spudded:15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached:16. W ell Name and Number: Surface: Top of Productive Interval:9. Ref Elevations: KB:17. Field / Pool(s): Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD:19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5.Directional or Inclination Survey: Yes (attached) No 13. W ater Depth, if Offshore:21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 112' 10-3/4"L-80/K-55 2,549' 7-5/8" L-80 4,075' 4-1/2" L-80 4,063' 4-1/2" L-80 4,045' 4-1/2" L-80 4,088' 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 2,319' NSL, 3,521' WEL, SEC. 33, T13N, R10E, UM 2,136' NSL, 4,447' WEL, SEC. 28, T13, R10E, UM 4,538' NSL, 4,284' WEL, SEC. 28, T13N, R10E, UM N/A 35' 2,999' HOLE SIZE If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4,013' 4,052' 7,326' / 4,056' 7,144' / 4,000' TUBING RECORD Uncemented Slotted Liner 9,720' 12,199' AMOUNT PULLED 468 sx AS Lite, 254 sx Class G 4-1/2" SIZE DEPTH SET (MD) 5,456' / 3,468' PACKER SET (MD/TVD) 3800 Centerpoint Dr, Suite 1400, Anchorage Alaska 99503 12.6# 7,187' 7,315' 12.6# 6-3/4" Uncemented Slotted Liner 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, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas Permit to Drill Number / Sundry: 135 / 3 6.Date Comp., Susp., or Aband.: $SULO August 28, 2004 50-029-23218-00-00 September 5, 2004 MILNE PT UNIT I-19 MILNE POINT / SCHRADER BLUFF OIL 69.3' ADL00259066,620' / 3,849' 9,720' / 4,088'551851.0812 6009435.082 GL: 24.8' BF:N/A 6014494.258 SETTING DEPTH TVD -6016926.573 N/A TOP suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A / N/A 1,800' MD / 1,793' 7,192' / 4,015' 6-3/4" 34' 13-1/2" 260 sx Arctic Set (Approx.) 35' 757 sx Class G 42" LinerN/A5,456' BOTTOM 92# 45.5# 112' CEMENTING RECORD 7,428' CASING WT. PER FT.GRADE 550863.9417 551010.7058 TOP SETTING DEPTH MD 34' Gas-Oil Ratio: Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 7,355' 33' 3,468'12.6# 9-7/8" 5,460' 33' Flow Tubing Water-Bbl: PRODUCTION TEST Date of Test: Sr Pet Eng Oil-Bbl: Water-Bbl: Choke Size: Sr Res EngSr Pet Geo Oil-Bbl: Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 10:51 am, May 18, 2020 Suspension Date 4/17/2020 HEW RBDMS HEW 5/21/2020 xG DLB 05/21/2020 DSR-5/21/2020 Suspended SFD 6/10/2020 gls 6/10/20 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 0' 0' 1,800' 1,793' Top of Productive Interval 7,300' 4,048' 5,085' 3,319' 5,650' 3,544' 5,665' 3,550' 5,830' 3,607' MC 6,183' 3,726' NA 6,543' 3,828' 6,680' 3,865' 6,810' 3,897' NE 6,900' 3,920' NF 7,060' 3,973' OA 7,188' 4,014' OB 7,300' 4,048' Schrader Bluff 31.List of Attachments: Operations Summary & Wellbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Chad Helgeson Contact Name: Stan Porhola Operations Manager Contact Email:sporhola@hilcorp.com Authorized Contact Phone:777-8412 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29.GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. NC Formation at total depth: MB1 MB2 NB TUZC MA If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Chad A Helgeson cn=Chad A Helgeson, c=US, o=Hilcorp Alaska, ou=ANS Operations Manager, email=chelgeson@hilcorp.com 2020.05.14 22:13:58 -08'00' _____________________________________________________________________________________ Revised By: TDF 5/12/2020 SCHEMATIC Milne Point Unit Well: MPU I-19 Last Completed: 3/06/2020 PTD: 204-135 “OB”TD =9,720’(MD) / TD =4,088’(TVD) 20” Orig. DF Elev. = 69.10’ / Orig. GL Elev.= 24.80’ 7-5/8”9, 10, 11, 12,13 1 5 8 6,7 5 “OA” Lateral PBTD = 9,720’(MD) / PBTD =4,088’(TVD) “OB” Lateral 10-3/4” 2 3 4 TOC @6,620’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A N/A Surface 112' N/A 10-3/4” Surface 45.5 / L-80 / BTC-M 9.950 Surface 161’ 0.0962 10-3/4” Surface 45.5 / K-55 / BTC-M 9.950 161’ 2,999’ 0.0962 7-5/8" Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,428’ 0.0459 4-1/2” Liner 12.6 / L-80 / IBT 3.958 5,456’ 7,355’ 0.0152 4-1/2” Slotted Liner “OA” 12.6 / L-80 / IBT 3.958 7,187’ 12,199’ 0.0152 4-1/2” Slotted Liner “OB” 12.6 / L-80 / IBT 3.958 7,315’ 9,720’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / EZGO-HT 3.958 Surface 5,460’ 0.0058 JEWELRY DETAIL No Depth Item 1 32.82’ 4-1/2” Tubing Hanger 4-1/2” 2 5,449’ Top of Locator Sub on 10’ Seal Assembly stabbed into ZXP 3 5,456’ HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" : 4 5,476’ Flex Lock LNR Hanger 7-5/8" x 5-1/2" 5 7,144’ HES HRD ZXP Liner Top Packer 6 7,187’ 4-1/2” x 7-5/8”Baker LEM #1 7 7,187’ 4-1/2” Hook hanger inside casing (outside hook point 7,204’) 8 7,263’ 2-7/8” XN Nip, ID= 2.323” 9 7,310’ L-1 Non-Locating Seal Assembly 10 7,315’ Baker Tie Back Sleeve 11 7,326’ Baker ZXP Liner Top Packer 12 7,332’ Baker HMC Liner Hanger 13 7,340’ Baker Sealbore extension OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42” Hole 10-3/4”468 sx of Class Lite and 254 sx Class “G” in 13-1/2” Hole 7” 757 sx Class “G” in 9-7/8” Hole 4-1/2” OA 97 bbl of 15.8 ppg Class G cement; TOC @ 6,620’ MD 4-1/2” OB 35 bbl of 15.8 ppg Class G cement; Est TOC @ 7,380’ MD WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 75 deg. @ 6,450’, 50+ deg. from 2,500’ MD GENERAL WELL INFO API: 50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 - 9/13/2004 ESP RWO by Nabors 4ES – 2/12/2005 ESP RWO and Install LEM by Nabors 3S – 10/17/2008 ESP RWO by Nabors 4ES – 1/10/2010 ESP RWO by Doyon 16 – 2/14/2013 ESP RWO by ASR#1 – 10/8/2017 ESP RWO by ASR#1 – 3/06/2020 COIL TUBING CEMENT PLUGBACK – 4/17/2020 LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 7,192’ to 7,204’ Well Angle @ Window =72 deg. WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 11” 5M Gen. FMC Gen 5, 4-1/2” FMC tubing hanger, 4-1/2” H563 on top & 4-1/2” 4-1/2” H521 bottom, 4” CIW=H BPV Profile MIT tubing and IA to 2000 psi Well Name Rig API Number Well Permit Number Start Date End Date MP I-19 Coil 50-029-23218-00-00 204-135 4/8/2020 4/17/2020 4/10/2020 - Friday M/U BHA #2: 2" CTC, 2.13" CTC, 2" xo, 2.13" DFCV, 2" xo, , 2" Carrier w/ CCL (OAL = 18.71'). Stab on and P/T to 250/ 4,000psi. Open Swab and Master. T/I/O = 0/0/0. RIH to 7,700'. POH while logging at 60 fpm. Stop and paint flag at 7,400'. Continue to POH to 7,000' and stop. POH to surface. Close swab and master valve. Stand back injector. Break and L/D BHA #2. Download Data. Tie in. Flag on coil is at 7,388' after depth correlation. Wait on cementers.SDFN. 4/8/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary CTU #6 14,468' of 2" coil: MIRU on MPI-19. Perform BOP Test to 250psi low and 4,000psi high. Performed full body test. Tested 4-1/16” upper blind shears, lower blind shears, slip rams, and pipe rams. Tested inner real valve and check valve. Drawdown test: start at 2,700psi with final pressure of 1,600psi. Total test time was 2 hours and 5 minutes. 4/9/2020 - Thursday CTU #6: FCO. M/U BHA #1: 2" CTC, 2.13" CTC, 2.13" DFCV, 2" xo, 2 x 2.13" weight bars, 1.98" JSN (OAL = 11.9'). Stab on and P/T to 250/ 4,000psi. Open Swab and Master. T/I/O = 283/0/0. RIH w/ BHA #1 to 7,100'. Begin cleanout by circulating at 2.1 BPM while taking returns to a tiger tank. Cleanout to 9,684' ctmd. Sit down 4k-lbs at 9,684' ctmd and repeat 3 times. PBTD in OB lateral has been reached. POH while chasing a 10 bbl gel sweep from 9,684' (PBTD). At surface, freeze protect tree and tubing to 300'. Close swab valve and master valve. T/I/O = 11/14/14. M/U BHA #3: 2" CTC, 2.13" CTC, 2" xo, 2.13" DFCV, 2" xo, 2 x 2.13" weight bars, 2.2" nozzle (OAL = 11.9'). Stab on and P/T to 250/4000psi. RIH w/ BHA #3. Stop at Flag. Correct depth. EOP at flag is 7,369.1'. Current BHA is 11.9' Adjust depth at flag to 7,381'. Continue to RIH and reach 10,000'. In OA lateral instead of OB Lateral. Make multiple attempts to enter OB Lateral but end up in OA Lateral each time. POH to surface. Change out Packoffs. SDFN. 4/11/2020 - Saturday M/U BHA #5: 2" CTC, 2.13" DBPV, 2.13" TJ Disconnect, 2.87" xo, 2.88" Hipp Tripper, 3.12" xo, 3.5" Hydraulic GS, 3.89" Type 1 Diverter (OAL = 28.95'). RIH and set Type 1 Diverter at 7,196' ctmd. POH to surface. SDFN. 4/14/2020 - Tuesday 4/12/2020 - Sunday M/U BHA #4: 2" CTC, 2.13" CTC, 2" xo, 2.13" DFCV, 2 x 2.13" weight bars, 2 x 2" weight bars, 2" xo, 2.2" nozzle (OAL = 21.4'). Stab on and P/T to 250/ 4,000psi. RIH w/ BHA #3. Stop at Flag. Correct depth. EOP at flag is 7,369.1'. Current BHA is 21.4' Adjust depth at flag to 7,380.5'. Continue to RIH and tag PBTD at 9,679'. R/U and P/T cementers and lines to 250psi low and 4,500psi high. Pump 10 bbls fresh water, 35 bbls of 15.8 ppg class G cement, 5 bbls fresh water, 40 bbls PowerVis. Begin laying in cement from 9,679' ctmd (PBTD) 1:1 after one bbls of cement is out of nozzle. Pull out of cement at 7,380' ctmd. Wait for PowerVis to reach nozzle and begin washing down to 7,300'. Lay in 30 bbls of PowerVis from 7,300' to 5,329'. POH to surface. FP coil with 40 bbls 60/40 MeOH. FP tree. Stand back injector. 4/13/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-19 Coil 50-029-23218-00-00 204-135 4/8/2020 4/17/2020 Hilcorp Alaska, LLC Weekly Operations Summary M/U BHA #6: CTC, xo, DFCV, weight bar, Tempress tool, nozzle. RIH and cleanout OA lateral to 11,750'. Unable to go deeper due to friction. POH to surface. M/U BHA #7: CTC, xo, DFCV, weight bar, 2.13" cement nozzle. Pump 80 bbls diesel down tubing w/ LRS.RIH into OA Lateral to 12,060'. Obtain P/U weight and unable to go deeper than 12,000'. R/U and P/T cementers and lines to 250psi low and 4,500psi high. Pump 10 bbls fresh water, 77 bbls of 15.8 ppg class G cement, 10 bbls fresh water, 30 bbls PowerVis. Begin laying in cement from 12,000' ctmd 1:1 (66.5 fpm) after one bbls of cement is out of nozzle. Pull out of cement at 6,940' ctmd. POH to safety at 6,840' and squeeze 2.5 bbls. Estimated TOC is at 7,104'. Wait for PowerVis to reach nozzle and begin washing down to 7,000'. POH to surface. FP coil with 40 bbls 60/40 MeOH. FP tubing with 42 bbls of 60/40 MeOH. FP tree. Stand back injector. L/D BHA. SDFN. Well Name Rig API Number Well Permit Number Start Date End Date MP I-19 Coil 50-029-23218-00-00 204-135 4/8/2020 4/17/2020 No operations to report. No operations to report. 4/18/2020 - Saturday No operations to report. 4/21/2020 - Tuesday 4/19/2020 - Sunday No operations to report. 4/20/2020 - Monday 4/17/2020 - Friday M/U BHA #8: CTC, xo, DFCV, weight bar, 2.13" cement nozzle. T/I/O = 0/0/1psi.RIH at tag Top of Cement at 6,620' w/ Guy Cook w/ AOGCC as witness. P/T tubing and cement to 2,000psi charted minutes w/ Guy Cook w/ AOGCC as witness. POH to surface. Secure well. Well is freeze protected to 2,800' MD/2,500' TVD. RDMO. 4/15/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIH and tag TOC at 7,200' POH to 7,100' and attempt MIT-T to 2,000psi. Acheive injectivity at 0.9 BPM at 950psi. MIT-T failed. POH to surface. SDFN. 4/16/2020 - Thursday M/U BHA #8: CTC, xo, DFCV, weight bar, 2.13" cement nozzle. RIH and tag TOC at 7,200' ctmd. R/U and P/T cementers and lines to 250psi low and 4,500psi high. Pump 5 bbls fresh water, 20 bbls of 15.8 ppg class G cement, 15 bbls fresh water, 25 bbls PowerVis. Squeeze 10 bbls of cement. Only a 150psi tubing pressure increase over the 10 bbls queezed was seen. POH from 7,200' ctmd while laying in another 10 bbls of cement 1:1 (66.5 fpm) after one bbls of cement is out of nozzle. Pull out of cement at 6,493' ctmd. POH to safety at 6,400'. Estimated TOC is at 6,493'. POH to surface. FP coil with 40 bbls 60/40 MeOH. FP tubing with 42 bbls of 60/40 MeOH. FP tree. Stand back injector. L/D BHA. SDFN. RIH and tag TOC at 7,200' POH to 7,100' and attempt MIT-T to 2,000psi. Acheive injectivity at 0.9 BPM at 950psi. MIT-T g Top of Cement at 6,620' tag cement . Squeeze 10 bbls of cement. Estimated TOC is at 6,493' P/T tubing and cement to 2,000psi charted minutes w/ Guy Cook w/ AOGCC as witness. POH t Test plugs..... 1. 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: Pull ESP & Run Tie-back String 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 9,720 feet N/A feet true vertical 4,088 feet N/A feet Effective Depth measured 9,720 feet feet true vertical 4,088 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / EZGO-HT 5,460' 3,470' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: N/A Collapse 520psi 2,090psi 4,063' 4,088' 2,090psi 4,790psi Burst 1,530psi 3,580psi 3,580psi 6,890psi 7,500psi 20'' 10-3/4" 10-3/4" 7-5/8" N/A N/A 8,430psi 161' 2,549' Intermediate Liner Casing Conductor Slot Liner 'OB'2,405' Length 112' 161' measured 7,428 1,696 2838' Surface Surface N/A 0 Authorized Signature with date: Authorized Name: Stan Porhola sporhola@hilcorp.com Casing Pressure Tubing Pressure 0 777-8412 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-024 00 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-135 50-029-23218-00-00 Plugs ADL0025906 MILNE PT UNIT I-19 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 0 Oil-Bbl measured true vertical Packer 4-1/2" 4-1/2" 7,428' 7,355' WINJ WAG 0 Water-Bbl MD 112' 161' 2,999' 9,720' TVD 112' 5,456, 7,144 & 7,326 3,468, 4,000 & 4,056 HRD-E ZXP, HES HRD ZXP & ZXP Slot Liner 'OA'5,012 4-1/2" 12,199' 4,045' Size 4,075' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson cn=Chad A Helgeson, c=US, o=Hilcorp Alaska LLC, ou=ANS Operations Manager, email=chelgeson@hilcorp.com 2020.04.17 19:28:38 -05'00' By Samantha Carlisle at 10:36 am, Apr 20, 2020 gls 4/28/20 Pull ESP & Run Tie-back String DSR-4/20/2020 RBDMS HEW 4/20/2020 SFD 4/23/2020 _____________________________________________________________________________________ Revised By: STP 3/24/2020 SCHEMATIC Milne Point Unit Well: MPU I-19 Last Completed: 3/06/2020 PTD: 204-135 “OB”TD =9,720’(MD) / TD =4,088’(TVD) 20” Orig. DF Elev. = 69.10’ / Orig. GL Elev.= 24.80’ 7-5/8”9, 10, 11, 12,13 1 5 8 6,7 5 “OA” Lateral PBTD= 9,720’(MD) / PBTD =4,088’(TVD) “OB” Lateral 10-3/4” 2 3 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A N/A Surface 112' N/A 10-3/4” Surface 45.5 / L-80 / BTC-M 9.950 Surface 161’ 0.0962 10-3/4” Surface 45.5 / K-55 / BTC-M 9.950 161’ 2,999’ 0.0962 7-5/8" Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,428’ 0.0459 4-1/2” Liner 12.6 / L-80 / IBT 3.958 5,456’ 7,355’ 0.0152 4-1/2” Slotted Liner “OA” 12.6 / L-80 / IBT 3.958 7,187’ 12,199’ 0.0152 4-1/2” Slotted Liner “OB” 12.6 / L-80 / IBT 3.958 7,315’ 9,720’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / EZGO-HT 3.958 Surface 5,460’ 0.0058 JEWELRY DETAIL No Depth Item 1 32.82’ 4-1/2” Tubing Hanger 4-1/2” 2 5,449’ Top of Locator Sub on 10’ Seal Assembly stabbed into ZXP 3 5,456’ HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" 4 5,476’ Flex Lock LNR Hanger 7-5/8" x 5-1/2" 5 7,144’ HES HRD ZXP Liner Top Packer 6 7,187’ 4-1/2” x 7-5/8”Baker LEM #1 7 7,187’ 4-1/2” Hook hanger inside casing (outside hook point 7,204’) 8 7,263’ 2-7/8” XN Nip, ID= 2.323” 9 7,310’ L-1 Non-Locating Seal Assembly 10 7,315’ Baker Tie Back Sleeve 11 7,326’ Baker ZXP Liner Top Packer 12 7,332’ Baker HMC Liner Hanger 13 7,340’ Baker Sealbore extension OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42” Hole 10-3/4”468 sx of Class Lite and 254 sx Class “G” in 13-1/2” Hole 7” 757 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 75 deg. @ 6,450’, 50+ deg. from 2,500’ MD GENERAL WELL INFO API: 50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 - 9/13/2004 ESP RWO by Nabors 4ES – 2/12/2005 ESP RWO and Install LEM by Nabors 3S – 10/17/2008 ESP RWO by Nabors 4ES – 1/10/2010 ESP RWO by Doyon 16 – 2/14/2013 ESP RWO by ASR#1 – 10/8/2017 ESP RWO by ASR#1 – 3/06/2020 LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 7,192’ to 7,204’ Well Angle @ Window =72 deg. WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 11” 5M Gen. FMC Gen 5, 4-1/2” FMC tubing hanger, 4-1/2” H563 on top & 4-1/2” 4-1/2” H521 bottom, 4” CIW=H BPV Profile MIT-IA to 1500 psi Well Name Rig API Number Well Permit Number Start Date End Date MP I-19 ASR#1 50-029-23218-00-00 204-135 3/2/2020 3/6/2020 Held PJSM and discussed daily activities. Checked fluids and serviced rig. Continued testing BOPE as following: Annular 250- 2,500psi, Rams 250-2,500psi, Valves 250-2,500psi, Gas Detection and Koomey Draw-down. 1 F/P recorded on K-2. Greased and cycled valve-retested good. AOGCC witness waived be Jeff Jones. Blow lines dry and RD Testing Equipment. RU Elephant trunk, sheaves and spooler. Built scaffolding for stairwell so we can get the pipe shed and catwalk closer to the rig. Spotted Pipe Shed and RU handling tools to pull 2-7/8" ESP Completion. Repair Mercer Valve on Accumulator. Pulled BPV and BOLDS PU/MU Landing Jnt, test cable test was good. BO/LD Hanger. O'Malley Cap line Spooler down Could not get running had to take heater from back of the rig to heat spooler and get running. Lay down 9 jnts 2-7/8" EUE 6.5# L-80 TBG/w esp cable, Pull ESP,Heat trace, cap tube over the sheaves and tie into spooling units. Lost another hose on the catwalk. Hoses are not artic grade and all need to be swapped out with artic grade hoses. fixed hose and returned to work. Lay down 38 more jnts of 2- 7/8" EUE 6.5# L-80 TBG Pulling 100% coverage Heat trace clamps and collar clamps . Lost power to the Spooling unit had to trouble shoot and found breaker tripped. Cont. to POOH/LD 2-7/8" EUE 6.5# L-80 TBG Pulling 100% coverage Heat trace clamps and collar clamps. No operations to report. 2/29/2020 - Saturday Held Sundry Meeting with crew. Serviced rig and checked fliuds. Limited ops due to cold weather -42. Continued Winterizing and hooking up hoses while waiting on weather. With assistance from crane Laid out the koomey hose and hooked up. Functioned BOP's. Raised Mast and secured rack pins. Started Hooked up hoses and winterized. Continued RU and perp for BOPE test. Cont. to Hook up hoses and winterized. Continued RU and perp for BOPE test. Set all heaters in place, set Mud pump and hook up lines for NU Flow Spool and 6” flow line. Check hydraulic pressure at the stack to make sure full pressure was getting to stack 6, Make up both 2-7/8” and 4.5” Test Mandrills and get heat on them. -40 degrees most of the night. took some time to get things warm enough to test. Begin BOPE Test 250psi/low 2,500psi/high on all equipment as per sundry. 3/3/2020 - Tuesday 3/1/2020 - Sunday No operations to report. 3/2/2020 - Monday 2/28/2020 - Friday No operations to report. 2/26/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/27/2020 - Thursday No operations to report. y down 9 jnts 2-7/8" EUE 6.5# L-80 TBG/w esp cable, Pull ESP,Heat trace, cap tube over the sheaves and tie into spooling units. tinued testing BOPE as following: Annular 250- 2,500psi, Rams 250-2,500psi, Valves 250-2,500psi, Well Name Rig API Number Well Permit Number Start Date End Date MP I-19 ASR#1 50-029-23218-00-00 204-135 3/2/2020 3/6/2020 No operations to report. No operations to report. 3/7/2020 - Saturday No operations to report. 3/10/2020 - Tuesday 3/8/2020 - Sunday No operations to report. 3/9/2020 - Monday 3/6/2020 - Friday Morning Safety Meeting and crew swaps. SIMOPS continue to make up new hanger delivered by WH team. Make up X-overs on landing joint to new landing sub on new hanger, Land Hanger and RILDS. R/U to pressure test casing and seal bore seal. Pressure up to 1,500psi and chart test on casing and seal bore seals for 30 minutes for good test. Bleed off. Set BPV in well. End of well ops for I-19. Start RDMO ASR. 3/4/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Held PJSM and discussed daily activities. Check fluids and serviced rig. Continued POOH w/ 2-7/8" 6.5 L-80 EUE 8RD tbg and ESP completion. Pumping single displacement every 15 jts. L/D Bottom GLM, RU Mud bucket to pull last 4 jts wet. Had about 2' of scale in the pup jt just above the discharge head. LD ESP assembly. There was a lot of pitting and scale buildup around the seals and motor section. Pump was complete full of scale. All clamps accounted for. RD sheave, elephant trunk and spooler. L/D 2-7/8" Handling Tools PU 4-1/2" Handling tools. Racked and tallies Bullet seal assembly and the first row of 4- 1/2" EZGO Tbg. RIH/w TBG 4-1/2" EZGO 12.6# L-80 with Bullet seal Assembly. Total 128 jts in the hole at report time. 3/5/2020 - Thursday Held PJSM and discussed daily activities. Repaired hydraulic hose on cat walk. Reroute hoses to keep from rubbing against the frame. Had to S/D and prep to swap out catwalk due to hoses damaged beyond repair in the field. Request Roads and Pads assistance to mobilize old Catwalk to location. Crew pulled tubing from Pipe Shed and then move Pipe Shed to get to Catwalk. Swap out Catwalks. Connect hoses, function test on Catwalk. Orientate crew to well plan going forward - Safety meeting and Sundry Discussion. Continue to RIH with completion string. S/D day crew and swap to night crew. Night crew arrived Milne Point 3:30pm. Orientate night crew to current well plan and Sundry discussion. Continue to RIH and tag seal bore @ 20' in on joint 166. P/U and re-tag to verify good tag at same spot on pipe. - Good tag. Prep to circulate. RU to circulate down tubing. Circulate down Source Water at 3 bpm with string immediately above Bore Receptacle to heat up seals and clean any potential debris off of Bore Receptacle. Fluid returns at 25 bbls away. RD circulation equipment. Conduct space-out operation. Tag up to Seal Assembly No-Go two times to determine space-out pups. Crew mobilized crossovers for landing hanger, cannot get crossover to MU into hanger. Realize it is a different thread than communicated. Wellhead team verifies that this hanger won’t work. RU to take returns to flowback tank. Circulate down 90 bbls of Corrosion Inhibitor with rig pump down IA. slight returns during pumping but pressure drop once complete. Follow immediately with 65 bbls of diesel down IA with same pattern of slight returns. Open valve, well on vacuum initially and then static. Bleed off 150 psi from IA through choke. Notified by WH team that they are bringing out replacement hanger. Mobilize hanger to rig floor. Toolpusher looking for pup joint to make up for difference in hanger lengths. Necessary to travel to D pad to look for and find 2.5' pup joint to make up difference in new hanger pup length difference. Continue to RIH and tag seal bore @ 20' in on joint 166. P/U and re-tag to verify good tag at same spot on pipe. - Circulate down 90 bbls of Corrosion Inhibitor with rig pump down IA. slig . RIH/w TBG 4-1/2" EZGO 12.6# L-80 with Bullet seal Assembly. Pump was complete full of scale. All Pressure up to 1,500psi and chart test on casing and seal bore seals for 30 minutes for good test. Bleed off. Set BPV in well. Had about 2' of scale in the pup jt just above the discharge head. LD ESP assembly. MEMORANDUM State of Alaska O.D. Shoe@ Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: April 17, 2020 Intermediate: P.I. Supervisor O.D. Shoe@ Production: SUBJECT: Well Bore Plug & Abandonment O.D. Shoe@ MPU 1-19 - FROM: Guy Cook PTD 2041350; Sundry 320-024 Liner (OB): Petroleum Inspector MPU 1-191-1 Shoe@ Tubing: PTD 2041350; Sundry 320-024 O.D. Tail@ Hilcorp Alaska LLC - Section: 33 Township: 13N Range: 10E Meridian: Umiat " Drilling Rig: n/a Rig Elevation: Total Depth: 12199 ft MD Lease No.: ADL0025517 Operator Rep: Nick Frazier Suspend: X P&A: Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ Surface: 10 3/4" O.D. Shoe@ Intermediate: 7 5/8" O.D. Shoe@ Production: Feet O.D. Shoe@ Liner (OA): 4.5' O.D. Shoe@ Liner (OB): 4.5' O.D. Shoe@ Tubing: 4.5' O.D. Tail@ Plugging Data: Test Data: 112 , Feet 2999 Feet 7428 - Feet Csg Cut@ Feet 12199 Feet 9720 Feet 5460 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bottom 12199 ft MD 6620 ft MD - 15.8 ppg- C.T. Tag 2 20 Initial 15 min 30 min 45 min Result Tubing 2292 2212- 2172 IA 0 0 0 P OA 2 2 20 Remarks: Second plug verification attempt after first attempt had a good tag but failed the pressure test - refer to my report 4/15/2020. Hilcorp squeezed and laid cement on top of the plug at 7200 ft MD. Tagged twice at 6620 ft MD. Put 5000# downforce on the plug with no movement. Performed a MIT -T to 2000 psi with 2.3 bbls of 60/40 methanol pumped and 2 bbls bled back after the test was complete. Good test and tag., Attachments: none I rev. 11-28-18 2020-0417_Plug Verification_MPU_I-19&L1_gc 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Coil Cement Laterals 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,720'N/A Casing Collapse Conductor 520psi Surface 2,090psi Surface 2,090psi Intermediate 4,790psi Liner 7,500psi Slotted Liner 'OA'N/A Slotted Liner 'OB'N/A Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Stan Porhola Operations Manager Contact Email: Contact Phone: 777-8412 Date:3/25/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 12,199'4,045'N/A 3800 Centerpoint Dr, Suite 1400 C.O. 477.05 MILNE PT UNIT I-19 MILNE POINT / SCHRADER BLUFF OIL sporhola@hilcorp.com COMMISSION USE ONLY Authorized Name: N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 5,012'4-1/2" 204-135 Anchorage Alaska 99503 50-029-23218-00-00 Hilcorp Alaska LLC Length Size 4,088'9,720'4,088' 112'112' 12.6# / L-80 / EZGO-HT TVD Burst 5,460' 8,430psi MD 1,530psi 6,890psi 3,580psi 3,580psi 161' 2,549' 4,075' 161' 2,999' 4-1/2" 112'20" 10-3/4" 10-3/4" 161' 7-5/8"7,428' 2,838' Authorized Signature: 3/27/2020 9,720'2,405' 4-1/2" 4,088' Perforation Depth MD (ft): See Schematic 4-1/2" See Schematic 1,041 N/A HRD-E ZXP, HES HRD ZXP & Baker ZXP and N/A 5,456MD/ 3,468TVD, 7,144MD / 4,000TVD & 7,326MD / 4,056TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7,255' 7,428' 211' 4,063' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Chad Helgeson DN: cn=Chad Helgeson, ou=Users Date: 2020.03.25 17:15:10 -05'00' Chad Helgeson By Samantha Carlisle at 12:29 pm, Apr 08, 2020 320-158 Suspend Suspended well inspection required within 1 yr per 20 X 10-407 AAC 25.110(e) DLB 4/8/2020 DSR-4/8/2020gls 4//8/20 Suspended X Notify inspector to witness tag and pressure test of cement plug. Com m. on Required? Yes No 4/8/2020 X dts 4/8/2020 JLC 4/8/2020 Well Prognosis Well: MPU I-19 Date: 3/24/2020 Well Name:MPU I-19 API Number:50-029-23218-00 Current Status:Idle Producer [No Pump]Pad:I-Pad Estimated Start Date:March 27 th , 2020 Rig:Coil Tubing Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-135 First Call Engineer:Stan Porhola (907) 777-8412 (O) (907) 331-8228 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:2050058 Job Type:Cement Laterals Current Bottom Hole Pressure: 1,441 psi @ 4,000’ TVD (SBHPS 12/27/2019 / 6.93 ppg EMW) Maximum Expected BHP:1,441 psi @ 4,000’ TVD (No new perfs being added) MPSP:1,041 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point I-19 well was drilled as a Schrader Bluff development well dual lateral with Doyon 14 in September 2004. The well was initially completed with an ESP. This ESP failed and was replaced in February 2005 (Nabors 4ES). In October 2008 (Nabors 3S), the LEM (Lateral Entry Module) and ZXP liner top packer was installed along with a replacement ESP. In November 2009 (Nabors 4ES), pulled a failed ESP and ran a 4-1/2” completion string into the ZXP liner top packer. A coil tubing cleanout in December 2009 was completed in the OA sand to 10,900’ CTM and in the OB sand to 9,702’ CTM. The 4-1/2” completion string was pulled in January 2010 (Nabors 4ES) and a new ESP was run. This ESP failed and was replaced in February 2013 (Doyon 16). The ESP was pulled in August 2017 and a hole in the casing was found. A tieback tubing string was set, coil cleaned out both laterals in September 2017 and the ASR ran a new tieback with a liner hanger/liner top packer to cover up the casing hole in October 2017 and ran a new ESP. The ESP was pulled and replaced with a 4-1/2” tieback tubing string in March 2020 with the ASR Rig. Notes Regarding Wellbore Condition x There is a leak in the 7-5/8” casing between 5,552’ – 5,592’ MD. A 4-1/2” scab liner was run across this to isolate the leak and corrosion inhibited brine was placed behind the liner. x Casing tested to 1,500 psi down to 5,456’ MD (Liner Top) on 3/06/2020. x Max angle 76.3° @ 6,760’ in the 7-5/8” casing. Max angle 94.9 @ 8,090’ in the laterals. Objective: The purpose of this work is for coil tubing to abandon both horizontal laterals with cement. The planned redevelopment pattern for the I-Pad Schrader reservoir requires this wellbore to be isolated to help prevent potential MBE’s (Matrix Bypass Events). Future Wellbore Utility Options to be Reviewed: 1.) Rotary sidetrack into the Ugnu or Schrader Bluff sands. 2.) Coil tubing sidetrack into the Ugnu or Schrader Bluff sands. 3.) Conversion to a water source well in either the Prince Creek or Ugnu sands. Coil Tubing Procedure: 1. MIRU Coiled Tubing Unit w/ 1.75” or 2.0” coil and spot ancillary equipment. 2. Fill source tank w/ slick source water. The purpose of this work is for coil tubing to abandon both horizontal laterals with cement. Well Prognosis Well: MPU I-19 Date: 3/24/2020 3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. 4. RIH w/ CCL memory logging carrier and 1.75”-2.0” jet-swirl nozzle. 5. Obtain PUW’s while in the OB lateral and dry tag to determine if an FCO is needed. a. Note the PBTD of the OA lateral is 12,200’ MD and the OB lateral is 9,720’ MD to help determine which lateral we are in. b.Contingency: If able to run deeper than 9,720’ MD (inside OA lateral), pull back to LEM an re- attempt to enter the OB lateral. c.Contingency: if a FCO is determine necessary by WSM (contact OE in town): i. Attempt to circulate and gain full returns to surface w/ 1% KCl and gel sweeps. ii. If unable to gain returns, circulate out fill using 1% KCl w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. 6. When POOH, log OOH and pause at 7,400’ MD to paint a flag. Log up to 7,000’ and continue to POOH. 7. MU ball drop cementing nozzle and RIH to TD or deepest depth reached during FCO. 8. Bullhead ±80bbls of diesel down the CTxTbg. This should provide ~30psi positive wellhead pressure after the cementing is completed. 9. Begin to mix cement. Once blend is up 15.8ppg, pump ±40 bbls of cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. If unable to previously get returns, block in IA and monitor for pressure buildup. While laying in cement, returns will be taken to the OA Lateral. 10. Allow ~1bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1 up to 7,350’ MD. a. Pull out of the cement as the last of the cement exits the nozzle. 11. At 7,350’ MD, contaminate cement and attempt to circulate coil tubing clean. POOH. a. Leave a contamination pill around the LEM at 7,187’ MD using +/- 109 bbl of N-Vis. 12. Wait on cement to build compressive strength and PU diverter BHA. 13. RIH and set diverter in LEM at 7,187’ MD. 14. POOH. LD diverter BHA. 15. MU ball drop cementing nozzle and RIH to TD of the OA Lateral or 12,153’ MD. 16. Obtain PUW’s while in the OA lateral and dry tag to determine if an FCO is needed. a.Contingency: if a FCO is determine necessary by WSM (contact OE in town): i. Attempt to circulate and gain full returns to surface w/ 1% KCl and gel sweeps. ii. If unable to gain returns, circulate out fill using 1% KCl w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. 17. Bullhead ±80bbls of diesel down the CTxTbg. This should provide ~100psi positive wellhead pressure after the cementing is completed. 18. Begin to mix cement. Once blend is up 15.8ppg, pump ±85 bbls of cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. If unable to previously get returns, block in IA and monitor for pressure buildup. While laying in cement, returns will be taken to the OA Lateral. 19. Allow ~1bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1 up to 7,200’ MD. a. Pull out of the cement as the last of the cement exits the nozzle. 20. PU to safety and attempt to squeeze away ±5bbls of cement. Do not exceed 500 psi above circulating pressure. No AOGCC notification required. OA plug e PBTD of the OA lateral is 12,200’ MD and the OB lateral is 9,720’ MD to help determine pump ±40 bbls of cement d set LEM diverter OB plug Well Prognosis Well: MPU I-19 Date: 3/24/2020 21. Swap to contaminate and RIH to cleanout to 7,160’ MD. a. Use +/- 109 bbl of N-Vis for contamination. 22. POOH and circulate coil tubing clean as needed. a. Freeze protect well on way out of hole. 23. Wait on cement to gain 1,000psi compressive strength. 24. RIH w/ nozzle BHA and tag top of cement at estimated +/- 7,160’ MD. 25. Pressure test casing to 1,500psi for 30 min charted. 26. Contingency: If failed pressure test of the casing and cement plug. a. Re-squeeze cement down into liner as needed. 27. POOH. LD nozzle BHA. 28. RD CT unit. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen & Foam Flow Diagram Tag TOC and pressure test tag top of cement at estimated +/- 7,160’ MD. Notify Inspector 2000 psi _____________________________________________________________________________________ Revised By: STP 3/24/2020 SCHEMATIC Milne Point Unit Well: MPU I-19 Last Completed: 3/06/2020 PTD: 204-135 “OB”TD =9,720’(MD) / TD =4,088’(TVD) 20” Orig. DF Elev. = 69.10’ / Orig. GL Elev.= 24.80’ 7-5/8”9, 10, 11, 12,13 1 5 8 6,7 5 “OA” Lateral PBTD= 9,720’(MD) / PBTD =4,088’(TVD) “OB” Lateral 10-3/4” 2 3 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A N/A Surface 112' N/A 10-3/4” Surface 45.5 / L-80 / BTC-M 9.950 Surface 161’ 0.0962 10-3/4” Surface 45.5 / K-55 / BTC-M 9.950 161’ 2,999’ 0.0962 7-5/8" Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,428’ 0.0459 4-1/2” Liner 12.6 / L-80 / IBT 3.958 5,456’ 7,355’ 0.0152 4-1/2” Slotted Liner “OA” 12.6 / L-80 / IBT 3.958 7,187’ 12,199’ 0.0152 4-1/2” Slotted Liner “OB” 12.6 / L-80 / IBT 3.958 7,315’ 9,720’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / EZGO-HT 3.958 Surface 5,460’ 0.0058 JEWELRY DETAIL No Depth Item 1 32.82’ 4-1/2” Tubing Hanger 4-1/2” 2 5,449’ Top of Locator Sub on 10’ Seal Assembly stabbed into ZXP 3 5,456’ HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" 4 5,476’ Flex Lock LNR Hanger 7-5/8" x 5-1/2" 5 7,144’ HES HRD ZXP Liner Top Packer 6 7,187’ 4-1/2” x 7-5/8”Baker LEM #1 7 7,187’ 4-1/2” Hook hanger inside casing (outside hook point 7,204’) 8 7,263’ 2-7/8” XN Nip, ID= 2.323” 9 7,310’ L-1 Non-Locating Seal Assembly 10 7,315’ Baker Tie Back Sleeve 11 7,326’ Baker ZXP Liner Top Packer 12 7,332’ Baker HMC Liner Hanger 13 7,340’ Baker Sealbore extension OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42” Hole 10-3/4”468 sx of Class Lite and 254 sx Class “G” in 13-1/2” Hole 7” 757 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 75 deg. @ 6,450’, 50+ deg. from 2,500’ MD GENERAL WELL INFO API: 50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 - 9/13/2004 ESP RWO by Nabors 4ES – 2/12/2005 ESP RWO and Install LEM by Nabors 3S – 10/17/2008 ESP RWO by Nabors 4ES – 1/10/2010 ESP RWO by Doyon 16 – 2/14/2013 ESP RWO by ASR#1 – 10/8/2017 ESP RWO by ASR#1 – 3/06/2020 LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 7,192’ to 7,204’ Well Angle @ Window =72 deg. WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 11” 5M Gen. FMC Gen 5, 4-1/2” FMC tubing hanger, 4-1/2” H563 on top & 4-1/2” 4-1/2” H521 bottom, 4” CIW=H BPV Profile _____________________________________________________________________________________ Revised By: STP 3/24/2020 PROPOSED Milne Point Unit Well: MPU I-19 Last Completed: 3/06/2020 PTD: 204-135 “OB”TD =9,720’(MD) / TD =4,088’(TVD) 20” Orig. DF Elev. = 69.10’ / Orig. GL Elev.= 24.80’ 7-5/8”9, 10, 11, 12,13 1 5 8 6,7 5 “OA” Lateral PBTD =9,720’(MD) / PBTD =4,088’(TVD) “OB” Lateral 10-3/4” 2 3 4 TOC @±7,160’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / N/A N/A Surface 112' N/A 10-3/4” Surface 45.5 / L-80 / BTC-M 9.950 Surface 161’ 0.0962 10-3/4” Surface 45.5 / K-55 / BTC-M 9.950 161’ 2,999’ 0.0962 7-5/8" Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,428’ 0.0459 4-1/2” Liner 12.6 / L-80 / IBT 3.958 5,456’ 7,355’ 0.0152 4-1/2” Slotted Liner “OA” 12.6 / L-80 / IBT 3.958 7,187’ 12,199’ 0.0152 4-1/2” Slotted Liner “OB” 12.6 / L-80 / IBT 3.958 7,315’ 9,720’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / EZGO-HT 3.958 Surface 5,460’ 0.0058 JEWELRY DETAIL No Depth Item 1 32.82’ 4-1/2” Tubing Hanger 4-1/2” 2 5,449’ Top of Locator Sub on 10’ Seal Assembly stabbed into ZXP 3 5,456’ HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" 4 5,476’ Flex Lock LNR Hanger 7-5/8" x 5-1/2" 5 7,144’ HES HRD ZXP Liner Top Packer 6 7,187’ 4-1/2” x 7-5/8”Baker LEM #1 7 7,187’ 4-1/2” Hook hanger inside casing (outside hook point 7,204’) 8 7,263’ 2-7/8” XN Nip, ID= 2.323” 9 7,310’ L-1 Non-Locating Seal Assembly 10 7,315’ Baker Tie Back Sleeve 11 7,326’ Baker ZXP Liner Top Packer 12 7,332’ Baker HMC Liner Hanger 13 7,340’ Baker Sealbore extension OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx) in 42” Hole 10-3/4”468 sx of Class Lite and 254 sx Class “G” in 13-1/2” Hole 7” 757 sx Class “G” in 9-7/8” Hole 4-1/2” OA +/- 90 bbl of 15.8 ppg Class G cement; Est TOC @ 7,160’ MD 4-1/2” OB +/- 40 bbl of 15.8 ppg Class G cement; Est TOC @ 7,350’ MD WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 75 deg. @ 6,450’, 50+ deg. from 2,500’ MD GENERAL WELL INFO API: 50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 - 9/13/2004 ESP RWO by Nabors 4ES – 2/12/2005 ESP RWO and Install LEM by Nabors 3S – 10/17/2008 ESP RWO by Nabors 4ES – 1/10/2010 ESP RWO by Doyon 16 – 2/14/2013 ESP RWO by ASR#1 – 10/8/2017 ESP RWO by ASR#1 – 3/06/2020 LATERAL WINDOW DETAIL Window in 7-5/8” Casing @ 7,192’ to 7,204’ Well Angle @ Window =72 deg. WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 11” 5M Gen. FMC Gen 5, 4-1/2” FMC tubing hanger, 4-1/2” H563 on top & 4-1/2” 4-1/2” H521 bottom, 4” CIW=H BPV Profile tag and press test 1500 psi MILNE POINT UNIT MPU I-19 3/24/2020 COIL BOPE Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic MPU I-19 20 X 10¾ X 7 з X 4 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2.00" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Coil Tubing UnitFluid Flow DiagramCleanout w/ Nitrogen & FoamUpdated 9/22/16LEGEND:Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveCheck Valve Manual ChokePressure Gauge500 BBL KILL TANKChoke ManifoldP400 BBL UPRIGHTPOpenVBRBLINDCOIL PUMP400 BBL UPRIGHTOpenClosedOpenOpenOpenOpenOpenOpenOpenPSW or KCLW/FOAMERORFRIC TIONREDUCER50 BBL FREEZEPROTECT TANKSW or KCLW/FOAMERORFRIC TIONREDUCERTo FlowlineNITROGEN PUMP & TANKPCOIL UNIT WITH 1.5” to 2.0” COIL400 BBL UPRIGHTSEAWATERW/DEFOAMERTRIPLEX THE STATE °ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-19 Permit to Drill Number: 204-135 Sundry Number: 320-024 Dear Mr. Helgeson: Alaska (til and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l as k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, DATED this �"ay of January, 2020. gB®MS ej lA!i 7 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n nnrt �'s pan RECEIVED JAN 17 20210 LA0 62 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q . Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run Tie -back String ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • Stratigraphic Service El 204-135 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23218-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT 1-19 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT/ SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,720' 4,088' 9,720' 4,088' • 1,041 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,530psi 520psi Surface 161' 10-3/4" 161' 161' 3,580psi 2,090psi Surface 2,838' 10-3/4" 2,999' 2,549' 3,580psi 2,090psi Intermediate 7,428' 7-5/8" 17,428' 4,075' 6,890psi 4,790ps! Liner 211' 4-1/2" 17,255' 4,063' 8,430psi 7,500P si Slotted Liner'OA' 5,012' 4-1/2" 1 12,199' 4,045' N/A N/A Slotted Liner'OB' 2,405' 4-1/2" 19,720' 14,088' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5# / L-80 / FILE 8rd 5,404' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HRD-E ZXP, HES HRD ZXP & Baker ZXP and N/A 5,456MD/ 3,468TVD, 7,144MD / 4,000TVD & 7,326MD / 4,056TVD and N/A 12. Attachments: Proposal Summary .i Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development [Z Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/1/2020 Commencing Operations: OIL ❑ WINJ F]WDSPL ❑ Suspended ❑ GAS p WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. S� Authorized Name: Chad HelgesonContact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: S Orhola hilCor .Cam Contact Phone: 777-8412 Authorized Signature: Date: 1/9/2020 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance p Other: '�— 2-.560 / j �StJF' RBDMS�'�JAN 2 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Ex ception Required? Yes No Subsequent Form Required: u APPROVED BY r/]1 Approved 1 1 by: COMMISSIONER THE COMMISSION Dao '�Z"'-� u itForm and Form 10-4 3 .vise 017 A roved a application is valid for 12 months from the date of a _ Duplicate PP �P c I(?i2�217 //=!/ZaJOrORIGINAL ,.L,- U MI..a Alaska, LLi Well Prognosis Well: MPU 1-19 Date: 2/0912020 Well Name: MPU 1-19 API Number: 50-029-23218-00 Current Status: Operable Producer [ESP] Pad: ]-Pad Estimated Start Date: February 1s1, 2020 Rig: ASR 1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-135 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFENumber: 2050058 Job Type- Pull ESP/Run Tbg Current Bottom Hole Pressure: 1,441 psi @ 4,000' TVD (SBHPS 12/27/2019 / 6.93 ppg EMW) Maximum Expected BHP: 1,441 psi @ 4,000' TVD (No new perfs being added) MPSP: 1,041 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point 1-19 well was drilled as a Schrader Bluff development well dual lateral with Doyon 14 in September 2004. The well was initially completed with an ESP. This ESP failed and was replaced in February 2005 (Nabors 4ES). In October 2008 (Nabors 3S), the LEM (Lateral Entry Module) and ZXP liner top packer was installed along with a replacement ESP. In November 2009 (Nabors 4ES), a failed ESP was pulled and a 4-1/2" completion string was ran into the ZXP liner top packer. A coil tubing cleanout in December 2009 was completed in the OA sand to 10,900' CTM and in the OB sand to 9,702' CTM. The 4-1/2" completion string was pulled in January 2010 (Nabors 4ES) and an ESP was ran. This ESP failed and was replaced in February 2013 (Doyon 16). The ESP was pulled in August 2017 and a hole in the casing was found. A tieback tubing string was set, coil cleaned out both laterals in September 2017 and the ASR ran a tieback w/ a liner hanger/liner top packer to cover up the casing hole in October 2017 and ran a new ESP. Notes Regarding Wellbore Condition • There is a leak in the 7-5/8" casing between 5,552'— 5,592' MD. A 4-1/2" scab liner was run across this to isolate the leak and corrosion inhibited brine was placed behind the liner. • Casing tested to 1,500 psi down to 5,452' MD (Liner Top) on 10/9/2017. • Max angle 76.3° @ 6,760' in the 7-5/8" casing. Max angle 94.9 @ 8,090' in the laterals. • Deviation at ESP is 67.0" and dogleg of 0.52°/100 ft. • Min ID is 2.205" thru XN profile above ESP. Objective: The purpose of this work is to pull the ESP with the ASR rig and run a tieback tubing string. i Future work will involve a separate sundry for coil tubing to abandon both horizontal laterals with cement. - The planned redevelopment pattern for the I -Pad Schrader reservoir requires this wellbore to be isolated to help prevent potential MBE's. Pre -Rig Procedure: 1. MIRU Slickline unit. a. Pull orifice valve from STA #2 @ 160' and set DV. Well Prognosis Well: MPU 1-19 I lcoru Alnske, LG Date: 1/09/2020 b. Pull DV from STA #1 @ 5,238' MD. Leave pocket open. c. RD Slickline Unit. 2. RU LRS and PT lines to 3,000 psi. 3. Pump 1 IA volume (265 bbls) with 8.3 ppg source -water down IA. 4. Clear and level pad area in front of well. Spot rig mats and containment. 5. RD well house and flowlines. Clear and level area around well. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Due to the low reservoir pressure, a tubing freeze protect should not be needed but this can be confirmed with a FL shot. This is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services. B. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 1� p 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.3 ppg source -water prior to pulling BPV. 12. Set BPV Plug (converting BPV to TWC). 13. Test BOPE to 250 psi Low/ 2.500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve pn and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR #1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. Well Prognosis Well: MPU 1-19 Hikorp Alaska, LIJ Date: 1/09/2020 15. Bleed any pressure off casing to returns tank. Pull BPV plug and BPV. Kill well w/ 8.3 ppg source -water as needed. 16. Rig up spoolers for ESP #2 RD cable, heat trace and 3/8" capillary string. a. Baker Hughes representative should be onsite for ESP pull. b. There is 3,500' of heat trace installed, send this for scrap once recovered. 17. RU spoolers and MU landing joint or spear and PU on the tubing hanger. a. The PU/SO weights during the 2017 ASR ESP RWO were 28k/20k. 18. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (ortest plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 19. POOH and lay down the 2-7/8" tubing. Lay down ESP. a. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over -torqued connections from previous tubing runs. c. The well completion currently has: i. 3,500' of heat trace ii. 5,392' of ESP cable iii. 5,402' of 3/8" SS Cap String iv. 6 Cannon Clamps V. 3 Protectorlizers vi. 2 Flat Guards vii. 4 Pump Clamps 20. RIH w/ 4-1/2" kill string w/ EZGO-HT thread and no-go in ZXP tie -back sealbore at±5,456' MD. a. Run 5-1/2" non -ported seal assembly w/ XOs and handling pup back to 4-1/2" EZGO-HT. ��)v 5)21. Tag no-go, PU above sealbore to be able to circulate. vJ �� 22. Pump corrosion inhibited brine (±90bbls 1% KCI + CI) and freeze protect fluid down the IA (±55bbls freeze protect) to 2,100' MD. 23. Tag no-go, PU 2'-3' and space out to land. a. Seal assembly is 10' long w/ 3 set of bullet seals. b. ZXP tieback sealbore is 11.18' long w/ 5.75" ID. 24. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off) weights on tally. 25. Bleed tubing to 0 psi. 26. Pressure test IA to 1,500 psi for 30 min and chart., 27. Freeze protect tubing (Tbg ±32bbls freeze protect) for upcoming coil tubing operations. 28. Lay down landing joint. Set BPV. Post -Rig Procedure: 29. Begin RD of ASR. RD BOPE house. 30. RU crane. ND BOPE. 31. NU used 4-1/8" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 32. RD crane. Move to next well location. Move 500 bbl returns tank and rig mats to next well location. U IHl.u, Alaska, LL, 33. Pull BPV. 34. RD crane. Move returns tank and rig mats to next well location. 35. Replace casing gauge(s) if removed. 36. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO Sundry Change Form Well Prognosis Well: MPU 1-19 Date: 1/09/2020 K Hilcorp Alaska, LLC Orig. DF Elev. = 69.10' / Orig. GL Elev. 24.84 SCHEMATIC "OB" TD=9,72d (NU) / TD=4,098' (TVD) PBTD =9,724 (MID) / PB1D=4,088'0VD) Milne Point Unit Well: MPU 1-19 Last Completed: 10/8/2017 PTD: 204-135 WELLHEAD Tree 2-9/16"—SM FMC 10-3/4" 11" x 11" 5M Gen. FMC Gen 5, 2/2-7/8" Wellhead FMCtubing 2-7/8" EU 8rd on top & 7" bottom, 2.5" CIW=H BPV Profile OPEN HOLE/ CEMENT DETAIL 20" 1 260 sx of Arcticset (Approx) in 42" Hole 10-3/4" 468 sx of Class Lite and 254 sx Class "G" in Btm 13-1/2" Hole 7" 1 757 sx Class "G" in 9-7/8" Hole CASING DETAIL re Wt/Grade/Conn ID Top Btm BPF rotor 92/H-40/N/A N/A Surface 112' N/A ace 45.5/L-80/BTC-M 9.950 Surface 161' 0.0962 ace 45.5 / K-55 / BTC -M 9.950 161' 5,476' Flex Lock LNR Hanger 7-5/8" x 5-1/2" adiate 29.7 / L-80 / BTC -M 6.875 Surfacear 7,187' 4-1/2" Hook hanger inside casing (outside hook point 7,204') 7,263' 12.6 / L-80 / IBT 3.958 5,456' j2,999'EO.O459 Baker Tie Back Sleeve ier"OA" 12.6/L-80/IBT 3.958 7,187' 7,340' Baker Sealbore extension ier"OB" 12.6/L-80/IBT 3.958 7,315' TUBING DETAIL ng 6.5#/L-80/EUE8rd 1 2.441 1 Surface 5,404' 0.0058 WELL INCLINATION DETAIL KOP @ 300' MD -Max-Hole Angle = 75 deg. @ 6,459, 50+ deg. from 2,500' MD JEWELRY DETAIL Depth Item 160' GLM ST 2: Camco 2-7/8"X 1"w/ DGLV —Set 01/04/2020 5,238' GLM ST 1: Camco 2-7/8" x 1"w/ ***EMPTY*** —Set 1/04/2020 5,317' 2-7/8" HES XN Nip, MIN ID= 2.205" 5,358.9' Discharge Head: FPDIS 5,359.4' Pump: 141P6 PMSXD 5,375' Gas Separator: GRS FER N AR 5,379' Tandem Seal Sections: GSB3DBUT SB/SB PFSA 5,392' Motor: CL5 —XP 100 HP, 1,820 volt, 34 amp 5,401' Sensor: Welll-ift E w/6 fin centralizer—Bottom @ 5,404' 5,456' HRD-E ZXPN LNR Top PKR 7-5/8"x5-1/2" 5,476' Flex Lock LNR Hanger 7-5/8" x 5-1/2" 7,144' HES HRD ZXP Liner Top Packer 7,187 4-1/2" x 7-5/8"Baker LEM #1 7,187' 4-1/2" Hook hanger inside casing (outside hook point 7,204') 7,263' 2-7/8" XN Nip, ID= 2.323" 7,310' L-1 Non -Locating Seal Assembly 7,315' Baker Tie Back Sleeve 7,326' Baker ZXP Liner Top Packer 7,332' Baker HMC Liner Hanger 7,340' Baker Sealbore extension LATERAL WINDOW DETAIL Window in 7-5/8" Casing @ 7, .12'to 7,204' Well Angle@Window=72 deg. GENERAL WELL INFO ESP RWO by P ESP RWO and ESP RWO by Nabors 4ES —1/10/2010 ESP RWO by Doyon 16 — 2/14/2013 ESP RWO by ASR#1 — 10/8/2017 Revised By: 1CM 1/04/2020 0 I loom Alaska. LLC Orig. DF Elev. = 69.101 / Orig. GL Elev. 24.80' PROPOSED "OB" TD=9,720' (MID) /TD=4,088' (TVD) P3TD=9,7201 (MD) / PBTD=4,088'(TVD) Milne Point Unit Well: MPU 1-19 Last Completed: 10/8/2017 PTD: 204-135 WELLHEAD Tree2-9/16"—SM FMC 10-3/4" 11" x 11" SM Gen. FMC Gen 5, 2/2-7/8" Wellhead FMC tubing 2-7/8" EU 8rd on top& 7" bottom, 2.5" CIW=H BPV Profile OPEN HOLE/ CEMENT DETAIL 2 OW' I 260 sx of Arcticset (Approx) in 42" Hole 10-3/4" 468 sx of Class Ute and 254 sx Class "G" in Btm 13-1/2" Hole 7" 1 757 sx Class "G" in 9-7/8" Hole CASING DETAIL ie Wt/Grade/Conn ID Top Btm BPF ctor 92/H-40/N/A N/A Surface 112' N/A me 45.5/L-80/BTC-M 9.950 Surface 161' 0.0962 ice 45.5/K-55/BTC-M 9.950 161' 2,999' 0.0962 �diate 29.7/L-80/BTC-M 6.875 Surface 7,428' 0.0459 !r 12.6 / L-80 / IBT 3.958 5,456' 7,355' 0.0152 er "OA" E2.6 / L-80 / IBT 3.958 7,187' 12,199' 0.0152 ger"OB" 12.6/L-80/IBT 3.958 7,315' 9,720' 0.0152 TUBING DETAIL Ig 12.64/L-80/ EZGO-HT 1 3.958 1 Surface 1 5,456' 1 0.0152 WELL INCLINATION DETAIL KOP @ 300' MD Max Hole Angle= 75 deg. @ 6,450', 50+ deg. from 2,500' MD JEWELRY DETAIL Depth Item 5,456' HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" 5,476' Flex Lock LNR Hanger 7-5/8" x 5-1/2" 7,144' HES HRD ZXP Liner Top Packer 7,187' 4-1/2" x 7-5/8"Baker LEM #1 7,187' 4-1/2" Hook hanger inside casing (outside hook point 7,204') 7,263' 2-7/8"XN Nip, ID=2.323" 7,310' L-1 Non -Locating Seal Assembly 7,315' Baker Tie Back Sleeve 7,326' Baker ZXP Liner Top Packer 7,332' Baker HMC Liner Hanger 7,340' Baker Sealbore extension LATERAL WINDOW DETAIL Window in 7-5/8" Casing @ 7,192'to 7,204' Well Angle @ Window=72 deg. GENERAL WELL INFO Drilled and Completed by Doyon 14 -9/13/2004 ESP mo by Nabors 4ES — 2/12/2005 ESP RWO and Install LEM by Nabors 3S-10/17/)nM 4E5 Revised By: TDF 1/7/2020 H 11" BOPE Milne Point ASR Rig 1 BOPE 2020 Updated 1/09/2020 i-7/8" x 5" VBR lind res U Le i w m O v d 3 d L cc 0 a Q. El Z -o d m CL d CL L C d y y d ❑ � C U m c O Qy QQa 'a N d jp = ac Qm d N L W a � Y >, Q m d c s U d v La .4: R Q d N IL CL cc 0 a Q. El Z -o d m CL d CL L Ln M r -I 1 O N cn 0 Li- z Z m Y w c a a W v O J VUf a` F > Z s C 0 U a � J LV J Z J Y � f0 CL L- 0 0 V r' Barrels of Oil per Month or Barrels of Water per Month 0 O O O O O O O O O O O O O O O O O o O O O O N ~ O O O O O N O O O O N .o+ o1jeu 110 -seg Jo gluoW aad („��W„) seg;o;aaj 3Ign:) puesnoyl 0 C O N 0 N C OF ALASKA E ' ALI.OIL AND G STCONSERVATION COMOSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS OCT 2 7 2017 1.Operations Abandon U Plug Perforations U Fracture Stimulate ✓ LJ Pull Tubing U A s shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Cl CTU FCO w/N2 0 Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ESP Change-out CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 204-135 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-23218-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT 1-19 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: Total Depth measured 9,720 feet Plugs measured N/A feet true vertical 4,088 feet Junk measured N/A feet 5,456,7,144& Effective Depth measured 9,720 feet Packer measured 7,326 feet 3,468,4,000& true vertical 4,088 feet true vertical 4,056 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,530psi 520psi Surface 161' 10-3/4" 161' 161' 3,580psi 2,090psi Surface 2,838' 10-3/4" 2,999' 2,549' 3,580psi 2,090psi Intermediate 7,428' 7-5/8" 7,428' 4,075' 6,890psi 4,790psi Liner 1,696' 4-1/2" 7,355' 4,063' 8,430psi 7,500psi Slot Liner'OA' 5,012' 4-1/2" 12,199' 4,045' N/A N/A Slot Liner'OB' 2,405' 4-1/2" 9,720' 4,088' N/A N/A Perforation depth Measured depth See Schematic feet SCANNED ,if- ....j16 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 5,404' 3,448' HRD-E ZXP,HES Packers and SSSV(type,measured and true vertical depth) HRD ZXP&ZXP N/A See Above 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: 0 0 0 970 0 Subsequent to operation: 172 15 174 240 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas Li WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-364 Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: Sporhola@hllcorp.com Authorized Signatur ��_Z "c `� Dab 10/26/2017 Contact Phone: 777 8412 Form 10 cviccd 1/2017 ,�,�/ Submit Original Only ,."/,47� "le— RBD? S L�P' ?'i' - 22017 • • Milne Point Unit Well: MPU 1-19 SCHEMATIC Last Completed: 10/8/2017 Hikura Alaska.1.i.c PTD: 204-135 WELLHEAD Tree 2-9/16"-5M FMC 11"x 11"5M Gen.FMC Gen 5,2/2-7/8" Orig.DF Elev.=69.10'/Orig.GL Elev.=24.80' Wellhead FMC tubing 2-7/8"EU 8rd on top& € , bottom,2.5"CIW=H BPV Profile 20,Al1 OPEN HOLE/CEMENT DETAIL I" 20" 260 sx of Arcticset(Approx)in 42"Hole 1 468 sx of Class Lite and 254 sx Class"G"in 10-3/4" 13-1/2"Hole 7" 757 sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40/N/A N/A Surface 112' N/A 10-3/4" Surface 45.5/L-80/BTC-M 9.950 Surface 161' 0.0962 10-3/4" Surface 45.5/K-55/BTC-M 9.950 161' 2,999' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 7,428' 0.0459 103/4"I , 4-1/2" Liner 12.6/L-80/IBT 3.958 5,456' 7,355' 0.0152 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 7,187' 12,199' 0.0152 C.entilrft heat trace I ?.. 4-1/2" Slotted Liner"OB" 12.6/L-80/IBT 3.958 7,315' 9,720' 0.0152 to 3500 TUBING DETAIL 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2.441 Surface 5,404' 0.0058 WELL INCLINATION DETAIL NinID=2.205" 2 KOP@300'MD @5,317 Max Hole Angle=75 deg.@ 6,450',50+deg.from 2,500'MD 93 4 JEWELRY DETAIL 5 No Depth Item • 1 160' GLM ST 2:Camco 2-7/8"x 1"w/DOSV-Set 10/9/2017 Ili 6 2 5,238' GLM ST 1:Camco 2-7/8"x 1"w/Dummy GLM-Set 10/9/2017 3 5,317' 2-7/8"HES XN Nip,MIN ID=2.205" 7 4 5,358.9' Discharge Head:FPDIS wir 3/8"SSCapstring 5 5,359.4 Pump:141P6 PMSXD Check Valve 8 6 5,375' Gas Separator:GRS FER N AR 1,620psi 7 5,379' Tandem Seal Sections:GSB3DBUT SB/SB PFSA r ..,-(0` iv` 8 5,392' Motor:CL5-XP 100 HP,1,820 volt,34 amp !1l f 9 0L" 47 ` 9 5,401' Sensor:WellLift E w/6 fin centralizer-Bottom @ 5,404' 5,456' HRD-E ZXPN LNR Top PKR 7-5/8"x 5-1/2" j+>, �, 10 11 5,476' Flex Lock LNR Hanger 7-5/8"x 5-1/2" ( 111 12 7,144' HES HRD ZXP Liner Top Packer n�// 13 7,187' 4-1/2"x 7-5/8"Baker LEM#1 Rv'Ys"' ^ 14 7,187' 4-1/r Hook hanger inside casing(outside hook point 7,204') IV �,'t S0 15 7,263' 2-7/8"XN Nip,ID=2.323" �J 16 7,310' L-1 Non-Locating Seal Assembly 4 I4 4 /?a 17 7,315' Baker Tie Back Sleeve S`7 18 7,326' Baker ZXP Liner Top Packer r 19 7,332' Baker HMC Liner Hanger d�at°e 12 20 7,340' Baker Sealbore extension I LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 7,192'to 7,204' Well Angle @ Window=72 deg. GENERAL WELL INFO r13,14 API:50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 -9/13/2004 CW Lateral ESPRWObyNabors4ES-2/12/2005 15= «-- q ESP RWO and Install LEM by Nabors 35-10/17/2008 "..at.>. 14617,18,1920 ESP RWO by Nabors 4ES-1/10/2010 ESP RWO by Doyon 16-2/14/2013 A ESP RWO by ASR#1-10/8/2017 '.OB.Lateral MI "OB"TD=9,720'(MD)/TD=4,088'(TVD) PBTD=9,720'(MD)/PBTD=4,088'(TVD) Revised By:TDF 10/26/2017 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-19 ASR#1 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: 8/16/2017 -Wednesday No activity to report. 8/17/2017 -Thursday No activity to report. 8/18/2017 - Friday No activity to report. 8/19/2017 -Saturday No activity to report. 8/20/2017 -Sunday Well Support Installed BPV in Hanger,Well head rep John Morrow Bleed off hanger void, IWS Crew Nipple down Production Tree, Check hanger Threads 2-7/8" EUE 8.5 Turns, Check LDS,Roads and Pad Crane operator Assisted in Hoisting and Nipple up 11' Bop Stack, Hauled and in spotted Company man Trailer, Change House , spotted Mud Boat and well Hut over well. 8/21/2017 - Monday R/U on well 1-19. Spot mud pits and TP trailer into place, roads and pads crane operator on location to pick well house and spot rig floor into position. ASRC Crane operator Hoist Rig Floor in to place, Spot ASR Rig on Mud Boat and spot over well, Hilcorp Electrician Brandon Naylor on Location Connecting Fire and gas Alarms in Pits, Cellar, Rig Floor Raise and Pin Top Section of Derrick, Finish Torquing up BOP Bolts on all Flanges,Rig up all Hydraulic lines from Accumulator to Bop Stack, Fill pits with 200 bbl. Sea water, Rig up all Service Lines, Function Test BOP Rams and Valves, Spot Spooling unit into Place Grease all Choke Valves and Manual Valves on Mud Cross, FMC Well head Rep Deno Tee bar Remove BPV and Installed TWC Valve in Hanger Profile, Nipple up spacer Spools top Annular Rig up Test Equipment Test bop as per sundry,Test with 2-7/8" and 4-1/2" Test Joints all Rams and Valves 250 low/2,500 high 5 min each,Test Annular with 2-7/8" test joint I-BOP and TIW Valves 250 low/2,500 high 5 Min Each, Record Accumulator Pre-Charge Pressures and Chart Test, (AOGCC Jeff Jones Waived Bop Test on 8-20-17 at 5:51am) FMC Well head rep Tee Bar remove TWC Valve from Hanger Profile Pick up Landing Joint make up in Hanger, BOLDS, Pull hanger to the Rig floor Max Pull=51k Free Pull=47k. 8/22/2017 -Tuesday POOH w/ Baker Centrilift ESP on 2-7/8" 6.5ppf, L-80, EUE TBG f/—6,600'md to surface. 2,954'md of heat trace cable recovered. 5 collar clamps missing off of last 5 joints of TBG. 207 total jnts recovered. L/D ESP as per Baker Centrilift hand. All collar clams accounted for except 1 which is caught in wellhead. Making plan to fish collar. Rig Service Check Fluids Grease Change over Handling Equipment Tools F/2-7/8" to 3-1/2" Clear and Clean Rig, Well Support spot Flow Back Tank and Hammer up Hard Line Unload Hoist and make up BHA on Rig Floor TIH w/ Polish Mill Assembly on 3-1/2" Work String with ASR Rig 1' RKB of 17.2 Tagged ZXP Liner Top Packer at 14' in Joint 178 @ 7,146.61'.Swallowed 8' into ZXP Packer to 7,154.61'. (Did not see any Obstructions, our take any weight loss).Tooh w/ Polish Mill Assembly on 3-1/2" Work String f/ 7,154' to 5,750'md • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-19 ASR#1 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Op' rations.i 8/23/2017-Wednesday Continue to POOH w/ Baker polished mill assembly w/magnet and strin mill on 3.5" NC-31 workstringf15,750' and to surface. L/D BHA, clean and clear rig floor.VMS out to location to inspect loader. Wrap leak area and drive loader back to VMS to be repaired. Load and tally 4.5" 12.6ppf L-80 IBT velocity string. Verify strap on Baker completions Bullet Seal Locating Seal Assembly. Swap over pipe handling equipment to 4.5" from 3.5". RIH w/ Baker completions Bullet Seal Locating Seal Assembly on 4.5" 12.6ppf L-80 IBT velocity string f/surface to 3,175' Service Rig Check Fluids and Grease RIH w/ Baker completions Bullet Seal Locating Seal Assembly on 4.5" 12.6ppf L-80 IBT velocity string f/3,175'to 7,152' Load and Tally 4-1/2" IBT Tubing. (Well Support Tee Bar Installed BPV Valve in Hanger Profile,ASRC Crane Support IWS Crew N/D Production Tree Well Head Rep Greg Ruge Check Hanger Threads and Travel on LDS N/U Bop Stack on 1-15). Spaced well out Pick up Make up Hanger, RIH Land Hanger RILDS, LRS, pump 8 bbl Diesel Fill hole with 10 bbl sea water Rig up on IA Valve Pressure test Casing f/7,144' to Surface Increased Pressure to 1,050psi Lost 200psi Pressure, Check Rig Equipment For Leaks none was Found, Pumping 2.5 BPM at a Steady 1,050psi for 5 Min Stopped Pumping Called Engineer Decision was made to pull Hanger and lay down Pick up joint 169 RIH Stack out on the no-go Seal Assembly Stacked out on No-go on Seal Assembly Fill Back Side Closed Annular Pressured up on IA to 1,200psi Pumping a Steady 2.5 BPM for 5 min. Stopped Pumping Slow Bleed off, Call Engineer Decision was made to Pull out of the hole lay down 4-1/2"Tubing and Seal Assembly, Run a RTTS Test Packer and Test Casing. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-19 ASR#1 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: 8/24/2017 -Thursday L/D pup joints, and landing joint from completion. Meet w/crew and discuss plan forward, emphasize the need for steady work speed, and not to feel pressure as our well scenario changes. L/D Baker Bullet Seal Assembly and 4.5" 12.6ppf, L-80, IBT velocity string f/7,144' and to surface. Inspect seal assembly for damage. Nothing definitive with regards to the annulus pressure test failure route. Halliburton completion tools on location w/ RTTS tool. Load RTTS onto catwalk. Load and tally 3.5" 9.5ppf NC-31 work string. P/U RTTS running tool and function as per Halliburton tool hand.Verify tool is in running position and has proper function. RIH w/ Halliburton RTTS running tool on 3.5" 9.5ppf, NC-31 work string f/surface to 1,800' Service Rig Check Fluids and Grease RIH w/ Halliburton RTTS Test Packer on 3-1/2" 9.5#work string f/ 1,800'to 7,010' . Driller Saw Drag on Joint 159 with a 10k weight Loss, set PKR at 7,110' C/O/E, P/U/W=63K D/N/W=23K 22 bbl Fill Hole Close Pipe Rams OApsi=110 Set RTTS PKRTest casing f/7,110' to Surface,22bb1 Fill Hole, Pressured up to 800psi with a Steady Injection Rate of 2BPM for 3 Charted min, Engineer was called Decision was made to trip out of the hole lay down 200' at Time and Retest Casing, OApsi=110 Trip out of the hole lay down five Joints, Set RTTS PKR at 6,910' C/O/E Test Casing f/6,910'to Surface, 22bb1 Fill Hole, Closed Pipe Rams, Pressured up to 900psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams, OApsi =110 Trip out of the hole lay down five Joints,Set RTTS PKR at 6,710' C/O/E Test Casing f/6,710'to Surface, 22bb1 Fill Hole, Closed Pipe Rams, Pressured up to 800psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams, OApsi =110 Trip out of the hole lay down five Joints, Set RTTS PKR at 6,510' C/O/E Test Casing f/6,510'to Surface, 22bb1 Fill Hole, Closed Pipe Rams, Pressured up to 1,000psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams, OApsi =110(IWS Crew Performed Taking a Kick While Tripping Drill 62' Sec)Trip out of the hole lay down five Joints, Set RTTS PKR at 6,310' C/O/E Test Casing f/6,310'to Surface, 22bb1 Fill Hole, Closed Pipe Rams, Pressured up to 900psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams, OApsi=110 Trip out of the hole lay down five Joints, Set RTTS PKR at 6,110' C/O/E Test Casing f/6,110' to Surface, 22bb1 Fill Hole,Closed Pipe Rams, Pressured up to 900psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams, OApsi=110 Trip out of the hole lay down five Joints, Set RTTS PKR at 5,910' C/O/E Test Casing f/5,910'to Surface, 22bb1 Fill Hole, Closed Pipe Rams, Pressured up to 900psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams, OApsi =110. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP1-19 ASR#1 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: 8/25/2017- Friday Trip out of hole, L/D five Joints, Set RTTS PKR at 5,710' C/O/E Test Casing f/5,710'to Surface. Fill Hole, Close Pipe Rams, Pressure up to 900psi with a Steady Injection Rate of 2 BPM for 2 Charted Min Bleed off Pressure Open Pipe Rams. Discuss possible leak zone issues from past wells w/well pad foreman. Decision made to POOH to 3,000' and and test the CSG. Progressively test the CSG cutting each failed test interval in half until closing in on leak. Pressure up IA to 1,750psi @ 3,000' md, IA pressure holding solid. Bleed off pressure, release RTTS, and RIH on 3.5" 9.5ppf NC-13 work string.Split CSG interval f/5,710' and to 3,000' and in half and test @ 4,350' md. RTTS tool stacking weight @ 4,000' md. Work through trouble spot, until just below trouble zone, set RTTS and test CSG to 1,750psi. IA pressure holding solid. Bleed off pressure, release RTTS, and RIH on 3.5" 9.5ppf NC-13 work string. Having trouble w/the RTTS tool setting when moving pipe down hole. Assumption made that the drag block on the RTTS was no turning properly when releasing, which leaves the tool in the run position. Most likely debris caught between RTTS and CSG. Rotate assembly to the left 1 turn to force the RTTS running tool into run position. Split CSG interval f/4,000' and to 5,710' and in half and test @ 4,850' md. RTTS tool still sticking while trying to RIH. Rotate assembly to the left one turn to force RTTS into run position. Decision made to test CSG at this point,4,560' md. Pressure up IA to 1,750psi @ 4,560' md, IA pressure holding solid. Bleed off pressure, release RTTS, and RIH on 3.5" 9.5ppf NC-13 work string. Bullhead 15bbls down the IA @ 3BPM while working the drill string to clear debris. RTTS functioning properly again. Split CSG interval f/4,560' and to 5,710' and in half and test @ 5,110' md. Pressure up IA to 1,750psi @ 5110' md, IA pressure holding solid. Bleed off pressure, release RTTS, and RIH on 3.5" 9.5ppf NC-13 work string. Continue to hunt for leak splitting the difference between where we tested and where the test failed. Narrow leak zone to 40' interval between 5,552' and and 5,592' md. Chart 30min MIT 7-5/8" CSG to 1 750psi @ 5,552' md.Speak w/engineer about plan forward. POOH w/ RTTS running tool and prep to RIH w/ polished mill/ magnet/string mill, clean out assembly. POOH w/ RTTS running tool on 3.5" 9.5ppf NC-31 work string f/5,552' md.to 3,227' Service Rig Check Fluids and Grease POOH w/ RTTS running tool on 3-1/2" work string f/3,227' to Surface, Lay down 7-5/8" RTTS Packer Assembly Pick and Make up Polishing Mill, Magnet, and String Mill Assembly on 3-1/2" Work String TIH f/Surface to 7,149'Swivel up on Joint 178 Tag top of ZXP Liner Top at 7,149.5' set down on the No-go @ 7,157.5' P/U/W=65K D/N/W=24K. Pick up 2' Rotate work string w/ RPM=40 Polish 4-1/2" (f/7,149'to 7,157.5' .) Made 5 passes Pick up out of liner top POOH w/ Polishing Mill Assembly on 3-1/2" work string f/7,149' to 5,600' . • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-19 ASR#1 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: 8/26/2017-Saturday Continue to POOH w/ Baker Completions, Polishing Mill/Magnet/String Mill, BHA f/—5,600' and to 3,200' md. Sleeve that contains hydraulic loop in rig mast tearing do to wear. Shut down and change out sleeve so that hydraulic lines stay together while traveling within the rig mast. Continue to POOH w/ Baker Completions, Polishing Mill/Magnet/String Mill, BHA f/'"3,200' and to surface. L/D Baker Completions, Polishing Mill/Magnet/String Mill, BHA. Magnet covered in metal shavings, but no additional large pieces of metal. Upper and lower polished mills show signs of wear. SLB E-line crew on location. R/U sheaves off of the catwalk and from the bales on the rig carriage. M/U BHA and test all electrical connections. Not getting connectivity through one of the roller assemblies. Found bent spring in the connection. Change out spring, M/U to BHA, test (GOOD TEST). PJSM w/SLB and ASR crew discussing operations, well control plans, communication routes, etc. RIH w/SLB E-line 40 arm caliper as per SLB rep. Issue getting BHA past'3,600' md. Fill hole to create larger hydrostatic pressure on the bottom hole, creating faster fluid loss.Able to push past 3,600' and with BHA. Continue to RIH w/SLB E-line while pumping fluids down hole to push BHA. Not able to get past 6,100' and w/caliper BHA. Hole deviation changes from 70-76deg deviation in this area. Decision made to caliper from 6,100' and to surface. SLB E-line perform caliper log @ 30' /min from 6,100' md. to Surface Rig down Schlumberger E-line Tools and Equipment RIH w/ Baker completions Bullet Seal, Locating Seal Assembly on 4.5" 12.6ppf L-80 IBT velocity string f/surface to 7,100' . S • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-19 ASR#1 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations. 8/27/2017 -Sunday Continue to RIH w/ Baker bullet seal bore assembly on 4.5" IBT TBG. See initial weight bobble mid way through joint 169. No go w/5K, 8' from the top of JNT 169 (7,159' MD ORKB). Pull out of seal bore receptacle watching for any weight changes (none). Sting back in w/seal bore assembly and no go in the same spot. P/U to neutral weight and calculate space out for landing. L/D JNT 169 and P/U 9.75' and pup w/ hanger and pup jnt. Land completion at 7,138.44' and w/11' seal assembly in receptacle. Greg Ruge on location to RILDS. SLB E-line on location to prep for R/U. R/U SLB E-line in prep for running Halliburton Evo-Trieve RBP. Halliburton S/L rep Ty Burley on location to run RBP. R/U sheaves, M/U pump in sub and pack-off to the top of the landing joint. M/U SLB BHA and attach Halliburton Evo-Trieve plug and DPU. Calculate time needed to set RBP in place and set timer on the DPU to set and release RBP. RIH w/ Halliburton Evo-Trieve RBP on SLB E- line BHA f/surface to 7,160' md. Fight to get Evo-Trieve to bottom. Perform CCL log on up pass and attempt to correlate. Continue to correlate until content with the gamma markers. Pick RKB set depth in the middle of 10' pup below ZXP PKR @ 7,170' md. Pull Evo-Trieve into position and wait for timer to activate DPU. Waiting on DPU timer to set Evo-Trieve. See CCL movement giving indication of DPU activating. Evo-Trieve plug set at 7170' and center of elements. P/U 50' and from plug set depth and then RIH and tag up on RBP. Evo-Trieve tagged up on depth @ 7,170' and center of elements. POOH w/SLB E- line BHA f/7,170' and to surface. L/D SLB BHA and Halliburton DPU, all indications Evo-Trieve plug released as planned. R/U to pump down TBG and test Evo-Trieve plug and seal bore assembly. Pumping down TBG but having a hard time catching pressure. Fill IA and pump down TBG to see if we are able to get any fluid movement in the IA via the TBG. Service Rig Check Fluids and Grease Make up landing Joint into Hanger BOLDS, Pull Hanger to the rig Floor, Made up 10' Pup Joint, Land Hanger RILDS, P/U/W=75K D/N/W=25K R/U to pump down Tubing and Test Evo-Trieve plug and seal bore assembly to 1,750psi 5min Charted , unable to get a test, Pump and Test IA 750-1,000psi at 2.5 Bpm Charted for 5 min, with the Tubing showingpsi-0, Pumped 74 bbl down the tubing 2.5 Bpm atpsi=0-350psi Charted 5 min with the IA showing no signs of Communication,Turn of Mud Pump Tubing is on a Vacuum, Sent test charts to Engineer, IWS Crew Clean and Maintenance Rig. 8/28/2017- Monday Greg Ruge on location to set BPV in TBG hanger. R/D and M/O well 1-19. R/D fluid and hydraulic lines, move TP trailer so roads and pads can finish prepping location f/ I-15, move pipe racks, catwalk, R/D rig floor and lower mast back onto rig carrier. Release rig. 8/29/2017-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number _ Well Permit Number Start Date End Date MP 1-19 SLB CTU#14 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations 1 ', '' l 9/13/2017-Wednesday No activity to report. 9/14/2017 -Thursday No activity to report. 9/15/2017 - Friday No activity to report. 9/16/2017-Saturday No activity to report. 9/17/2017-Sunday No activity to report. 9/18/2017 - Monday SLB CTU crew on site. PJSM. MIRU on MPI-19. Perform BOPE test. Haul off returns from MPI-15 to B-50. Reload uprights. No Night CT activity. Continue hauling returns to B-50. 9/19/2017-Tuesday SLB CT crew, HAL N2 crew, on site. PJSM. HAL N2 MIRU . CTU made up BHA#1 yesterday after BOP test. BHA= 2" OD int dimple CTC, 2.13" OD DBPV, 2 x Wt Bars,TJ disconnect(5/8" ball),2" OD Rupture disc sub (6k), 2.13" OD Tempress screen, Tempress, XO, 1.75" OD JSN. OAL= 17.5'. Stab on well. NU BOPE. Fluid pack out to tanks. PT low 425psi/4,140psi high. Good test. Bleed down to 500psi. Decision made to not run diverter first for chance there could difficulty setting it due to existing solids not cleaned out yet. Will try to determine what lateral we enter on initial cleanout today and run either the diverter or Isolation sleeve as needed on next run. Open well to 105psi SITP. IAP=0, OAP = 0. RIH with cleanout BHA. Start pumping N2 and SLK 1%at 4,400' ctmd - N2 rate at 800 scf/m/fluid rate at 1.7 bpm. CTP= 3300psi. Started getting full returns back with N2 at 7000' ctmd. WHP at 260psi with 2" choke FO. Started cleanout at 7,150' ctmd. Clean out 300' intervals followed by 50' short trips. Pump 30 bbls SLK 1%followed by 5 bbls gel and repeat. Gel treated with .6% NXS lube. One upright of fluid is SLK 1%, 2nd upright is same but treated with .6% NXS lube. Fluid rate kept at 1.7 bpm/N2 rate at 800 scf/m/CTP at 3,150psi/WHP- 190 to 280psi. Start stacking weight with coil at 8000' and deeper. RIH Weight dropped off from 2,000lbs to <800lbs. 1st lockup with coil at 8615'. PUH 300'. RBIH and reach 8,688' before lockup. Reduce N2 rate to 500 scf/m. PU 150' and RBIH. Able to reach 8810' before lockup. Continue process and able to cleanout to final depth of 9,410' ctmd. Lost returns momentarily for—15 minutes but throughout operation maintained 93% returns. POOH chasing returns. Make U/D pass across LEM to clean profile for setting diverter.SD pumping fluid at 5,000'.SD N2 at 2,700'. Displace N2 from coil with SLK 1%. SD after pumping coil volume (57 bbls), coil was 200' from surface.Tag up at surface. Close swab, BD and pop off well. PU 2 more sticks of lubricator. MU BHA#2 -2" OD int dimple CTC, 2.13" OD DBPV,TJ disconnect (5/8" ball), 2.87" OD XO, 2.88" OD SIDI Hipp Tripper, 3.12" OD XO, 3.5" OD "4" GS,Type 1-3.68" OD Diverter. OAL= 28.95'. On well. PT low 265psi/3,509psi. Open well and RIH with BHA#2.T/1/0 = 206/0/0 Set down with diverter at 5,009' ctmd. PU heavy. PUH till clean weight. Pump tubing volume of SLK 1%and RBIH. Set down at 7182' ctmd. PU and hiptripp diverter down into profile. Pump off to release from diverter. POOH. FP well with diesel while POOH.At surface, close SV, BD and pop off well. Diverter left in hole. L/D tools. MU cleanout BHA. Secure well. SDFN • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-19 CTU 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: 9/20/2017-Wednesday CTU and N2 crews on site. PJSM. MU BHA#1-2" OD int dimple CTC, 2.13" OD DBPV, 2 x Wt Bars,TJ disconnect (5/8" ball),2" OD Rupture disc sub (6k), 2.13" OD Tempress screen,Tempress, XO, 1.75" OD JSN. OAL= 17.5' Stab on well. Fluid pack out to tanks. PT low 425psi/4,140psi high. Good test. Bleed down toLK Open well and RIH with cleanout BHA. T/I/O = 90/0/0. Online with N2 at 800 scf/m at 3,650' ctmd. Online with SLK 1%at 3,9100'. CTP stabilized at—3,200psi. Returns to surface with N2 with coil at 6,800' ctmd. WHP at 220-300psi with FO 2" choke. Enter OA lateral via diverter with no problem. Clean out from 7,150'to 11,189' ctmd. Cleaned out taking 300' bites pumping 30 bbls SLK 1%with NXS lube and 5 bbls gel sweeps down to 10,450'. Started losing pipe wt, stopped taking short trips, increase N2 rate to 1000 scf/m, and ran in at 20 fpm until Lockup at 11,189'. Pumped final 10 bbl gel sweep off bottom. Getting 1:1 returns POOH chasing returns pumping 1.7 bpm/ 1000 scf/m N2. SD pumping fluid at 4,400'. SD N2 at 2,460'. Displace N2 from coil with SLK 1% L. Tag up at surface. Close swab, BD and pop off well. L/D cleanout BHA. MU BHA#3 for fishing diverter- 2" OD int dimple CTC, 2.13" OD DBPV,Jars,Ti disconnect(5/8" ball), 3.10" OD XO, 3.5" OD 4" GS. OAL= 11.55'. Diverter length = 18.6'.Total length with diverter= 30.15'. Lubricator length = 30 ft. PT tools to 4,000psi. On Well. PT low and high-270/3,700psi Open well (180psi WHP). RIH with 4" GS. Wt ck at 7,100' = 17k. RBIH and set down and latch diverter at 7,163'. PU with slight overpull (17.5k). Set backdown, set diverter, PU and see more definitive overpull (21k). POOH. Pump 38 bbls diesel down backside to FP well.Tag up at surface. Close swab, BD and pop off well. Diverter recovered. L/D all tools. RDMO. Secure well.Job Complete. Final T/I/O = 94/0/0 9/21/2017 -Thursday No activity to report. 9/22/2017- Friday No activity to report. 9/23/2017-Saturday No activity to report. 9/24/2017-Sunday No activity to report. 9/25/2017- Monday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name _ Rig API Number Well Permit Number Start Date End Date MP1-19 C 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: 10/4/2017 -Wednesday No activity to report. 10/5/2017 Thursday No activity to report. 10/6/2017- Friday, A514- Service Rig Check Fluids and Grease Raise Derrick, and Pin Top Section, Spot Pit Module, Cat Walk, Pipe Racks, Rig up Hydraulic Accumulators Hoses to Bop Stack, Rig Up Service Lines, Rap with Glycol Lines and Wrap Start Certex Unit, Electrician Hooked up and Calibrated Fire and Gas Alarms in pits Rig Floor and Cellar, N/D Bop Stack & N/U Tree on 1-15 Test Hanger Void 5,000psi,ASRC Crane Remove well House f/ I-15, Fill Pill pit with 40 bbl. Fresh Water Well Head Rep Tee Bar Removed BPV Pumped 10 bbl. down Tubing Installed TWC Valve in Hanger Profile Conduct Spill Drill with Rig Crew Tool Pusher Pad Operator, Milne point Security Was Called No Answer Left Message, Crew Response to Drill (2.45sec) Went over things we as a Crew can Get better at Responding to Spill R/U Shell 250/2,500psi (Good Test)Test bop as per sundry, Test with 2-7/8" and 4-1/2" Test Joints all Rams and Valves 250 low/2,5001-110 5 min each 1est.Annular with 2-7/8" test joint I-BOP and TIW Valves 250 low/2,500 high 5 Min Each, Record Accumulator Pre-Charge Pressures and Chart Test, (AOGCC Jim Regg Waived Witness Test on 10-6-17 at 9:06am) M/U Landing joint into hanger BOLDS Pull hanger to Rig Floor unseat at 65k Max pull =88k Free PuIl=79 Service rig, as per maintenance log. Pump 30bbls at 4BPM w/ no returns. L/D 4.5" 12.6ppf, range 3, IBT TBG f/7144'md to surface. Well control drill, kick while tripping. Well secured in 1.5min.AAR after drill w/crew. Fill hole w/double metal displacement every 15jnts. Once at surface pump 20bbls of 8.4ppg fluid down hole at 4BPM w/no returns. Close blinds and monitor well. Change out pipe handling equipment f/4.5" to 3.5". Load and strap 3.5" NC-31, range 3 work string. Baker fishing hand Aaron Brown on location to load and strap BHA. 10/7/2017-Saturday Service Rig Check Fluids and Grease ASRC VMS Mechanic trouble shoot Main Generator on Tool Pusher Shack, VMS Mechanic Said fuel Pump Failed, Portable Gen Set was brought out, Load and Tally 192 joints 3.5" 9.3#ppf Work string on pipe racks, Driller Then pumped 25 bbl. Open blind Rams, Ran BHA in the hole Made up 7-5/8" Casing Scraper, Magnet BHA Trip in the Hole w/3.5" 9.3#ppf. Work String F/Surface 7,131.5' (ASR DPM)Tagged 27' in on Jt. =178 set 4K Down P/UW=64K D/N/W=21KPulled up Broke off joint 178 set on pipe Ramp Pumped 25 bbl. down IA' Made up Joint 178 RIH Retag same spot set 5k down Pooh lay down 3.5 9.3#ppf Work String and 7.625 Casing Scraper& Magnet BHA f/7,131.5' to 1,488' (Rig Crew Conducted Kick While Tripping Drill 108 sec Well Secure all Crew Members in Place) Rig crew perform preventative maintenance checks. Grease equipment,verify fluid levels. POOH w/Baker fishing 7-5/8" CSG scraper/Magnet/Mule Shoe BHA on 3.5" NC-31 work string f/ 1,488'md to surface. L/D BHA, close blind rams and monitor well via choke manifold IA sensor. R/U and M/U polished mill w/magnet, cleanout BHA as per Baker fishing rep. Fill the hole w/ 10bbls of fluid, open blind rams. Power went out on tool push trailer when pump#2 kicked in on accumulator. Manually lock blind rams on BOP stack and bleed off accumulator. Remove drive belt and attempt to rotate accumulator pump and drive motor. Both functioning smooth. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP1-19 CTU 50-029-23218-0000 204-135 8/20/17 10/10/17 Dailybperations: I. 10/8/2017-Sunday Service Rig Check Fluids and Grease Swap out 40kw generator from Dog House/Company Rep shack w/30kw. Filled Hole with 29 bbl. (Confirm No Flow to Pits) Open Blind Rams TIH w/ BHA No 2' Polishing Mill w/ Upper Dress off Mill & Magnet Ran on 3-1/2" 9.3# ppf Work String f/Surface Tagged up on Jt. 178 (ASR DPM) @ 7,131.5' R/U Circulating Hose on Swivel Set Swivel Torque at 5,000'/lbs. with a Free Rotating wt. of 39k Free Torque 2,600'/lbs. Pumping D/N Tubing at 2bpm, Stacked out on the No-Go at 7,131.5' Work and Rotate Dressed of Liner Top WOB=2K at 30/40 Rpm P/U/W=65K D/N/W=22K Tooh w/ BHA No 2' Polishing Mill w/ Upper Dress off Mill & Magnet Ran on 3-1/2" 9.3# ppf Work String f/ 7,131.5' to Surface (Pumping Double Pipe Displacement) Break and Lay down BHA No 2' Polishing Mill Upper Dress off Mill & Magnet, Change over Handling Equipment to 4-1/2" Load Bullet Seal Locating Seal Assembly and 39 jts of 4-1/2" IBT L-80 Tubing on Pipe Racks Perform rig service. Check fluid levels and grease equipment. P/U Baker Completions Bullet Locating Seal Assembly and M/U to joint of 4.5" 12.6ppf IBT TBG. RIH w/39jnts of 4.5" 12.5ppf L-80 IBT TBG f/surface to 1,650'md. 1r P/U Baker Completions ZXP LNR Top PKR w/ Flex Lock LNR HGR and M/U to 4.5" 12.5ppf L-80 IBT TBG. Baker Completions rep on location to perform equipment verification. RIH w/ Baker Completions ZXP LNR Top PKR w/ Flex Lock LNR HGR f/ 1,650'md to"7,130'md. Perform simulated kick while tripping drill on rig floor w/ hands when LNR HGR is across the BOPE and the TIW crossover is being changed from 4.5" IBT to 2-7/8" IF. Perform AAR on drill. 10/9/2017- Monday Spill on Suction Hose all Hands Responded at 400 bbl. up Right Tank Disconnect Suction and Replace with newer Hose Flagged off area of spill Milne point Security Was Called Pad Operator Enviro Rob and Safety Thad Responded to area of spill, Service Rig Check Fluids and Grease R/U Circulating Hose, on Jt. 135 Mix and Pump 1 Drum of Corrosion Inhibitor in pits, Pump Total 30bbl. of Inhibitor, D/N Tubing Take Returns to Pits, Not to Exceed 600psi on Tubing & Liner Packer,, Displaced with 140 bbl. 8.4 ppg w/2% KCL, 80 bbl. Returns to Flow Back Tank P/U RIH Tagged up on it. (136) 27'in set D/N 10k P/U to Neutral weight Drop Ball, Fill back side with Total 13 bbl. R/U LRS P/T Lines to 5,000psi, Pump ball on seat at 30 bbl. Pressure up to 1,974psi Actuate Pusher Tool Set PKR Continue Pressure up to 2,900psi Hold for 5 min Bleed down to 1,000psi, Fill back side Close Pipe Rams Pressure up to 1,500psi 30 Charted Min Test Casing f/5,452'to Surface (Good Test) Bleed Pressure off, R/U on Tubing Pressure up f/1,000psi to 4,000psi Put PKR in Neutral and Blew ball Set, HRD-E ZXPN LNR Top PKR 7-5/8" x 5-1/2" Set @ 5,452' (ASR RKB DPM) Pooh lay down 136 Joints 3-1/2 9.3#ppf and Liner hanger setting Tool Change over Handling Equipment from 3-1/2"to 2-7/8" Load and Tally 2-7/8" 6.5# L-80 Tubing while Making up ESP Pump Assembly Rig service, check fluids and lubricate equipment Continued P/U and Servicing ESP completion as per Baker Centrilift Rep. Crew member noticed leak coming from hydraulic fluid filter located in side pack of rig carrier. Shut down rig, remove filter, replace leaking o-ring, assemble filter and circulate hydraulics to verify no further issues. (Good Fix) Continued M/U ESP completion as per Baker Centrilift Rep. RIH w/ ESP completion w/3/8" cap string on 2-7/8" 6.5ppf L-80 EUE TBG.At GLM #1, unable to identify if the GLM has a dummy valve or an orifice valve. Not labeled on GLM. Call well support to verify. Well support unable to pull valve from pocket. Decision to get new GLM w/dummy and replace current GLM. RIH w/ ESP completion w/3/8" cap string on 2-7/8" 6.5ppf L-80 EUE TBG to JNT 62, ("2,000'md). Pull heat trace line over sheave and M/U to 2-7/8"TBG. Continue to RIH f/"2,000'md to 3,500'. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP1-19 CTU 50-029-23218-0000 204-135 8/20/17 10/10/17 Daily Operations: .� � 4�� 10/10/2017-Tuesday Service Rig Check Fluids and Grease, Fill Well Bore when come on Tour with Total of 94 bbl. RIH w/ New ESP Completion 3/8" cap string on 2-7/8" 6.5ppf L-80 EUE Tubing and Heat Trace Cable f/2,000'to 3,500' Rig Crew Perform Tripping Drill (100 sec) Continued RIH w/ New ESP Completion w/3/8" cap string on 2-7/8" 6.5ppf L-80 EUE Tubing and Heat Trace cable f/3,500'to 5,195' md.Verify ESP cable and heat trace conductivity every 1,000'md as well as cap string injection test. Fill IA w/5bbls every half hour. Run out of heat trace clamps, new crate was not the right size.Take bed truck to A pad and retrieve proper clamps to finish the run. Centrilift day shift hand out on location to support night shift in prep for cable and heat trace splice. Continue to RIH w/ ESP completion w/3/8" cap string on 2-7/8" 6.5ppf L-80 EUE TBG w/ heat trace, as per Centrilift rep and completion tally f/5,195'md to 5,375'md. P/U and M/U 2-7/8"TBG hanger. Well head rep Greg Ruge on location to M/U TBG hanger and set penetrators in position. 171 total joints of 2-7/8" EUE, 38 cross collar clamps, 2 hard bands, 543 trace clamps, 70 dual collar clamps, 3 protectrolizers, 2 flat guard clamps, and 4 pump clamps. Centrilift reps on location to perform ESP and Heat Trace splices.ASR crew begin R/D process. NES trucking on location to support rig move. Land TBG hanger on depth.Verify depth w/5' stick and do a visual verification through the IA. Back out landing joint, RILDS . Close blind rams. Rig crew blow down lines. Wellhead hand Greg Ruge T-bar in BPV. (Well released from 1-19 on 10/11/17 @ 3:30am) Begin R/D move off process. Start shuffling equipment f/ I pad to A pad. • Schwartz, Guy L (DOA) From: Quick, Michael J (DOA) Sent: Friday,August 25,2017 2:15 PM To: Stan Porhola Cc: Schwartz, Guy L(DOA) Subject: Re: Change of Approved Procedure - MPU I-19 (PTD 204-135 Sundry 317-364) Stan You have approval to continue operations per the procedure outlined in the email below. Mike On Aug 25, 2017,at 1:58 PM,Stan Porhola<sporhola@hilcorp.com>wrote: Guy, During step#24 of the approved sundry for MPU 1-19,the pressure test failed. Per the contingency listed on the sundry,we have been running a 7-5/8" RTTS looking for the leak.We have identified that the leak is below 5,150' MD(continuing to test the casing below this point currently). Our proposed change of approved procedure is as follows: 1.) *NEW STEP* Make a polished mill run to polish out the sealbore below the existing ZXP packer below 7,144' MD to clear the sealbore of any debris. 2.) *NEW STEP* RU E-line and make a 40-arm caliper run of the 7-5/8"casing from the ZXP at 7,144' MD to surface. Evaluate the condition of the casing for straddle option. 3.) *NEW STEP* RIH w/a 4-1/2" retrievable tubing plug and set in the 4-1/2" liner below the ZXP Packer but above the laterals. 4.) *NEW STEP* PU the same seal assembly as per Step#20 of the original sundry and RIH on 4- 1/2"tubing. 5.) *NEW STEP* Stab in the seals, land the hanger and pressure test the tubing string down to the tubing plug to 1,750 psi. 6.) RD the ASR rig per the sundry. 7.) Continue with the sundry from Step#25 and perform the coil tubing work from Step#33 to Step #43. 8.) RD the Coil Unit per the sundry. 9.) RU the ASR rig per the sundry. 10.)Continue with the sundry rig work from Step#44 to Step#61. 11.)*NEW STEP* Straddle the leaking 7-5/8"casing. Run a new ZXP packer w/4-1/2"tubing and seals and stab into the existing 7-5/8"ZXP packer at 7,144' MD.The top of the new ZXP would be at 5,150' MD(or deeper). 12.)*NEW STEP* Pressure test the new ZXP packer and casing to 1,750 psi. 13.)*NEW STEP* POOH. LD setting tool. 14.)*NEW STEP* Run a new ESP per Step#62 with a new set depth of 5,150' MD (or deeper). Regards, 1 • Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 ��,.tea Tele: 907 777-8337 Nilrirp:ILu.ka_LIR, ' * -ire+ D Fax: 907 777-8510 DATA LOGGED E-mail: doudean@hilcorp.com a1/29/2011 9 2017 Jl. K BENDER DATE 09/19/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPI-19 SCANNED SEP 2 52D17 Prints: CCL CALIPER-40 MFC CD's HILCORP_MPI-19_CALIPER 26AUG17_FINAL 9/8/2017124 PM File folder .2--.9g G O HILCORP_MPI-19_PLUG_27AUG17_FINAL 9/8/2017 108 PM File folder 2-6 C010 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 8 Date: • OF 7' S g,\"\ 1 yy�s� THE STATE Alaska Oil and Gas , --y✓d��-�'�,hi"' 7' � ALAS 1 Conservation CommissionCommission J� itt i 333 West Seventh Avenue " � 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4'ALAS" Fax: 907.276.7542 www.aogcc.alaska.gov Bo York �E� AUGNIL�� Operations Manager s � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-19 Permit to Drill Number: 204-135 Sundry Number: 317-364 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Commissioner DATED this Ray of August, 2017. RBDMS Lj`- AUG 1 1 2017 l' ECEIVEC STATE OF ALASKA AUG 0 ALASKA OIL AND GAS CONSERVATION COMMISSION 0 c'$ IgTc /, 7 APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 2Cn r^AT," -44 oro ram4 LST Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 2' 204-135. 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23218-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑, MILNE PT UNIT 1-19 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 - MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,720' - 4,088' - 9,720' • . 4,088' 900 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,530psi 520psi Surface 161' 10-3/4" 161' 161' 3,580psi 2,090psi Surface 2,838' 10-3/4" 2,999' 2,549' 3,580psi 2,090psi Intermediate 7,428' 7-5/8" 7,428' 4,075' 6,890psi 4,790psi Liner 211' 4-1/2" 7,255' 4,063' 8,430psi 7,500psi Slotted Liner'OA' 5,012' 4-1/2" 12,199' 4,045' N/A N/A Slotted Liner'OB' 2,405' 4-1/2" 9,720' 4,088' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 6,604' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES HRD ZXP&Baker ZXP and N/A , 7,144MD/4,000TVD&7,326MD/4,056TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development 2, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/21/2017 Commencing Operations: OIL 0• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola(C hiIcorp.com Contact Phone: 777-8412 Authorized Signat - A73a—.� 1�., [m/4, Date: 8/1/2017 COMMISSION USE ONLY Conditions of ap• • al: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test is Mechanical Integrity Test ❑ Location Clearance ❑ Other: „e._ 2,s.-.7zO , S•- FG.: �i;�'f-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0--410 Li RBDMSflit- AUb- 1 1 2017 APPROVED BY Approved by:#r COMMISSIONER THE COMMISSION g / _ Date: �'_! 7 8/?f � 7V '' Submit Form and Form 10-403 Revised 4/2017 O (�plyeN�aip'i>�ti�r i valid for 12 months from the date of appro///I. Attachments in Duplicate n • • Well Prognosis Well: MPU 1-19 h u ion,Alaska,LLI Date:8/03/2017 Well Name: MPU 1-19 API Number: 50-029-23218-00 Current Status: Oil Well [Failed ESP] Pad: I-Pad Estimated Start Date: August 21st, 2017 Rig: SR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-135 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1722259 1 Job Type: ESP Repair Current Bottom Hole Pressure: 1,329 psi @ 4,000' TVD (SBHPS 8/03/2017/6.39 ppg EMW) Maximum Expected BHP: 1,329 psi @ 4,000' TVD (No new perfs being added) MPSP: 929 psi (0.1 psi/ft gas gradient) C tt' Brief Well Summary: The Milne Point 1-19 well was drilled as a Schrader Bluff development well dual lateral with Doyon 14 in September 2004. The well was initially completed with an ESP.This ESP failed and was replaced in February 2005 (Nabors 4ES). In October 2008(Nabors 3S),the LEM (Lateral Entry Module)and ZXP liner top packer was installed along with a replacement ESP. In November 2009 (Nabors 4ES), a failed ESP was pulled and a 4-1/2" completion string was ran into the ZXP liner top packer. A coil tubing cleanout in December 2009 was completed in the OA sand to 10,900' CTM and in the OB sand to 9,702' CTM.The 4-1/2" completion string was pulled in January 2010 (Nabors 4ES)and a s ran.This ESP failed and was replaced in February 2013 (Doyon 16).The current ESP completion has hole in a tubing as of June 2017 and is a known solids producer, therefore options to patch the tubing are lime ed.The ESP and tubing will bP�replaced. Notes Regarding Wellbore Condition • Casing tested to 1,700 psi down to 6,572' MD (Above ESP Set Depth) on 2/12/2013. • Casing tested to 2,000 psi down to 7,116' MD (Above Liner Top) on 11/03/2009. , • Max angle 76.3° @ 6,760' in the 7-5/8" casing. Max angle 94.9 @ 8,090' in the laterals. • Deviation at ESP is 74.0° and dogleg of 1.75°/100 ft. • Min ID is 2.25"thru XN profile above ESP. • Last Fill Depth: 10,900' MD N2 cleanout of the OA lateral on 12/06/2009. • Last Fill Depth: 9,702' MD N2 cleanout of the OB lateral on 12/07/2009. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. C c 3r� e.t, icer Objective: The purpose of this work is to pull the failed ESP, run a kill string, rig down the ASR rig, RU coil and cleanout the lateral, rig up the ASR rig, pull the kill string and run new tubing and a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. . 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. ' . 11 . • Well Prognosis Well: MPU 1-19 "(ikon)Alaska,LL Date:8/03/2017 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect ( to send an inspector to witness test. IND. b. With stack out of the test path, test choke manifold per standard procedure "fe../j- c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor CO' the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. Pump cleaning pill w/heated seawater to flush tubing of residual oil. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2013 ESP swap was 80K lbs(block weight of 40k) b. If needed, circulate pill (forward or reverse) with cleaning surfactant prior to laying down the tubing hanger. 16. Recover the tubing hanger. • Well Prognosis Well: MPU 1-19 Ililcorp Alaska,LU Date:8/03/2017 Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will be junked. Lay down failed ESP. a. Junk all joints of tubing. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. RIH with 7-5/8" 29.7#scraper assembly to—7,144' MD (top of ZXP Liner Top Packer) on 3-1/2" workstring. Circulate the well clean with 8.5 ppg seawater. 19. POOH and LD 3-1/2" workstring and scraper assembly. 20. PU seal assembly and RIH on 4-1/2" tubing. 21. Tag up and space out above the ZXP Liner Top Packer at±7,144' MD. Circ inhibited packer fluid and freeze protect fluid. '07) 22. Set seals below top of ZXP Liner Top Packer at±7,144' MD. 23. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off) weights on tally. "< 24. Pressure test annulus to 1,750 psi for 30 min and chart (test casing from surface to the ZXP packer). Contingency(If casing test fails): PU 7-5/8" RTTS and RIH on 3-1/2" workstring and test casing Cc S to 1,750 psi looking for possible leak. Notify town engineer of results to decide plan forward. 25. Lay down landing joint. 26. Set BPV. Rig down ASR. Post-Rig Procedure: 27. RD mud boat. RD BOPE house. Move to next well location. 28. RU crane. ND BOPE. 29. NU new 4-1/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 30. RD crane. Move 500 bbl returns tank and rig mats to next well location. 31. Replace gauge(s) if removed. 32. Turn well over to production. RU well house and flowlines. Coiled Tubing Procedure: + ti % ra-0 33. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 34. Pressure test BOPE 3,500 psi Hi 250 Low, 10 min each test. a. Each subseque nt testof he lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 35. RIH w/2.00" coil w/diverter sleeve and set in XN profile below LEM (Lateral Entry Module) at 7,187'. POOH. 36. RIH w/2.00" coil w/2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 12,198' MD in the OA lateral. POOH. • • Well Prognosis Well: MPU I-19 !Won)Alaska.LLQ Date:8/03/2017 a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 12,198' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 37. RIH w/2.00" coil w/4" GS spear retrieval tool and recover diverter sleeve set in XN profile below LEM (Lateral Entry Module) at 7,187'. POOH. 38. RIH w/2.00" coil w/ isolation sleeve and set in XN profile below LEM (Lateral Entry Module)at 7,187'. POOH. 39. RIH w/2.00" coil w/2.0" to 2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-9,676' MD in the OB lateral. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. , b. Contingency: If unable to wash down with nozzle, RIH w/2.0" to 2.5" mill and extended reach r cleanout BHA and cleanout to PBTD at+/-9,676' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 40. RIH w/2.00" coil w/4" GS spear retrieval tool and recover isolation sleeve set in XN profile below LEM (Lateral Entry Module) at 7,187'. 41. PU to 2,500' and freeze protect well down the coil x tubing annulus. POOH w/coil. 42. RD Coiled Tubing and ancillary equipment. 43. Turn well over to production. �I Pre-Rig Procedure: _ 15,E %�) /1-S I 1)1 ..t 4- 44. 44. Clear and level pad area in front of well. Spot rig mats and containment. 45. RD well house and flowlines. Clear and level area around well. 46. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 47. Pressure test lines to 3,000 psi. 48. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing, taking returns up casing to 500 bbl returns tank. 49. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 50. RD Little Red Services and reverse out skid. 51. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 52. NU BOPE house. Spot mud boat. Brief RWO Procedure: 53. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 54. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 55. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. • i Well Prognosis Well: MPU 1-19 Ililcorp Alaska,LLI Date:8/03/2017 d. Test VBR ram on 2-7/8" and 4-1/2"test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 56. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. ttbt1: b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 57. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 58. MU landing joint or spear and PU on the tubing hanger. a. The PU weight is estimated to be 80k. 59. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 60. Pull seals out of ZXP packer. Circ out inhibited packer fluid and freeze protect fluid using 8.5 ppg �j y seawater. 61. POOH and the 4-1/2" tubing and seal assembly. I10)-- - 62. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±6,200' MD. a. Upper GLM @ ± 140' MD w/SO b. Lower GLM @ ±5,950' MD w/ DGLV 05P c. 2-7/8" XN (2.205" No-Go) @ ± 6,100' MD d. Base of ESP centralizer @ ±6,200' MD e. Run heat trace from ±3,500' MD to surface. 63. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 64. Set BPV. Rig down ASR. Post-Rig Procedure: 65. RD mud boat. RD BOPE house. Move to next well location. 66. RU crane. ND BOPE. 67. NU previous 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. • • Well Prognosis Well: MPU 1-19 Hilcorp Alaska,Lb Date:8/03/2017 68. RD crane. Move 500 bbl returns tank and rig mats to next well location. 69. Replace gauge(s) if removed. 70. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Temporary Tree/Wellhead 6. Blank RWO MOC Form 7. Coil BOPE Schematic 8. Nitrogen Operations Procedure 9. Nitrogen & Foam Flow Diagram • Milne Point Unit 11 Well: MPU 1-19 SCHEMATIC Last Completed: 2/14/2013 Hamra Alaska,LIA PTD: 204 135 WELLHEAD Tree 2-9/16"-5M FMC 11"x 11"5M Gen.FMC Gen 5,2/2-7/8" Orig.DF Elev.=69.10'/Orig.GL Elev.=24.80' Wellhead FMC tubing 2-7/8"EU 8rd on top& bottom,2.5"CIW=H BPV Profile /k OPEN HOLE/CEMENT DETAIL 20'4 20" 260 sx of Arcticset(Approx)in 42"Hole 1 468 sx of Class Lite and 254 sx Class"G"in 10-3/4" 13-1/2"Hole 7" 757 sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40/N/A N/A Surface 112' N/A 10-3/4" Surface 45.5/L-80/BTC-M 9.950 Surface 161' 0.0962 10-3/4" Surface 45.5/K-55/BTC-M 9.950 161' 2,999' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 7,428' 0.0459 10-3/4'4 " A 4-1/2" Liner 12.6/L-80/IBT 3.958 7,144' 7,355' 0.0152 t 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 7,187' 12,199' 0.0152 Centilift heat trace 4-1/2" Slotted Liner"OB" 12.6/L-80/IBT 3.958 7,315' 9,720' 0.0152 to 2,954' TUBING DETAIL 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2.441 Surface 6,604' 0.0058 WELL INCLINATION DETAIL KOP@300'MD Max Hole Angle=75 deg.@ 6,450',50+deg.from 2,500'MD 2 JEWELRY DETAIL No Depth Item 1 142' GLM ST 2:Camco KBMM-2 1"DGLV set 2/13/13 2 6,361' _ GLM ST 1:Camco KBMG 1"DSOV set 2/13/13 kiln ID=2.20` 3 6,513' 2-7/8"HES XN Nip,ID=2.25" @6,512 I 13 4 6,555' Discharge Head:FPHVDIS t''... 'I4 5 6,556' Pump:140-P10 PMSXD 6 6,573' Gas Separator:GRSFTXARH6 5 7 6,578' Tandem Seal Sections:GSD3DB UT/LT SB/SB PFSA 8 6,592' Motor:CL4-MSP1 84 HP,2,210 volt,23 amp 1:111: 6 9 6,602' Sensor:MGU w/6 fin centralizer-Bottom @ 6,604' 10 7,144' HES HRD ZXP Liner Top Packer 7 11 7,187 4-1/2"x 7-5/8"Baker LEM#1 12 7,187' 4-1/2"Hook hanger inside casing(outside hook point 7,204') 8 13 7,263' 2-7/8"XN Nip,10=2.323" 14 7,310' L-1 Non-Locating Seal Assembly tji 15 7,315' Baker Tie Back Sleeve 43 16 7,326' Baker ZXP Liner Top Packer 9 17 7,332' Baker HMC Liner Hanger 18 7,340' Baker Sealbore extension LATERAL WINDOW DETAIL 4 " 10 Window in 7-5/8"Casing @ 7,192'to 7,204'_ Well Angle @ Window=72 deg. GENERAL WELL INFO API:50-029-23218-00 and 50-029-23218-60 mii.i Drilled and Completed by Doyon 14 -9/13/2004 ' 11,12 ESP RWO by Nabors 4ES-2/12/2005 r f ESP RWO and Install LEM by Nabors 3S-10/17/2008 "Q4"Lateral ESP RWO by Nabors 4ES-1/10/2010 1'0113 x«tea,,",. 14 ESP RWO by Doyon 16-2/14/2013 ?' a ,=! 14,15,16,17,18 7 ,I \ OB'Lateral "OB"TD=9,720'(MD)/TD=4,088'(ND) PBTD=9,720'(MD)/PBTD=4,088'(TVD) Revised By:DH 6/23/2017 • • • Milne Point Unit 111 Well: MPU 1-19 PROPOSED Last Completed: 2/14/2013 11Ricurp Alaska.i,i,c PTD: 204-135 WELLHEAD Tree 2-9/16"-5M FMC 11"x 11"5M Gen.FMC Gen 5,2/2-7/8" Orig.DFElev.=69.10/Orig.GL Elev.=24.80' Wellhead FMC tubing 2-7/8"EU 8rd on top& 2.5"CIW=H BPV Profile 20"41 Lbottom, OPEN HOLE/CEMENT DETAIL 20" 260 sx of Arcticset(Approx)in 42"Hole 1 468 sx of Class Lite and 254 sx Class"G"in 10-3/4" 13-1/2"Hole 7" 757 sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40/N/A N/A Surface 112' N/A 10-3/4" Surface 45.5/L-80/BTC-M 9.950 Surface 161' 0.0962 10-3/4" Surface 45.5/K-55/BTC-M 9.950 161' 2,999' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 7,428' 0.0459 103/4"I , 4-1/2" Liner 12.6/L-80/IBT 3.958 7,144' 7,355' 0.0152 4-1/2" Slotted Liner"OA" 12.6/L-80/IBT 3.958 7,187' 12,199' 0.0152 Centlft heat trace 4-1/2" Slotted Liner"OB" 12.6/L-80/IBT 3.958 7,315' 9,720' 0.0152 to±3,500' r TUBING DETAIL 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2.441 Surface 6,604' 0.0058 WELL INCLINATION DETAIL 4 KOP@300'MD Max Hole Angle=75 deg.@ 6,450',50+deg.from 2,500'MD JEWELRY DETAIL 2 No Depth Item 1 ±142' GLM ST 2:Camco KBMM-2 1"DGLV set 2/13/13 2 ±5,959' GLM ST 1:Camco KBMG 1"DSOV set 2/13/13 MnID=2.205" 3 ±6,111' 2-7/8"HES XN Nip,ID=2.25" ©6,512 b 3 4 ±6,153' Discharge Head:FPHVDIS 4 5 ±6,154' Pump:140-P10 PMSXD 6 ±6,171' Gas Separator:GRSFTXARH6 5 7 ±6,176' Tandem Seal Sections:GSD3DB UT/LT SB/SB PFSA 8 ±6,190' Motor:CL4–MSP1 84 HP,2,210 volt,23 amp lilaill 6 9 ±6,200' Sensor:MGUw/6fin centralizer–Bottom @±6,202' 10 7,144' HES HRD ZXP Liner Top Packer 7 11 7,187' 4-1/2"x 7-5/8"Baker LEM#1 12 7,187' 4-1/2"Hook hanger inside casing(outside hook point 7,204') B 13 7,263' 2-7/8"XN Nip,ID=2.323" 14 7,310' L-1 Non-Locating Seal Assembly 15 7,315' Baker Tie Back Sleeve 16 7,326' Baker ZXP Liner Top Packer 9 17 7,332' Baker HMC Liner Hanger 18 7,340' Baker Sealbore extension ✓��q'4 LATERAL WINDOW DETAIL 4. ► 10 Window in 7-5/8"Casing g @ 7,192'to 7,204' Well Angle @ Window=72 deg. GENERAL WELL INFO API:50-029-23218-00 and 50-029-23218-60 Drilled and Completed by Doyon 14 -9/13/2004 11,12 ESP RWO by Nabors 4ES-2/12/2005 s - `- ESP RWO and Install LEM by Nabors 3S–10/17/2008 • Latea ESP RWO by Nabors 4ES–1/10/2010 ' 13r ..."Cl._ — qi ESP RWO by Doyon 16–2/14/2013 .�,' ,�- 14,15,1317,18 r .11 "OB"lateral "OB"TD=9,720'(MD)/TD=4,088'(TVD) PBTD=9,720'(MD)/PBTD=4,088'(TVD) Revised By:TDF 8/1/2017 • . ! S II Milne Point ASR Rig 1 BOPE frl.-.qw,%It•t*.ii,t. 11" BOPE , Stripping Head ( 1 3.98' Ir. 1,TII P Shaffer a 4 • 50001411. Num ow 1161tII& lI al 111 - TAU III 1 ...Irmo CI ► -U rl 4.54 �dEt � (_ �= VBR or Pipe Rams r}Gr. :e4I 11 5000 11116111 Blind n in Trutt 21/16 5M Kill Line Valves x 21/16 5M Choke Line Valves I 1111IiLUHF 'fi - 2.00' : .171 di ffi'ii, ! C i I i I ! Iii f I� J- I Manual Manual . ! Manual HCR Updated 8/19/2015 • 14 •EXISTING TREE/WMPU I-19 Wellhead/Tree head/Tree Milne Point Unit Ilileorp Alaska.I.IA II Tree Cap ‘,--$.,0. eita Tree Valve 2-9/16" 5M '(0 `' , ,1101 ,i, - c 1 0 0 Tree Cross 2-9/16" 5MIn IF,(°)c,)oo- Tree Valve 2-9/16" 5M SSV 2-9/16" 5M 0 11N. Tree Valve 2-9/16" 5M �ff'..(:)(oro 0p0: I ,�,., ESP Cable I" "I an Tubing Adapter i =: Tubing Head in Hu 11" 5M Top x 11" 5M Btm m'.. Wit, ga all I. aloin:: I rI I!-I..! Iii III Casing Head ,, l .'AMIE N. imp 11" 5M Top x 11" 5M Btm II All ill"' I j 11 • • TEMPORARY TREE/WELLHEADMPU 1-19 Wellhead/Tree Hilcorp Alaska,ILLMilne Point Unit Tree Cap 111 t,i lis € •t 1 0 Tree Valve 4-1/16" 5M z,"o .. et, Tree Cross 4-1/16" 5M WI.. s Tree Valve 4-1/16" 5M X00 Tree Valve 4-1/16" 5M ±'o ° ,.,.R, � 0 Tree Valve 4-1/16" 5M - (off CCC: III MI 1 kr I1' '� Tubing Adapter if - ...._, Tubing Head is",= Ill 11" 5M Top x11" 5M Btm a1 -•'#'''' ' ' 11111 Hifi, ,i �mii. �IIt rte' Iti •1. lii Casing Head _ , ,.: 11" 5M Top x 11" 5M Btm_ — ,40‘, it iiiiiini,' - fill-I- # . ` 0 • 0 0 o JJf co / / C > g e > o / 7 Rk ( § _c < �a E o c o - ' e 0 MI CA / §< 2 f \ E 0. $ 0 m 3f \ � s- C 0 \ CO k / � c 00 � � § .§ < m ■ a) \ / k k o 0 Co / CD % B kk 0 _a / k \ 14. \ \\ c \« co '§- 0 c \ 20 2 0 0 4. § 9 S CD E E § 2 m R o a O 2 0 .R 2 0 / a a II /ass § .� k a) co c I > 0 § @ o 2 0 04 / < / \ . - r0 % « E 0 o 7 CO CO & n .2 ® CO CI CD � II 0 a) ■ 2 7 2 a 2 it o 0 .. TO. \ a > ¢ k 2 /3 0. 2 f o $ $ \ / < E • • Milne Point Unit a 0 COIL BOPE MPU I-19 nil.."11.4..l.iA 6/21/2017 MPU 1-19 20 x 10% x 7% x 4% Coil Tubing BOP € Lubricator to injection head f ° 1 2.00"Single Stripper •',(,I % Blind/Shear = 1/16 10 =w Blind/Shear ,I,'. . Ili 1.',I, Blind/Shear 1111. =r Blind/Shear 11110 O IIII •',I. Slip _ ® ■� Slip Illt(111 meemi 011111 Pipe �_ Pipe •I•''(-II zea Crossover spool 4 1/16 10M X 4 1/16 5M tea a Pump-In Sub { • 4 1/16 5M , °j (°'•.11502 Union 3 R IAB Manual Gate Manual Gate • • Valve,Swab,WKM-M, r2 1/8 5M 21/85Mo,. �O. 41/165MFE ) ,� .e l��e. �a��e��' • • o• ,6 in ,• ... Valve,Upper Master,Baker, • 4 1/16 5M FE,w/Hydraulic alma Valve,Lower Master,WKM-M, '10 4 1/16 5M FE `� tirM* _WI ia 7 Tubing Adapter,4 1/16 5M • w► STANDARD WELL PROCEDURE HiI or•p AIaaka.LIA NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 . • • i Oil ■ 2 § $ . . / ! 2 ) ( * ce © \ ' \ E 2 = & / ez Z �2§ ! i; E� �\k § ) � " • \ 2222 k m § § k e E | - s \ . \ �m ) '4 ■ I Z Z O _ ee I- _ .) . 2 .x Z 2 E »_ _ _ • _ « { 2 - �•. a. |/ © a 0 & a ■ # § ( / \ r ) • m : } 6 [ 0 _ > )\ ) «l . ) \ \ \ \ \ \ r. 2 k k \ , \ #� (: 5 \ 2 2 / u w 3=c « . § . § 2( m § ) < \ \ A .. . . . '!..4... MI MI _�. Z • Y1A k 2 5 : " = f' /| ! : 2 I � � . g : . . \1 #7 I ° ,,,,.1.7;--,:-, , «:: :: a k _ » \ j % k ' mt ill\ . :| ( j � @ # iv k I \ i k d ) V r_ � —Z-[>-- . 1- § )22 z A. §. \ / e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. & () '=J- - 1 '3 S Well History File Identifier Page Count from Scanned File: I à 8' (Count does include cover sheet) Page Count Matches Number in sc:nning Preparation: ~ YES ~ Date:/JI<ð/D~ Organizing (done) D Two-sided "' 111111111111111I REYAN ¥CoJor Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. to D Other, No/Type: D Poor Quality Originals: D Other: NOTES: Dale 1 . ~/O~ BY: , Maria J Project Proofing BY: G- Maria ~ Date: , I J Rio 0 Lf X 30 = {àO Date: III ~ /oip Scanning Preparation BY: C Maria => Production Scanning Stage 1 BY: Stage 1 D Rescan Needed 111111111111"" III OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: lMP 11111111111111 "III Isl Isl ~p + 7 = TOTAL PAGES I d- 'l (Count does not include cover sheet) VI AJ!) Isl r V I ,- 111111111111111111I NO Isl wr NO BY: Date: If NO in stage 1, page(s) discrepancies were found: YES Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: Isl III II 111111I111111I III II 111111111 1111I Isl Quality Checked 111111111111 1111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED •SKA OIL AND GAS CONSERVATION C MISSION REPORT OF SUNDRY WELL OPERATIONS MAR 0 `= 2013 1. Operations Performed: AOGCC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ° 204 - 135 3. Address: ® Development ❑ Service 6. API Numbe r P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 — MPI - ' 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 9720' feet Plugs:(measured) None feet true vertical 4088' feet Junk: (measured) None feet Effective depth: measured 9720' feet Packer: (measured) None feet true vertical 4088' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34' - 112' 34' - 112' 1490 470 Surface 2964' 10 -3/4" 35' - 2999' 35' - 2550' 5210 2480 Intermediate Production 7395' 7 -5/8" 33' - 7428' 33' - 4076' 6890 4790 Liner 2405' 4 -1/2" 7315 - 9720' 4053' - 4088' 8430 7500 Perforation Depth: Measured Depth: Slotted 7391' - 9591' feet True Vertical Depth: Slotted 4070' - 4095' feet Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 6604' 3844' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED APR 1 9 2013 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 160 36 172 250 202 Subsequent to operation: 170 42 110 220 204 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: ■ ® Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 564 -5683 N/A Email: David.Bjork @bp.com Printed - 'e Joe • u : Title: Drilling Technologist Signatur , .1\ Phone: 564 - 4091 ,! Date: 5/ Form 10-404 R- -ed 10/2 RBDMS MA 08 ✓AL c /9 ubmit Original Only • . ,�- �,. -., a 4 h:7 a cam. >,' Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date /Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/10/2013 00:00 - 03:00 3.00 MOB P PRE MOBILIZE EQUIPMENT IN PREPARATION FOR RIG MOVE - LOAD EQUIPMENT ONTO TRAILERS - MOVE CREW TRAILER - PJSM FOR DERRICK OVER - BRIDLE UP AND LAY DERRICK OVER 03:00 - 05:00 2.00 MOB P PRE PJSM FOR RIG MOVE OFF OF MPG -14 - NOTIFY PAD OPERATOR - DAY AND NIGHT TOOLPUSHERS & NIGHT WSL ON LOCATION - PULL OFF OF MP G -14 AND MOVE TO MP I PAD 05:00 - 06:30 1.50 MOB P PRE ARRIVE MPI -PAD - PULL ON TO MPI -PAD - LAY MATS AND PREP TO BACK OVER WELL. - BACK OVER MPI -19 - WSL / TOOLPUSHER PRESENT. 06:30 - 09:00 2.50 RIGU P PRE PJSM, RAISE DERRICK - BRIDLE DOWN - SPOT RIG COMPONENTS. - RU CELLAR AND RIG FLOOR. - KWF STILL IN ROUTE FROM PBU. ACCEPT RIG AT 0900 HRS 2/10/2013 09:00 - 10:00 1.00 WHSUR P WHDTRE PJSM, RU CIRCULATING EQUIPMENT.. - RU TO HARD LINE TO FLOW BACK TANK - WARM LINE AND FILL TO TEST WITH DIESEL. 10:00 - 12:00 2.00 WHSUR P WHDTRE PJSM, R/U KILL MANIFOLD IN CELLAR. - CIRCULATING LINE TO WELL HEAD. - TAKE ON 130 DEG F. SEAWATER (8.5PPG KWF) TO PITS. - FILL LINES WITH DIESEL - PRESSURE TEST KILL MANIFOLD AND HARD LINE. - 250 / 3500 PSI FOR 5 CHARTED MIN. PASSED. - TEST ALARM ON FLOW BACK TANK. 12:00 - 13:00 1.00 WHSUR P WHDTRE PJSM, CONTINUE ONLOADING 8.5 PPG - 120 DEGREE SEAWATER TO PITS. - PERFORM SPCC CHECKS AROUND THE RIG. SET UP COMMS. - RIG ELECTRICIAN TESTING ALARMS AND GAS DETECTORS. 13:00 - 14:00 1.00 WHSUR P WHDTRE HELD H2S EVAC DRILL. WSL, TOOLPUSHER, SCS, RIG CREW, THIRD PARTY PERSONNEL PRESENT. AAR - GOOD RESPONSE TIME BY ALL. DRILLER / FLOOR HAND CONDUCTED SWEEP OF RIG ON WAY OUT. -ALL 17 PERSONNEL ON LOCATION ACCOUNTED FOR. -SIREN COULD BE HEARD BY ALL PERSONNEL INVOLVED ON BOTH SIDES OF RIG. Printed 2/25 /2013 10:19:21AM • • Operation Summary Report x Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING ©69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:00 2.00 WHSUR P WHDTRE PJSM, PU DSM LUBRICATOR. RU TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. - PULL BPV WITH TESTED LUBRICATOR. SITP = 0 PSI. SICP = 120 PSI - LD LUBRICATOR PER DSM REPS. 16:00 - 16:45 0.75 KILLW P DECOMP PJSM, WELL KILL / BULLHEAD. - WSL, TOOLPUSHER, SCS, RIG CREW IN ATTENDANCE. - REVIEW DDI WELL KILL SOP. DISCUSS VALVE ALIGNMENT, HAND HELD GAS DETECTOR WITH MAN AT FBT. - DRILLER DISCUSSED ROLES AND RESPONSIBILITIES OF PERSONNEL. - MPU SECURITY AND PAD OPERATOR NOTIFIED OF GAS VENTING ON PAD. 16:45 - 20:00 3.25 KILLW P DECOMP R/U TO BULLHEAD WELL VIA WELL KILL MANIFOLD IN CELLAR. - WSL & TOOL PUSHER VERIFY VALVE ALIGNMENT FOR OA BLEED. - BLEED GAS FROM OAAT 500 PSI TO 150 PSI IN 8 MINUTES, NO FLUID RETURNS. - WSL & TOOL PUSHER VERIFY VALVE ALIGNMENT FOR BULLHEAD KILL. - BULLHEAD DOWN 27 /8" TBG AND IA SIMULTANEOUSLY. - BULLHEAD WITH 120 DEGREE 8.5 PPG SEAWATER. - PUMPED 870 BBLS KWF @ 9 BPM. 1CP (BULL HEAD) = 70D PS1. FCP (BULL HEAD) = 775 PSI. - SLOW TO 1 BPM 300 PSI. - PUMPS OFF 225 PSI @ 19:12 HRS. - AFTER 22 MINUTES BOTH TBG AND IA ON A VACUUM. - MONITOR WELL WITH PUMPS OFF FOR 30 MINUTES. - HOLE FILL FOR 20 MINUTES, 32 BBLS KWF. - 580 BBLS KWF LOST TO FORMATION 20:00 - 21:00 1.00 WHSUR P DECOMP RIG DOWN MANIFOLD - BLOW DOWN LINES - RIG DOWN CIRCULATING LINES & KILL MANIFOLD - R/U SECONDARY KILL LINE 21:00 - 22:30 1.50 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND °— — 3500 PSI LOW FOR 5 MINS EACH , CHARTED - SET TWC LAY DOWN LUBRICATOR Printed 2/25/2013 10:19:21AM • , Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date /Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 WHSUR P DECOMP PRESSURE TEST TWC - PERFORM ROLLING TEST BELOW TWC - POMP DOWN IA@ 9 BPMAND 500 PSI FOR 10 MINS, CHARTED (147 BBLS KWF PUMPED) - TEST TWC FROM ABOVE : 250 PSI LOW & 3buu PSI HIGH FOR 5 MINS EACH , CHARTED - AOGCC , CHUCK SCHEVE WAIVED STATES RIGHT OF WITNESS BOP TEST - MAINTAIN HOLE FILL TO IA AT 20 BPH WITH 8.5 PPG SEAWATER. TOTAL FLUIDS LOST IN 24 HRS= 1043 BBLS 8.5 PPG SEAWATER 2/11/2013 00:00 - 02:00 2.00 WHSUR P DECOMP PJSM TO DRAIN AND NIPPLE DOWN_TREE & , N/U BOPE =`N?PPtE DOWN FMC ADAPTER FLANGE & 2 9 /16 ",5MTREE - FMC REP CLEAN AND INSPECT EUE 8RD HANGER THREADS - CONFIRM 9 1/2 TURNS BY HAND - PRIOR TO NIPPLE DOWN , RIG CREW, FMC, AND MP WELL SUPPORT VERIFIED REFERENCE MARKS FOR POST RIG TREE ALIGNMENT 02:00 - 04:00 2.00 WHSUR P DECOMP PJSM, NIPPLE UP BOPE - N/U 13 -5/8" BOPE STACK. 04:00 - 06:00 2.00 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TESTANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST. - NO FAILURES. - CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT OF WITNESS BOP TEST - MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST @ -20 BPH , 8.5 PPG SEAWATER 06:00 - 09:00 3.00 BOPSUR P DECOMP PJSM, CONTINUE TESTING BOPE EQUIPMENT - CONDUCT TESTACCORDING TO DDI BOPE TESTING SOP. Printed 2/25 /2013 10:19:21AM • Y p ..Y .. x g ,s Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 11:30 2.50 BOPSUR P DECOMP PJSM, SLIP AND CUT DRILLING LINE. - DISCUSSED DDI SOP. ALL PERSONNEL HANDLING DRILL LINE WORE LEATHER GLOVES. - ALL PROPER PPE WAS WORN. GOOD COMMUNICATION WITH LOADER / RIG FLOOR. CUTATOTAL OF 594' OF DRILL LINE. - LOSSES TO WELL LAST 12 HOURS = 230 BBLS. 11:30 - 12:00 0.50 BOPSUR N DECOMP PJSM, PU DSM LUBRICATOR / OFFSET EXTENSION. - R/U ASSOCIATED TEST HOSES. - WAIT ON WELL SUPPORT DUE TO CONFLICTING JOB ON ANOTHER LOCATION. 12:00 - 13:00 1.00 BOPSUR P DECOMP PJSM, FILL BOPE, R/U DSM LUBRICATOR / OFFSET EXTENSION. - CONTINUE TO WAIT ON WELL SUPPORT. 13:00 - 14:00 1.00 BOPSUR P DECOMP - CLOSEANNULARANDPRESSURETESTTO 250 / 3500 PSI AND CHART FOR 5 MINUTES EACH. - PULL TWCAND R/D DSM LUBRICATORAND EXTENSION. 14:00 - 15:00 1.00 PULL P DECOMP PJSM, HANG ESP SHEAVE IN DERRICK. HANG ELEPHANT TRUNK FOR ESP CABLE. - R/U TO PULL ESP COMPLETION. CENTRILIFT REP TO CHECK REELS FOR ESP CABLE AND HEAT TRACE. 15:00 - 15:30 0.50 PULL P DECOMP PJSM ON PULLING 2 7/8 TBG HANGER, TO FLOOR. WSL, TOOLPUSHER, FMC REP, RIG CREW I N ATTENDANCE. - DISCUSSED WELL CONTROL, CONTINUOUS HOLE FILL, DISCONNECTING ESP CABLE FROM PENETRATER. 15:30 - 16:30 1.00 PULL P DECOMP MU 2 -7/8" EUE LANDING JOINT WITH FOSV TO TBG HANGER. BOLDS PER FMC REP. - WSL VERIFY NO TRAPPED PRESSURE UNDER,TBG HANGER. - PULL TBG_ HANGER OFFEAT 80 INCLUDES 40K TOP DRIVE WT. - MAX PULL 80K INCLUDES TOP DRIVE WT. - PUW = 79K, SOW = 70K - CENTRILIFT REP CONDUCT CONDUCTIVITY TEST ON ESP. GOOD. - PULL HANGER AND REMOVE FLAT GUARDS AND BANDS ON FIRST FULL JOINT, - CUT ESP & HEAT TRACE CABLE. - POSITION SLICK JOINT ACROSS BOPE. - LD TBG HANGER. 16:30 - 18:00 1.50 PULL P DECOMP PJSM, - CLOSE ANNULAR - BULLHEAD 40 BBLS KWF DOWN TUBING, 5.5 BPM = 1270 PSI. - WSL / DRILLER VERIFY VACUUM AND NO TRAPPED PRESSURE. - OPEN ANNULAR. START FEEDING THE IA. - CONTINUOUS HOLE FILL 8.5 PPG SEAWATER AT —20 - 25 BPH. Printed 2/25/2013 10:19:21AM • - �' ,' �,� � � s � � air Y 'r , ? y �''' $` `�'Ts f"�� " ' .�" ry Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- OOX6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date /Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 18:30 0.50 PULL P DECOMP L/D LANDING JOINT, FOSV AND CIRC HOSE. - BLOW DOWN CEMENT LINE AND CIRC. EQUIPMENT. 18:30 - 00:00 5.50 PULL P DECOMP PJSM TO PULL ESP / HEAT TRACE COMPLETION ASSEMBLY - POH WITH 2 -7/8" EUE 8RD TUBING, ESP CABLE , & HEAT TRACE - ATTACH ESP CABLE AND HEAT TRACE TO SPOOLING UNIT - POOH W/ ESP COMPLETION, HEAT TRACE ENDED AT- 3200" MD CONTINUAL HOLE FILL WITH 8.5 PPG SEAWATER @ -25 BPH 568 BBLS OF 8.5 PPG SEAWATER LOST IN 24 HRS 2/12/2013 00:00 - 02:30 2.50 PULL P DECOMP POOH WI 2-7/8" EUE 8RD TUBING AND ESP PUMP ASSEY CONTINU E POOH FROM -3600' MD 02:30 - 03:00 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL AAR: - SAFETY VALVE & JOINT WAS STABBED ON IN TIMELY MANNER - DISCUSSED CLOSING POWER TONGS LATCH IN ORDER TO WORK TUGGER - GOOD SIMULATION OF CUTTING & SECURING ESP CABLE 03:00 - 05:00 2.00 PULL P DECOMP INSPECTION REVEALS FOURTH TO LAST FULL JOINT OF 2 -7/8 ", L -80 IS FULL OF KWF, APPARENTLY TUBING BELOW IS PACKED OFF. - CONDUCT PJSM ON RIGGING UP TUBING PUNCH. - RU PUNCH, PUNCH HOLE IN TUBING JOINT BELOW COLLAR LOCATION; NO PRESSURE, SEAWATER ABOVE PUNCH - PICK UP STRING, MAKE SECOND & THIRD PUNCHES; NO PRESSURE - SEAWATER & SOME SCALE COMING FROM TUBING PUNCH , NO SAND OR PROPPANT - BREAK CONNECTION, INSPECT TUBING, - OUTSIDE OF TUBING IS FULL OF SCALE 05:00 - 06:00 1.00 PULL P DECOMP PULL ESP PUMP ASSEMBLY TO RIG FLOOR - CENTRILIFT BREAKING DOWN ESP - OUTSIDE OF PUMP IS ALSO FULL OF SCALE - UPPER PUMP COMPLETELY PACKED OFF WITH SCALE. CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER @ -25 BPH 06:00 - 07:00 1.00 PULL P DECOMP PJSM, LAY DOWN ESP MOTOR ASSEMBLY TO PIPE SHED. - ESP FAILURE TO BE DETERMINED AT CENTRALIFT SHOP. - CLEAN SCALE FROM RIG FLOOR. 07:00 - 08:30 1.50 PULL P DECOMP RD ESP SHEAVE FROM DERRICK. RD ELEPHANT TRUNK.. - CLEAN RIG FLOOR AND PIPESHED FREE OF SCALE. - SET 9 1/8" ID WEAR RING. Printed 2/25/2013 10:19:21AM • North America - ALASKA 3 Operation Summary Report xs Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10 /2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date /Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 12:00 3.50 EVAL P DECOMP PJSM, PU / MU 7 5/8" HES CHAMP PACKER PER HES REP. - WSL, TOOLPUSHER, HES REP. RIG CREW IN ATTENDANCE. - OD. OF HES 7 5/8" CHAMP PACKER = 6.51" - RIH ON 2 7/8" EUE TBG FROM DERRICK. - RIH TO 6066" MD. PUW= 65K INCLUDING 40K TOPDRIVE WT. SOW = 60K. LOSSES TO WELL LAST 12 HOURS = 243 BBLS KWF. 12:00 - 12:45 0.75 EVAL P DECOMP PJSM, SERVICE RIG, INSPECT EQUIPMENT. INSPECT HANDLING EQUIPMENT. - INSPECT TOP DRIVE, SERVICE LOOP, INSPECT DRAWWORKSAND BRAKES. - MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 PPG KWF. 12:45 - 14:00 1.25 EVAL P DECOMP PJSM, CONTINUE RIH WITH HES CHAMP PACKER ON 2 7/8" TBG FROM DERRICK. -RIH FROM 6066' MD. TO 6577' MD. - OBTAIN PARAMETERS. PUW = 68K INCLUDING 40K TOP DRIVE WT. - SOW = 63K. SET 7 5/8" HES CHAMP PACKER AT 6572' MD. - POSITION FULL SLICK JT. ACROSS BOPE. INSTALL FOSV NEAR FLOOR. 14:00 - 14:30 0.50 EVAL P DECOMP SET 7 -5/8" HES CHAMP PACKER - WORK PACKER AT SET DEPTH OF 6572' MD - SET DOWN 5' & ROTATE 1.5 TURNS, PACKER SET, UP WEIGHT= 67 K, DOWN WEIGHT = 60 K - FILLANNULUS WITH 77 BBLS KWF PRIOR TO PT 14:30 - 16:00 1.50 EVAL P DECOMP PJSM, MIT -IA, 7 5/8" L -80 29.7 # CSG BY 2 -7/8" EUE ANNULUS. - CONFIRM VALVE ALLIGNMENT PRIOR TO TEST - PUMPED 22 STKS (1.8 BBLS) TO / 1,700 PSI FOR 30 CHARTED MINUTES. - DISCUSS W/ TOWN RWO ENGINEER. - MAINTAIN CONTINUOUS HOLE FILL DOWN TUBING THROUGH CHAMP PACKER WITH KWF DURING TEST. - MIT- IA TEST,_MEETS BP STP CRT -AK -10 CRITERIA - RECEIVED PERMISSION TO PROCEED FROM WtL. - BLEED OFF PRESSURE. " 0 " READING. ESTIMATE 1.5 BBLS BLED BACK - VERIFIY NO TRAPPED PRESSURE BELOW PACKER. - FILLED TBG WITH KWF. RELEASED CHAMP PACKER PER HES REP. - ALLOW PACKER ELEMENTS TO RELAX - MONITOR WELL FOR 10 MIN. WITH CONTINUOUS HOLE FILL. - SEE ATTACHMENT Printed 2/25/2013 10:19:21AM • , x, -, '„ k � ,, N "` ,:'.s.. Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) _ __Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date /Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 18:00 2.00 EVAL P DECOMP PJSM, RD TEST LINES AND CIRC. EQUIPMENT. - BLOW DOWN ALLASSOCIATED LINES. - POOH WITH 7 -5/8" HES CHAMP PACKER - STAND BACK 2 -7/8" TUBING - MAINTAIN CONTINUOUS HOLE FILL@ -25 BPH WITH KWF. 18:00 - 19:00 1.00 EVAL P DECOMP PJSM TO LAY DOWN CHAMP PACKER - UD 7 -5/8" CHAMP PACKER PER HES ALL ELEMENTS INTACT 19:00 - 20:00 1.00 EVAL P DECOMP PICKUP RUNNING TOOL - PULL WEAR RING - SET TEST PLUG - INSTALL DUTCH RISER' - CLEAN AND CLEAR RIG FLOOR 20:00 - 22:00 2.00 EVAL P DECOMP - SWS SLICKLINE ON LOCATION - SPOT SLICKLINE UNIT - BRING SLICKLINE BOPS, LUBRICATOR, ETC TO RIG FLOOR 22:00 - 00:00 2.00 EVAL _ P DECOMP PJSM W/ SLICKLINE AND RIG CREW ON RIG UP OF FULL PRESSURE CONTROLAND EQUIPMENT - RIG UP SLICKLINE PRESSURE CONTROL - M/U SLICKLINE EQUIPMENT a v. - MAINTAIN CONTINUOUS HOLE FILL@ -25 BPH WITH 8.5 PPG SEAWATER - 560 BBLS KWF LOST TO WELL IN 24 HRS. 2/13/2013 00:00 - 02:00 2.00 EVAL P DECOMP RIG UP SWS SLICKLINE WITH FULL PRESSURE CONTROL - R/U SWS SLICKLINE PCE TO DUTCH RISER - PRESSURE TEST LUBRICATOR 250 PSI LOW AND 1700 PSI HIGH FOR 5 MINS EACH TEST - P/U LUBRICATOR ASSEMBLY AND REMOVE TEST PLUG - RE- INSTALL DUTCH RISER SYSTEM 02:00 - 03:00 1.00 EVAL P DECOMP MAKE UP PDS 40 ARM CALIPER - SURFACE TEST CALIPER - REPROGRAM CALIPER - MAKE BACK UP CALIPER AND STAB ON LUBRICATOR, TEST BREAK AT QUICK TEST SUB 03:00 - 04:00 1.00 EVAL N DFAL DECOMP RUN IN HOLE WITH PDS CALIPER - RIH W/ CALIPER ON SWS SLICKLINE TO 1050' MD - LOG UP FROM 1050' MD WITH PDS 40 ARM CALIPER 04:00 - 04:30 0.50 EVAL N DEAL DECOMP AT SURFACE WITH PDS CALIPER - WAIT 5 MINS TO ALLOW CALIPER ARMS TO CLOSE BEFORE PULLING TOOL TO FLOOR - WAIT FOR GOOD DATA 04:30 - 06:00 1.50 EVAL N DFAL DECOMP CALIPER DATA NOT GOOD - REPROGRAM CALIPER - MAKE UP CALIPER - RIH W/ CALIPER ON SLICKLINE TO 1050' MD - LOG UP FROM 1050' MD TO SURFACE CONTINUOUS HOLE FILL @ -25 BPH WITH 8.5 PPG SEAWATER Printed 2/25/2013 10:19:21AM • r...* �"":�'"�3 ,,r ��. tx. �,.. k�r, "�;K�.��.i'3�,......`�.�cu,;s. m.. 3�, �:i:?�..' �t `.�.:x�'��'�.�F`.,,.,._.:a.., ..i=Erx. _ a•.... �:, �. s. «er.,.s,�Stf,��:.3'�`�"�: _�',drta,. a�'a�° Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 08:00 2.00 EVAL P DECOMP PJSM, REPROGRAM / REASSEMBLE CALIPER. SURFACE TEST PDS CALIPER EQUIPMENT. - RIH W/ CALIPER ON SWS SLICKLINE TO 1050' MD - LOG UP FROM 1050' MD WITH PDS 40 ARM CALIPER. - PDS REP DISCUSSED GOOD DATA CAPTURE WITH WSL. 08:00 - 09:30 1.50 EVAL P DECOMP PJSM, RIG DOWN SWS EQUIPMENT. PRESSURE CONTROL. - RIG DOWN / LD SWS TOOLS, LUBRICATOR, AND DUTCH RISER SYSTEM. - PULL WEAR RING. 09:30 - 10:00 0.50 RUNCOM P RUNCMP PJSM, HANG ESP SHEAVE IN DERRICK. - MOBILIZE CANNON CLAMPS TO RIG FLOOR. " Y - R/U TO RUN ESP COMPLETION. 10:00 - 11:30 1.50 RUNCOM P RUNCMP PICKUP BAKER, ESP ASSEMBLY. - MAKE UP SENSOR, MOTOR, UPPER AND LOWER TANDEM SEALS, GAS SEPARATOR AND 140P10 PUMP. - SERVICE PUMP AND MOTOR. 11:30 - 12:30 1.00 RUNCOM P RUNCMP LOAD HEAT TRACE AND ESP SPOOLS INTO SPOOLING UNIT. . - SERVICE RIG. INSPECT EQUIPMENT - FLUID LOST TO WELL= 265 BBL 12:30 - 14:30 2.00 RUNCOM P RUNCMP INSTALL DISCHARGE HEAD ON PUMP. - PULL ESP AND HEAT TRACE CABLES OVER SHEAVES. - ATTACH ESP CABLE TO MOTOR AND TEST. INSTALL PROTECTORS 14:30 - 19:30 5.00 RUNCOM P RUNCMP RIH WITH ESP ASSEMBLY ON 2 -7/8" 6.5 PPF L -80, EUE, 8RD TUBING - INSTALL CABLE CLAMPS ON EVERY OTHER JOINT PER PROGRAM. - TEST CONDUCTIVITY OF ESP CABLE EVERY 2000' - FLUSH TUBING & PUMP EVERY 2000' WITH 5 BBLS KWF @ 0.75 BPM AND 1700 PSI 19:30 - 00:00 4.50 RUNCOM P RUNCMP BEGIN RUNNING HEAT TRACE - RUN HEAT TRACE FROM SPOOLING UNIT OVER SHEAVE TO RIG FLOOR - INSTALL HEAT TRACE IN MIDDLE OF JOINT #113 @ -2954' MD CONTINUOUS HOLE FILL @ -25 BPH WITH 8.5 PPG SEAWATER FLUID LOST TO WELL IN 24 HRS = 537 BBL Printed 2/25/2013 10:19:21AM • 4 ss ' a W u >., u.x.'r_. Yk: u°ic `xs e "s'� + TH.' . u1.., +. a a. L , >a.`. r Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING @69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/14/2013 00:00 - 07:00 7.00 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND CRITICAL EQUIPMENT CHECKS RIH WITH ESP ASSEMBLY & HEAT TRACE ON 2 -7/8" 6.5 PPF L -80, EUE, 8RD TUBING - CONTINUE IN HOLE FROM 4400' MD (65k DOWN) - INSTALL CABLE CLAMPS ON EVERY OTHER JOINT PER PROGRAM. - TEST CONDUCTIVITY OF ESP CABLE EVERY 2000' - FLUSH TUBING & PUMP EVERY 2000' WITH 5 BBLS KWF @ 0.75 BPM AND 1700 PSI CANNON CLAMPS = 70. 2' HEAT TRACE = 22. 5' HEAT TRACE = 481 - FLAT GUARDS = 2. PROTECTALIZERS = 4. SENT AOGCC BOP TEST NOTICE FOR MP H -19 AT 0445 AM, AUTO RESPONSE RECIEVED AT 0451AM 07:00 - 09:00 2.00 RUNCOM P RUNCMP PJSM, TERMINATE HEAT TRACE AND ESP CABLE. - INSTALL PENETRATORS IN HANGER - TERMINATE ESP CABLE AND HEAT TRACE TO PENETRATOR WHDTRE - 09:30 0.50 WHSUR P HDTRE MAKE UP FMC 2 7/8" x 11" HANGER - -Will EUE LANDING JOINT W/ FOSV TO HANGER 09:30 - 10:00 0.50 WHSUR P WHDTRE PJSM, LANDING 11`" TBG HANGER.fMC RFP, WSL, CENTRALIFT REP IN ATTENDANCE. - LAND HANGER PER FMC REP - PU WT = 80K, SOW= 75K. INCLUDING 40K TOP DRIVE WT. - HANGER SET AT 6604' MD. - RUN IN LOCK DOWN SCREWS PER FMC REP. LD LANDING JOINT. 10:00 - 11:00 1.00 WHSUR P WHDTRE PJSM INNSTALLAND TEST TWC - ATTEMPT ROLLING TEST FROM BELOW TWC. - PUMPED 88 BBL AT 8 BPM TO ATTAIN 250 PSI - PUMPED 108 BBL AT 8 BPM. PRESSURED UP TO 325. STOP PUMPING. - TEST TWC FROM ABOVE, 250 / 3500 PSI FOR 5 CHARTED MIN. PASSED. - BLEED OFF PRESSURE. BLOW DOWN LINES. 11:00 - 12:00 1.00 WHSUR P WHDTRE PJSM, NIPPLE DOWN BOP. - NIPPLE DOWN BOP RISER AND FLOW LINE 12:00 - 15:30 3.50 RUNCOM P RUNCMP NIPPLE UP TREE. - NIPPLE UP 11 "X 2- 9/16" ADAPTER AND TREE. - THE DRILL SITE MAINTENANCE CREW WITNESSED THE ALIGNMENT OF THE WING VALVES TO THE 'S' RISER. 15:30 - 16:30 1.00 RUNCOM P RUNCMP - CENTRALIFT MADE FINAL CHECKS ON HEAT TRACE / ESP. - TEST VOID, ADAPTER FLANGE, TREE TO 250 / 5000 PSI. FOR 5 CHARTED MIN. EACH. PASSED. - FMC REP, WSL, TOOL PUSHER WNESSED. Printed 2/25 /2013 10:19:21AM • • 4; x�,. �� North � Arneti�: � ,4 Operation Summary Report. ` Common Well Name: MPI -19 AFE No Event Type: WORKOVER (WO) Start Date: 2/10/2013 End Date: 2/14/2013 X4- 00X6C- E:DRILL (1,780,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name /No.: DOYON 16 Spud Date /Time: 8/28/2004 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: ORIG KELLY BUSHING t 69.1ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 19:00 2.50 WHSUR P WHDTRE PJSM, PU DSM LUBRICATOR AND RU TO TEST. - TEST DSM LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. - PULL TWC. - TEST LUBRICATOR TO 250 / 3500 FOR 5 CHARTED MIN. EACH. - INSTALL 2" TYPE 'H' BPV. LD LUBRICATOR PER DSM REPS. 19:00 - 20:30 1.50 WHSUR P WHDTRE PERFORM ROLLING TEST FROM BELOW BPV - LINE UP SECONDARY KILL LINE - PUMP 9 BPM AND REACH 500 PSI. 0 PRESSURE ON TREE, CHART FOR 10 MINS 20:30 - 22:30 2.00 WHSUR P WHDTRE SECURE TREE AND CELLAR - BLOW DOWN & RIG DOWN LINES - INSTALL FLANGE AND PRESSURE GAUGE ON ANNULUS - CLEAN PITS - RIG DOWN MUD MANIFOLD, PREP FOR RIG MOVE, BRIDLE UP 22:30 - 00:00 1.50 WHSUR _ P WHDTRE - PJSM FOR DERRICK OVER - BRIDLE UP AND LAY DERRICK OVER - PJSM FOR RIG MOVE OFF OF MPI -19 - NOTIFY PAD OPERATOR - DOYON SUPERINTENDANT, NIGHT TOOLPUSHER & NIGHT WSL ON LOCATION - PULL OFF OF MP 1 -19 AND MOVE TO MP H PAD - 393 BBLS OF 8.5 PPG SEAWATER LOST - RELEASE RIG AT 2400 HRS FOR MOVE TO MPH -19. Printed 2/25/2013 10:19:21AM Tree: 2- 9/16" - 5M FMC rig. DF elev. = 69.10' (Doyon 14) Wellhead: 11" x 11" 5M FM • M PI -1 9/L 1 rig. GL elev. = 24.80` (Doyon 14) Gen 5, w 2 -7/8" FMC Tbg. 2 -7/8" EU 8rd on t &b, 2.5" CIW -H BPV Profile j Casing tested to 1700 psi from 6572' during 2/13/13 RWO. 20 ", 92 # /ft, H -40 I 112' 1 p Camco 2 -7/8" x1" i "Note" , KBMM -2 Gas lift mandrel 142' 10 3/4" 45.5 ppf L -80 & K -55 BTC -M : 0 (Drift ID = 10.050, cap. = .0981 bpf) 0 Collapse / Internal Yield '0 K -55 2090 psi. / 3580 psi. 0 L -80 2480 psi. / 5210 psi. ' 0 K-55 161' thru 2,879' 'v 10 3/4" Howco Float Shoe I 2999' I Al Centrilift Heat Trace to 2954' KOP © 300' 50+ degree from 2500' Camco 2 -7/8" x1" 6,361' Max hole angle = 75 degrees @ 6450' MD KBMG Gas lift mandrel HES 2 -7/8" XN- Nipple (2.250" id) 6,512' II 2 -7/8" 6.5 ppf, L -80 8rd eue tbg. — Centrilift Pump ( drift id = 2.347" cap = .00592 bpf) II 140 - P10 PMSXD 6,555' 7 5/8" 29.7 ppf, L -80, BTC -M casing ■ ® Centrilift Gas Separator (Drift ID = 6.750 ", cap = 0.0459 bpf) GRSFTX AR H6 6,573` AK it Centrilift Tandem Seal section 6 578' GSD3DB UT /LT SB /SB PFSA Centrilift Motor (rerated) MSP1 6,592` an 60 HP / 2050 volt / 18 amps. MI WellLift MGU Gauge w/6 fin centralizer 6,600' ti Gauge TVD = 3843' Baker HRD ZXP Liner 1 7144' I Top Packer LEM sleeve (Internal 18092' 1 7174' x4.00 "GSFN) Baker LEM #1, 4 -1/2" x 7187' 7 -5/8" 13CR Window in 75/8" Casing © 7,192' - 7,204' Well Angle @ window = 72° 4 - 1/2" Hook Hanger inside casing 7,187' 6 3/4" Hole td @ 12,225` Btm Baker Float Shoe 12,198' outside hook point 7,204'' 118 jts. - 4 1/2" /2" Slotted Liner """ 1 jts, 12.6# L -80 IBT OA Lateral —u •...... Baker Tie Back Sleeve 7,315' ----• •= XN Nipple 2 -7/8 ", 2.323" 7263` Baker ZXP Liner Top Packer 7,326' Pkg Bore Baker HMC Liner Hgr 7,332' Baker Seal bore ext. 7,340' L -1 Non locating Seal Assy. 7310' / 6 3/4" Hole td @ 9720' Btm HES Type V Float Shoe 9720' 7 -5/8" Weatherford Float Collar 7344' ■ mow- 7-5/8" Weatherford Float Shoe 7428' 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L -80 IBT OB Lateral . . DATE REV. BY COMMENTS MILNE POINT UNIT 09/13/04 MDO Drilled & Completed Doyon 14 WELL I -19 02/12/05 MDO ESP RWO Nabors - 4ES 10/17/08 REH ESP RWO/ Install LEM API NO: 50 - 029 - 23218 - 01/09/10 LH ESP RWO - 4ES post lateral FCO 50 - 23218 - 02/13/13 LH ESP RWO - Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 A D F B 1 7 ZWZ Mr. Tom Maunder 1 Alaska Oil and Gas Conservation Commission 6 i 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD It API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 162 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 ^ MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 • STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS RECEIVED FHB 0 3 2010 wi...Le Ail ~ rye f'A11R CnmrrNQSlnn 1. Operations Performed: hAt'8Q@ IQ ~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ell ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Fill Clean Out, Run ESP Assembly 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number. BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-135 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23218-00-00 ° 7. Property Designation: 8. Well Name and Number: ADL 025906 MPI-19 ° 9. Field /Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured ~ 9720' feet true vertical \~ 4088' feet Plugs (measured) None Effective depth: measured 9720' feet Junk (measured) None true vertical 4088' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 2964' 10-3/4" 2999' 2550' 5210 2480 Intermediate Production 7395' 7-5/8" 7428' 4076' 6890 4790 Liner 2405' 4-1/2" 7315' - 9720' 4053' - 4088' 8430 7500 Perforation Depth: Measured Depth: Slotted: 7391' - 9591' ~~~ ~~.a ,~ ~..~ ~ i~7 True Vertical Depth: Slotted: 4070' - 4095' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 6597' 3842' Packers and SSSV (type, measured and true vertical depth): N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cleaned out to 10,900'. 12. Representative Daity Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressuro Tubing Pressure Prior to well operation: Subsequent to operation: 191 98 285 160 213 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service erations il R rt of Well O ® D y p a epo ® Well Schematic Diagram ~ Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca. 564-5444 ~ ~ NIA Printed Name Terris Hubble Title Drillin Technolo ist O Ph n 4628 Dato 564 /~~ Prepared By Narns/Numbet: u•J ~ T 564 4628 H l e o - Signature - erris e ubb Form 10-404 Revised 07/2009 R6DMS FEB 0 51010 c~~ ~ Z ~ Sr' I t? Submit Original Only • MPI-19 &MPI-19L1, Well History (Fill Cleanout) Date Summary Operations from 1 0105/09 - 1 1/05/09 (Pre-Rig and N-4ES Ops) Reported Previously (10-404 Dated 11!24109). That operation was to pull ESP and run workstring to prepare for coil tubing fill Cleanout. Subsequent work (post 11/05/09) reported below. 11/9/2009 ATTEMPT TO REMOVE BPV. UNABLE TO LATCH BPV, POSSIBLE ICE, APPLY HEAT. CONT TO ASSIST WELL SUPPORT TO REMOVE BPV. RAN KJ, 3.70" BELL GUIDE W/2.5" JUC (steel). PULL P-PRONG FROM PLUG BODY C~3 3,007' MD. RAN 4-1/2" OK-1, SET 1" BK-DGLV IN ST #1 C~k 2,514' MD. PULL PLUG BODY FROM X-NIPPLE C~3 3,007' MD. (empty) CONFIRM VALVE IS SET. WELL LEFT S/I ON DEP. BPV LEFT OUT, NOT INSTALLED. JOB COMPLETE. 12/2/2009 MIRU. RIH w / 4" GS & jars. Latch isolation sleeve 5 k over pull sat down -10k twice no over pull. POOH. 12/3/2009 Confirmed we retrieved isolation sleeve. RIH & set L1 Diverter dual key 7193'. POOH. Make up FCO BHA. RIH and drift through diverter at 7193' 2x before continuing in hole and soft tagging fill at 9285. PUH to 7100, begin pumping 1 % KCL at 1 bpm and N2 at 500 scfs. Heat up wellbore and allow return rates to stabilize before running 1 `v in hole and performing FCO. Start FCO at 7200, pumping 5bbl geo-vis sweeps and taking 50 ft bites as gel reaches ' or , continue clean out. nozzle. At 8100 ~ 12/4/2009 Cleaned out to 9800', starting to have trouble getting weight in hole. 12/5/2009 POOH, unable to get weight on bottom at 10039'. POOH to make up agitator tool. At surface, perform weekly BOP test, inspect chains, change out pack offs and reel swivel. Make up BHA to include 2 1/8" hycalog agitator. RBIH pumping 5bbl sweep across the diverter. On bottom good weight transfer with the agitator. RIH to 10150 and pumping 8bbl geo-vis sweeps while cleaning out 50 ft intervals. 12/6/2009 POOH, agitator is acting like it is getting weak and we're not getting good weight transfer. Stack negative 12 k down. Clean out to final depth of 10,900' MD. POH. Make up and RIH with GS spear. Latch on to and pull diverter out of hole. At surface break down diverter and make up isolation sleeve and iso sleeve setting assembly. RIH and set iso sleeve at 7195'. POOH. At surface, make up OB lateral FCO BHA w/ 2.0" JSN. RIH tagged ~ 7227' start clean out. , 12/7/2009 f;nntinue clean out. Clean out to 9702' (ctm uo). POOH and make up isolation sleeve retrieval bha (4" GS) and RBIH. Tag up at 7167' ctmd and latch isolation sleeve. POH pumping McOH down the backside. Freeze protected well w / 50 bbls of 60/40 Methanol. Isolation sleeve has been recovered. RDMO. Job complete. 1/4/2010 WELLS/I ON ARRIVAL. R/U SLICKLINE EQUIPMENT FOR RIG PREP. / 1/5/2010 MAKE STOPS C~ 7133' SLM FOR 3 HRS, AND 6633' SLM FOR 30 MIN. SET SLIP STOP CATCHER ~ 2970' i~ SLM. PULL DGLV FROM 2514' MD. POCKET LEFT EMPTY. PULL SLIP STOP CATCHER FROM 2970' SLM. ~GSf" SET BPV. WELL S/I ON DEPART. DSO NOTIFIED. R.~ 3 SL w°r~ Page 1 of 1 • BP EXPLORATION Page 1 of 4 Operations. Summary Report. Legal Well Name: MPI-19 Common Well Name: MPI-19 Event Name: WORKOVER 'Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From.- To Hours i Task Code NPT 1/6/2010 101:00 - 07:00 I 6.001 MOB I P 07:00 - 10:30 3.50 MOB P 10:30 - 14:15 3.75 RIGU P 14:15 - 16:00 1.751 RIGU P 16:00 - 18:00 2.00 RIGU P 18:00 - 20:00 2.00 RIGU P 20:00 - 20:15 0.25 RIGU P 20:15 - 21:00 0.75 RIGU P 21:00 - 22:10 1.171 KILL P 22:10 - 23:40 1.501 KILL P 23:40 - 00:00 0.33 KILL P 1/7/2010 00:00 - 00:45 0.75 WHSUR 00:45 - 01:00 0.25 WHSUR 01:00 - 03:20 2.33 WHSUR 03:20 - 03:35 0.25 BOPSU 03:35 - 05:30 1.92 BOPSU 05:30 - 06:00 0.50 06:00 - 11:30 5.50 11:30 - 11:45 0.251 BOPSU Start: 1 /4/2010 Rig Release: 1/10/2010 Rig Number: 4ES Spud Date: 8/28/2004 End: Phase Description of Operations PRE RDMO TO MPI-19 BLOW DOWN LINES LOWER DERRICK MOVE PITS & PIPE SHED PREP UNITS TO MOVE FROM E PAD PRE MOVE FROM MPE PAD TO MPI PAD PRE SPOT SUB OVER MPI-19 WELL SPOT PITS & PIPE SHED ALLIGNED TO SUB PRE RAISE & SCOPE UP DERRICK =ACCEPT RIG ~ 16:00 HRS= PRE CREW CHANGE & HANDOVER PRE TOUR MEETING TO DISCUSS DAYS OPERATIONS PRE RIG UP LUBRICATOR PT TO 500 PSI & PULL BPV PRE PJSM TO RIG UP TO BULLHEAD & KILL WELL PRE RU TO BULLHEAD WELL CONNECT LINES TO TIGER TANK & TEST CHECK WELL FOR PRESSURE, 340 PSI ON WELL CALL MPU RADIO &MPI PAD OPERATOR TO INFORM THEM WE ARE GOING TO BE VENTING GAS POST GAS VENTING SIGNS DECOMP STARTING PSI - T= 340 PSI, IA= 0, OA= 50 PSI DISPLACE WELL BY PUMPING HEATED 8.45 PPG SEAWATER DOWN IA & UP TUBING THROUGH THE GLM ~ 2,514' TO FLUSH FREEZE PROTECT FROM WELL, PUMPED 104 BBLS AS PLANNED & CHECKED RETURN DIESEL STILL VERY EVIDENT IN FLUID CONTINUED TO PUMP UNTIL DIESEL WAS GONE, PUMPED 176 BBLS TOTAL. DECOMP BULL HEAD WELL BY PUMPING 170 BBLS OF HEATED. SEAWATER DOWN TUBING FLOW CHECKED-WELL WELL ON A VAC ENDING PSI - T= 0, IA= 0, OA= 480 PSI BLED OA TO 0 PSI DECOMP PJSM TO INST TWC DECOMP INSTALL TWC PT & CHART TWC ATTEMPT TO TEST FROM BOTTOM CHARTED 50 PSI ~ 3 BPM 3,500 PSI FROM TOP FOR 10 MIN DECOMP PJSM TO ND TREE DECOMP BLEED VOID IN TREE ND TREE DECOMP PJSM TO NU BOPE DECOMP CALLED AOGCC SPOKE WITH BOB HE NEEDS 1 HOUR NOTICE TO WITNESS PT ON BOPE (-FEEDING WELL 20 BPH OF SEA WATER-) DECOMP CREW CHANGE OUT PREJOB TO PT ROPE DECOMP PT BOPE 250 PSI LOW / 3,500 PSI HIGH DECOMP PJSM TO INSTALL DUTCH RISER rmueu. ucuicu iu ic.uv.~<rm • • BP EXPLORATION Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Event Name: WORKOVER Start: 1/4/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/10/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Page2of4 Spud Date: 8/28/2004 End: Date ~ From - To Hours ' Task Code- NPT Phase Description of Operations. 1/7/2011:45 - 12:30 0.75 BOPSU DECOMP I A L D TCH RIS R 12:30 - 12:45 0.25 BOPSU DECOMP PJSM TO PULL TWC & LD DUTCH RISER 12:45 - 14:00 1.25 BOPSU DECOMP RU LUBRICATOR & PT TO 500 PSI PULL TWC LD DUTCH RISER 14:00 - 14:15 0.25 BOPSU DECOMP PJSM TO MU LANDING JT & BOLDS 14:15 - 15:00 0.75 BOPSU DECOMP MU LANDING JT & BOLDS 15:00 - 15:15 0.25 BOPSU DECOMP PJSM TO PULL HANGER & LD SAME 15:15 - 16:00 0.75 BOPSU DECOMP PULL HANGER ~ 30K PULL OUT OF SEALS ~ 65K = 5K OVER LD LANDING JT 16:00 - 16:15 0.25 PULL DECOMP PJSM TO PUMP FLUID & CLEAR RIG FLOOR 16:15 - 17:00 0.75 PULL DECOMP PUMP 150 BBL OF SEA WATER DOWN TUBING, 4 BPM ~ _ 70 PSI CLEAR RIG FLOOR 17:00 - 17:30 0.50 PULL DECOMP RD CEMENT LINES FROM IA 17:30 - 18:00 0.50 PULL DECOMP PRE TOUR MEETING WITH ONCOMING CREW PJSM TO RU TO PULL 4.5" TUBING STRING 18:00 - 19:15 1.25 PULL DECOMP RU FLOOR TO PULL 4.5" TUBING 19:15 - 19:30 0.25 PULL DECOMP PJSM TO PULL 4.5" TUBING FROM WELL 19:30 - 00:00 4.50 PULL DECOMP PULL & LD 4.5" TBG PULLED 105 JTS ~ 00:00 1/8/2010 00:00 - 03:00 3.00 PULL DECOMP CONTINUE TO PULL 4.5" TBG 03:00 - 03:15 0.25 PULL DECOMP PJSM TO CLEAR RIG FLOOR FROM PULLING 4.5" TBG 03:15 - 03:45 0.50 PULL DECOMP CLEAR RIG FLOOR 03:45 - 04:00 0.25 BUNCO RUNCMP PJSM TO RU FLOOR TO SERVICE ESP PUMP ASSEMBLY & PU ESP '~, 04:00 - 04:30 0.50 BUNCO RUNCMP RU FLOOR TO SERVICE ESP PUMP ASSEMBLY PU ESP PUMP ASSEMBLY 04:30 - 06:00 1.50 BUNCO RUNCMP INSPECT & SERVICE ESP PUMP ASSEMBLY 06:00 - 06:15 0.25 BUNCO RUNCMP CHECK 6 HELD A SHORT 15 MINUTE MEETING W/CREW AFTER PTSM - DISCUSSED AAR'S, PURPOSE AND IMPLEMENTATION. 06:15 - 07:00 0.75 BUNCO RUNCMP PULL ESP OVER SHEAVE, 07:00 - 07:15 0.25 BUNCO RUNCMP PJSM TO SECURE ESP, MU XN-NIPPLE, & TEST ESP CABLE 07:15 - 08:30 1.25 BUNCO RUNCMP ATTACH, MAKE MASTER SPLICE & SECURE ESP MU PUPS & XN-NIPPLE TEST ESP CABLE 08:30 - 08:45 0.25 BUNCO RUNCMP PJSM TO RIH WITH 2-7/8" ESP COMPLETION 08:45 - 13:00 4.25 BUNCO RUNCMP RIH WITH 2-7/8" ESP COMPLETION FLUSH PUMP (~ 2,000' W/ 800 PSI 13:00 - 17:00 4.00 BUNCO RUNCMP PULL HEAT TRACE OVER SHEAVE & ATTACH TO JT# 104 PINCHED ESP ARMOR WITH AIR SLIPS CUT & SPLICED ESP ~ 3,260' REPLACED AIR SLIPS 17:00 - 17:30 0.50 BUNCO RUNCMP RIH WITH 2-7/8" ESP COMPLETION CLAMPS CRIMPING ESP CABLE PULL CLAMP & TEST ESP TEST GOOD 17:30 - 18:45 1.25 BUNCO RUNCMP PTSM & CREW CHANGE OUT 18:45 - 20:00 1.25 BUNCO RUNCMP CHECK 6 HELD 60 MINUTE MEETING WITH CREW TO Printed: 1/25/2010 12:04:52 PM BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Event Name: WORKOVER 'Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT 1/8/2010 18:45 - 20:00 1.25 BUNCO 20:00 - 00:00 ~ 4.00 ~ RUNC01~1 1/9/2010 100:00 - 06:00 ~ 6.00 06:00 - 07:00 ~ 1.00 Spud Date: 8/28/2004 Start: 1 /4/2010 End: I Rig Release: 1/10/2010 Rig Number: 4ES Phase Description of Operations RUNCMP DISCUSS AAR'S, PURPOSE & IMPLEMENTATION PJSM TO RUN 2-7/8" ESP COMPLETION RUNCMP RIH WITH 2-7/8" COMPLETION USING FLAT GUARDS & BANDS DUE TO CLAMPS CRIMPING ESP CABLE 2-7/8" MU TO 2,300# ON JT# 108 AT MIDNIGHT RUNCMP CONTINUE TO RIH WITH 2-7/8" ESP COMPLETION WITH 2,300# MU TO FROM JT# 109 TO JT# 134 AT 06:00 HEAT TRACE & ESP CONNECTED WITH FLAT GUARDS & STRAPS RUNCMP CHECK 6 HELD ROUNDTABLE DISCUSSION WITH RIG LEADERSHIP DISCUSSED ASSESSMENT, LEADERSHIP TRAITS, AND STANDARDIZATION OF BRIEFING AND PLANNING PROCESSES. BOTH DAY AND NIGHT DRILLERS, TOOLPUSHERS AND WELL SITE LEADERS PARTICIPATED. RIG CREW HELD PJSM SERVICED RIG AND PERFORMED ENVIROMENTAL WALKAROUND 07:00 - 07:45 0.75 BUNCO RUNCMP CHECK 6 HELD 30 MINUTE MEETING WITH CREW TO DISCUSS PLANNING AND BRIEFING, PURPOSE & IMPLEMENTATION PJSM TO RUN 2-7/8" ESP COMPLETION 07:45 - 17:30 9.75 BUNCO RUNCMP CONTINUE TO RIH WITH 2-7/8" ESP COMPLETION HEAT TRACE AND ESP CABLE CONNECTED WITH FLAT GUARDS AND STEEL BANDS JT# 185 AT 16:00 OUTDOOR ACTIVITY AND FORKLIFT OPPERATIONS ARE LIMITED DUE TO COLD WEATHER 17:30 - 18:15 0.75 BUNCO P RUNCMP PTSM WITH CREW TO DISCUSS PLAN FORWARD FOR TOUR'S OPERATIONS CREW CHANGE OUT 18:15 - 18:45 0.50 BUNCO RUNCMP CHECK 6 HELD 30 MINUTE MEETING TO DISCUSS LEADERSHIP ROLES &PRE-PLANNING OBJECTIVES WITH CREW 18:45 - 19:00 0.25 BUNCO RUNCMP PJSM TO RIH WITH 2-7/8" ESP COMPLETION 19:00 - 20:15 1.25 BUNCO P RUNCMP RIH WITH 2-7/8" ESP COMPLETION HEAT TRACE & ESP CABLE CONNECTED WITH FLAT BARS & STEEL BANDS TOTAL BARS 523 EA - 6' 8EA-4' 8EA-2' 1,664 -BANDS 57 - LASALLE CLAMPS OUTDOOR ACTIVITY AND FORKLIFT OPPERATIONS ARE LIMITED DUE TO COLD WEATHER rnncea: ucoicui~ ic:w:oc rm • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 1/4/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/10/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours "f Task Code NPT Phase ` Description of Operations 1/9/2010 20:15 - 20:25 0.17 BUNCO RUNCMP PJSM TO MU LANDING JT & COMPLETE PENETRATOR SPLICE 20:25 - 21:00 0.58 BUNCO RUNCMP MU LANDING JT TO HANGER 21:00 - 00:00 3.00 BUNCO RUNCMP MU PENETRATOR SPLICE 1/10/2010 00:00 - 00:45 0.75 BUNCO RUNCMP MU PENETRATOR SPLICE 00:45 - 02:20 1.58 BUNCO RUNCMP 02:20 - 02:30 02:30 - 04:30 04:30 - 06:00 06:00 - 07:00 0.17 BOPSU P 2.00 BOPSU P 1.50 WHSUR P 1.00 WHSUR P 07:00 - 07:30 ~ 0.501 WHSUR ~ P 07:30 - 07:40 0.171 WHSUR ~ P 07:40 - 08:30 0.83 ~ WHSUR ~ P 08:30 - 09:00 0.50 WHSUR P 09:00 - 10:00 1.00 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 12:00 I 1.001 WHSUR I P TEST TWC 3,500 PSI FROM TOP FOR 10 MINUTES 200 PSI FOR 10 MINUTES FROM BOTTOM PUMPED AWAY 50 BBLS ~ SBPM DURING TEST POST PJSM TO BLOW DOWN LINES & ND BOPE POST BLOW DOWN LINES & ND BOPE POST NU 2-9/16" TREE ON WELL MPI-19 POST CHECK 6 HELD 30 MINUTE MEETING WITH CREW TO DISCUSS BRIEFING, PURPOSE & IMPLEMENTATION DEVELOPED AND IMPLIMENTED A NEW PTSM FORMAT FOR RIG CREW TO TRY. PTSM WITH CREW USING NEW FORMAT AND HELD SHORT AAR ON THE NEW FORMATWITH POSSIBLE SUGGESTIONS TO IMPROVE ON IT. POST PT TREE TO 5 000 PSI FOR 5 MINUTES. . CENTRILIFT PERFORMED FINAL CHECKS ON ESP AND HEAT TRACE -GOOD TESTS. POST PJSM WITH CREW AND WELL SUPPORT TO RU LUBRICATOR & TEST, PULL TWC, AND INSTALL BPV. POST RU LUBRICATOR AND TEST WITH DIESEL TO 500 PSI. PULL TWC AND INSTALL BPV. LD LUBRICATOR. POST SECURE WELL AND CELLAR. POST HELD AAR FOR MPI-19 WITH DAY TOUR. POST HELD WEEKLY SAFETY MEETING WITH NABOBS MANAGEMENT. DISCUSSED WEATHER RELATED ISSUES AND SET GOALS FOR UPCOMMING YEAR. POST ASSISTED LITTLE RED WITH FREEZE PROTECTING WELL WHILE WAITING FOR TRUCKS. TESTED LINES TO 2500 PSI PUMPED 15 BBLS CRUDE ~ -1 BPM AND 1950 PSI DOWN THE TBG. PUMPED 65 BBLS CRUDE ~ -1.5 BPM AND 400 PSI GOWN THE IA. ***RELEASED RIG AT 12:00*** WAITING ON WEATHER FOR TRUCKS. -37 F AMBIENT AT MPI PAD. -46 F AMBIENT AT DEADHORSE AIRPORT. NfIf1I80: 1/G5/LUIU 1L:U4:5L YM Tree: 2-9/16" - 5M FMC (~ Ori elev. = 69.10' (Doyon 14) Wellhead: 11" x 11" 5M FMC ~ M P I- ~ J Ori elev. = 24.80' (Doyon 14) Gen 5, w 2-7/8" FMC Tbg. 2-7/8" EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 11 12' I Camco 2-7/8" xi" "NOt@" KBMM-2 Gas lift mandrel 137' 10 3/4" 45:5 ppf L-80 & K-55 BTC-M (Drift ID = 1`0:050, cap..= .0981 bpf) Collapse / Internal Yield K-55 2090psi. / 3580 psi. L-80 2480-psi. / .5210 psi:. K-55 161'-thru 2,879' i 10 3/4" Howco Float Shoe 2999' Heat Trace to 3297` KOP @ 300' 50+ degree from 2500' Camco 2-7/8" x1" 6,386' Max hole angle = 75 degrees @ 6450' MD KBMG Gas lift mandrel 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) 7 5/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) Window in 75/8" Casing @ 7,192' - 7,204' Well Angle @ window = 72° 4-1/2" Hook Hanger inside casing 7,187' outside hook point 7,204' Baker Tie Back Sleeve 7,315' Baker ZXP Liner Top Packer 7,326' Baker HMC Liner Hgr 7,332' Baker Seal bore ext. 7,340' HES 2-7/8" XN-Nipple (2.205" id) 6,529` Tandem Centrilift Pump 141-P6 SXD Pump 6,545` 18-P75 SSD Pump Tandem Centrilift (400 Internals) Intake 6 563` GRSFTX AR H6 , Centrilift Tandem Seal section 6 568` GSB3D6 UT/LT , Centrilift Motor (rerated) 83 hp / KMHA 582` 6 2195 volt / 23 amps. , Phoenix PumpMate XTO Sensor 593` 6 w/6 fin centralizer , Baker HRD ZXP Liner 7144` Top Packer LEM sleeve (Internal 18092' 7174' x 4.00" GS FN) Baker LEM #1, 4-1/2" x 7187 7-5/8" 13CR 6 3/4" Hole td @ 12,225' Btm Baker Float Shoe 12,198' 118 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT OA Lateral XN Nipple 2-7/8", 2.323" 7263' Pkg Bore L-1 Non locating Seal Assy. 7310` 6 3/4" HOIe td @ 9720` Btm HES Type V Float Shoe 9720' 7-5/8" Weatherford Float Collar 7344' 7-5/8" Weatherford Float Shoe 7428' DATE REV. BY COMMENTS 09/13/04 MDO Drilled & Completed Doyon 14 02/12/05 MDO ESP RWO Nabors - 4ES 10/17/08 REH ESP RWO/ Install LEM 0/09/10 LH ESP RWO - 4ES after lateral FCO w/ CTU 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L-80 IBT OB Lateral MILNE POINT UNIT WELL I-19 BP EXPLORATION (AKl STATE OF ALASKA RECEIV ALA,*OIL AND GAS CONSERVATION COMMON NOV $3 0 2009 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Performed: A ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Fill Clean Out 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 204 -135 3. Address: ❑ Service ❑ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 '- 50 -029- 23218 -00-00 Property Designation: 18\Vell Name and Number: ADL 025906 MPI - 9. 'ekl / Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured ` 9720' feet true vertical 4088' feet Plugs (measured) None Effective depth: measured 9720' feet Junk (measured) None true vertical 4088' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 2964' 10 -3/4" 2999' 2550' 5210 2480 Intermediate Production 7395' 7 -5/8" 7428' 4076' 6890 4790 Liner 2405' 4-1/2" 7315'- 9720' 4053'- 4088' 8430 7500 E t: 200 9 Perforation Depth: Measured Depth: Slotted: 7391'- 9591' True Vertical Depth: Slotted: 4070'- 4095' Tubing (size, grade, measured and true vertical depth): Workstring: 4 -1/2 ", 12.6# L -80 7147' 4001' Packers and SSSV (type, measured and true vertical depth): N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pull ESP. Run Workstring so that coil can do a Fill Clean Out. (New ESP scheduled to be ran by N in January 2010.) 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 4. Well Class after work: ❑ Exploratory Development ❑ Service • Daily Report of Well Operations • Well Schematic Diagram Well Status after work: ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564 -5444 NIA Printed Name erne Hubble Title Drilling Technologist P �nt`t Signature Phone 564-4628 Date 2 fe�"'d By N�ne/Nmber u �9 Terrie Hubble, 564 -4628 Form 10-404 Revised 07/2009 A/ I ltlk Submit Original Onl MPI -19 & MPI -191-1, Well History (Pre Rig Workover) Date Summary 10/5/2009 WELL S/I ON ARRIVAL (Rig Prep). PULLED 1" BK -DGLV FROM ST #1 @ 6,416' MD. POCKET LEFT OPEN. PULLED 1" BEK -DPSOV FROM ST #3 @ 139' MD. SET 1" BK -DGLV IN ST #3 @ 139' MD. WELL LEFT S /I. TURN OVER TO DSO. JOB COMPLETE. 10/18/2009 WELL S/I ON ARRIVAL. R/U SLICKLINE EQUIPMENT TO RUN PRE -RWO SBHPS. 10/19/2009 INSTALLED BPV. 10/19/2009 RIH W/ 2.07" CENT, S.S, DUAL SPARTEK GAUGES. MADE 15 MINUTE STOP @ 6024' MD & 3 HOUR STOP 6524' MD. BPV IN HOLE. WELL LEFT S /I. I Page 1 of 1 BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPI -19 Common Well Name: MPI -19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 10/20/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/5/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 10/30/2009 06:00 - 07:30 1.50 RIGD P PRE UD DERRICK 07:30 - 08:30 1.00 RIGD P PRE HELD A.A.R. OF WELL MPI -04. 08:30 - 09:30 1.00 MOB P PRE MOVE PIPE SHED AND PITS OFF 1 -04. 09:30 - 10:30 1.00 MOB P PRE MOVE SUB OFF MPI -04. 10:30 - 12:00 1.50 MOB P PRE SPOT SUB OVER MPI -19 -SPOT PIPE SHED -SPOT PITS 12:00 - 14:00 2.00 RIGU P PRE RAISE DERRICK -R/U LINES. 14:00 - 16:00 2.00 RIGU P PRE R/U -KILL LINES -TIGER TANK LINES -TEST LINES TO 3,500 PSI -TAKE ON SEAWATER -RIG ACCEPTED AT 14:00 HRS 10/30/09. 16:00 - 17:00 1.00 WHSUR P WHDTRE BPV -R/U LURICATOR -TEST TO 500 PSI W / DIESEL -PULL BPV -UD LUBRICATOR 17:00 - 18:00 1.00 WHSUR P WHDTRE KILL WELL -PJSM -700 PSI TBG -700 IA -120 OA -BLEED OFF GAS TO 100 PSI 18:00 - 00:00 6.00 WHSUR WHDTRE KILL WELL BY PUMPING 120 DEGREE SEAWATER DOWN THE TUBING SET UP TO TAKE RETURNS OUT THE IA THROUGH THE CHOKE MANIFOLD TO THE TIGER TANK IF NEEDED. PUMP TUBING VOLUME OF 37 BBLS AT 3 BPM WITH 500 PSI. LINE UP AND BULLHEAD 37 BBLS AT 5 BPM WITH 300 -620 PSI. TOTAL PUMPED 7720 STKS , CONTINUE BULLHEAD @ 4BPM WITH 960 PSI. - MONITOR WELL. 10/31/2009 00:00 - 02:00 2.00 WHSUR WHDTRE PJSM - REVIEWED PROCEDURE TO SET AND TEST TWC WITH RIG CREW AND FMC PERSONNEL. -FMC WELLHEAD TECHNICAN SET TWC WITH DRY ROD. VERIFIED PROPER TRAVEL TO ENSURE 100% ENGAGEMENT OF TWC IN TUBING HANGER PROFILE. PRESSURE TESTED TWC FROM BELOW WITH INJECTIVITY TEST PUMPING AT 3 -BPM AT 75 -PSI. CHARTED TEST FOR 10MIN. - TESTED TOP TO 3500 PSI FOR 10 CHARTED MINUTES. 02:00 - 03 :30 1.50 WHSUR WHDTRE PJSM. RIG DOWN CIRCULATING LINES AND BLOW DOWN SAME. -ND PRODUCTION TREE, DRAIN SAME, WRAP WITH ABSORB AND SET OUTSIDE RIG CELLAR. - VISUALLY INSPECTED TUBING HANGER. 03:30 - 07:30 4.00 BOPSUF PRE N/U 13 -5/8 ", 5M BOP STACK WITH 2 -7/8 "X 5" VBR'S AND BLIND SHEAR RAMS. HOOK UP CHOKE AND KILL LINES, HOOK UP TURNBUCKLES AND INSTALL FLOW NIPPLE, HOOK UP KOOMEY LINES. Printed: 11/19/2009 11:38:19 AM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: MPI -19 Common Well Name: MPI -19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 10/20/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/5/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 10/31/2009 07:30 - 14:30 7.00 BOPSUF PRE TEST BOPE - FUNCTION TEST. -250 PSI LOW AND 3,500 PSI HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, -FLOOR VALVES, 2 -7/8" X 5" VBR'S, ANNULAR PREVENTER WITH 4 -1/2" TEST JOINT. -TEST 2-7/8'X 5" 'VBR'S WITH 2 -7/8" TEST JOINT. - ANNULAR PREVENTER FAILED TO TEST WITH 2 -7/8" TEST JOINT. -AOGCC WITNESS OF TEST WAS WAIVED BY CHUCK SCHEVE. - TESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. 14:30 - 22:00 7.50 BOPSUF N SFAL PRE REPLACE 13 -5/8" ANNULAR ELEMENT. -PJSM -N /D FLOW NIPPLE -N /D DUTCH SYSTEM - REMOVE ANNULAR CAP - REPLACED ANNULAR ELEMENT - INSTALLED ANNULAR CAP 22:00 - 22:30 0.50 BOPSUF N SFAL PRE RU DUTCH LUBRICATOR LOCK DOWN SYSTEM 22:30 - 00:00 1.50 BOPSUF P PRE CONTINUE BOPE TESTING - TESTING ANNULAR, 250 LOW AND 3500 HIGH. TEST GOOD -KOOMY TEST -AOGCC WITNESS OF TEST WAS WAIVED BY CHUCK SCHEVE, TESTING WITNESSED BY TOOL PUSHERS AND BP WSL. 11/1/2009 00:00 - 02:00 2.00 BOPSUF P PRE CONTINUE BOPE TESTING - TESTING ANNULAR, 250 LOW AND 3500 HIGH. TEST GOOD -KOOMY FUNCTION TEST -R/D TEST EQUIPMENT -AOGCC WITNESS OF TEST WAS WAIVED BY CHUCK SCHEVE, TESTING WITNESSED BY TOOL PUSHERS AND BP WSL. 02:00 - 04:30 2.50 PULL P DECOMP PU /MU & PRESSURE TEST LUBRICATOR TO 500 PSI W/ DIESEL FOR 5 MINUTES - GOOD TEST -PULL TWC. TBG ON VACUUM. -LD LUBRICATOR AND DUTCH LOCK DOWN SYSTEM -( 1 HR BACK FOR DAYLIGHT SAVINGS) 04:30 - 05:30 1.00 PULL P DECOMP PULL TBG HANGER. -FMC BACKED OUT LOCK DOWN SCREWS - PULLED 2 -7/8" TUBING HANGER -PULL OFF SEAT AT 39K AND 38K PUW. -BREAK OUT LAY DOWN HANGER 05:30 - 06:00 0.50 PULL P DECOMP PUMP A TBG VOLUME -40 BBL 8.45# SEAWATER 06:00 - 07:00 1.00 PULL P DECOMP R/U FLOOR TO PULL ESP / HEAT TRACE. 07:00 - 16:30 9.50 PULL P DECOMP PULL ESP /HEAT TRACE -135 JOINTS 2 -7/8" TBG UD. Printed: 11/19/2009 11:38:19 AM BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: MPI -19 Common Well Name: MPI -19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 10/20/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/5/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 11/1/2009 16:30 - 17:30 1.00 PULL P DECOMP WEEKLY SAFETY MEETING - REVIEWED NEW MAN RIDING POLICY. - REVIEWED SLOPE WIDE HSE INCIDENTS. 17:30 - 22:30 5.00 PULL P DECOMP PULL ESP -POH L/D 2 -7/8" TBG - RECOVERD. 451- 6' AND 1- 4', 30-3' FLAT GUARDS -1365 BANDS. 22:30 - 00:00 1.50 PULL P DECOMP BREAK OUT AND LAY DOWN ESP AND MOTOR - DETACH ESP CABLE FROM MOTOR. - SPOOLED UP CABLE INTO CABLE SPOOLER. - RECOVERED 5 PROTEC , 3 F/G 66 CLAMPS - RIGGED DOWN ELEPHANT TRUNK. 11/2/2009 00:00 - 02:30 2.50 CLEAN P DECOMP BREAK OUT AND LAY DOWN ESP AND MOTOR - DETACH ESP CABLE FROM MOTOR. - SPOOLED UP CABLE INTO CABLE SPOOLER. -R/D TUBING EQUIPMENT -CLEAN AND CLEAR RIG FLOOR 02:30 - 03:30 1.00 CLEAN P CLEAN RIG PREP TO RUN POLISH MILL ASSEMBLY -CLEAN AND CLEAR FLOOR - INSTALL WEAR RING 03:30 - 04:30 1.00 CLEAN P CLEAN NABORS WEEKLY SAFETY MEETING - REVIEWED NEW MAN RIDING POLICY. - REVIEWED SLOPE WIDE HSE INCIDENTS. - RECENT NABORS BP INCIDENTS - PERSONAL RESPONSIBILITY TO SAFETY 04:30 - 06:00 1.50 CLEAN P CLEAN PU /MU POLISHING MILL ASSEMBLY -BHA # 1 - 5.75" BAKER POLISH MILL, - 7 -5/8" CSG SCRAPER, 4 -3/4" BOOT BASKET (3) 4 -3/4" DC's -AS PER BAKER TOOL HAND 06:00 - 12:30 6.50 CLEAN P CLEAN -P /U 3 -1/2" DP FROM PIPE SHED. -RIH TO LINER TOP. 12:30 - 13:00 0.50 CLEAN P CLEAN POLISH RUN -LINER TOP = 7,134' MD -NO -GO = 7,144' MD -P /U KELLY, PUW = 74 (K), SOW = 52 (K), RT.WT = 63 (K). -RPM = 60, WOB = 0, TQ = 190 AMPS, 2 BPM / 300 PSI. - POLISH FROM 7,134' TO 7,144' MD - PUMPED -100 BBLS 13:00 - 16:30 3.50 CLEAN P CLEAN POH WITH POLISH MILL ASSEMBLY -PSJM -SET BACK KELLY -POH FROM 7,134' MD -STAND 3 -1/2" DP IN DERRICK. -FEED WELL W/ SEAWATER AT -20 BPH. 16:30 - 17:30 1.00 CLEAN P CLEAN BHA #1 -L/D BHA -NO GO COMFIRMS LINER TOP TAG. - SERVICE BOOT BASKET -NO RECOVERY IN BOOT BASKET 17:30 -18:00 0.50 CLEAN P CLEAN CLEAN AND CLEAR RIG FLOOR. Printed: 11/19/2009 11:38:19 AM i • BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPI -19 Common Well Name: MPI -19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 10/20/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/5/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/2/2009 18:00 - 23:00 5.00 CLEAN P CLEAN BHA #2 PU /MU 7 -5/8" FITTS AND SEAL ASSEMBLY -TIH W/ 3 -1/2" DP W/ 75 STANDS 23:00 - 00:00 1.00 CLEAN P CLEAN TAG LINER TOP AT 7134' -SET DOWN TO NO -GO 15' IN TO 7146', P/U 6', WITH 6' OF SEAL ASSEMBLY STILL STUNG IN. - FILLED HOLE W/42 BBLS 11/3/2009 00:00 - 03:00 3.00 CLEAN P CLEAN PRESSURE CASING UP TO 1,600 PSI. - PRESSURE BLEAD OFF IMMEDIATELY -CHECK ALL SURFACE EQUIPMENT. NO LEAKS DETECTED. - PULLED UP THEN TRIED TO RE- STING. - UNABLE TO PRESSURE UP OR FILL THE HOLE. -PU AND POSITION FITTS @ 7,116' MD, SET FITTS. -FILL HOLE W/ 30 BBLS OF SEAWATER. -TEST 7 -5/8" CSG FROM 7,116' MD TO SURFACE. -TEST TO 2,000 PSI FOR 30 MINUTES - GOOD TEST -TEST CHARTED TALKED WITH RWO ENGINEER IN TOWN ABOUT OPTIONS. DECISION WAS MADE TO RELEASE FITTS, MONITOR WELL POOH AND INSPECT SEALS 03:00 - 07:30 4.50 CLEAN P CLEAN RELEASE FITTS AND POH. -POOH W/ 7 -5/8" FITTS AND SEAL ASSEMBLY ON 3 -1/2" DP. -STAND BACK DP IN THE DERRICK. 07:30 - 09:00 1.50 CLEAN P CLEAN LD BHA #2 -RTTS AND SEAL ASSEMBLY. -CLEAN AND CLEAR RIG FLOOR. 09:00 - 09:30 0.50 CLEAN P CLEAN CONDUCT H2S DRILL. -RIG EVACUATION DRILL PERFORMED. 09:30 - 10:00 0.50 CLEAN P CLEAN PU & MU BHA #3. - 6 -1/8" BIT & BIT SUB. 10:00 - 12:00 2.00 CLEAN P CLEAN RIH W/ BHA #3. -RIH FROM DERRICK W/ 3 -1/2" DP. -RIH 55 STANDS. 12:00 - 13:30 1.50 CLEAN P CLEAN SAFETY VISIT BY STEVE ROBINSON. 13:30 - 15:00 1.50 CLEAN P CLEAN CONTINUE TO RIH. -RIH FROM STAND 55 TO 75. 15:00 - 16:30 1.50 CLEAN P CLEAN SLIP & CUT DRILL LINE. -CUT 84 FT OF 1 -1/8" LINE. 16:30 -18:00 1.50 CLEAN P CLEAN POH. -L/D 3 -1/2" DP FROM - 7,100' TO 5,240' MD. 18:00 -19:00 1.00 CLEAN P CLEAN SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. 19:00 - 00:00 5.00 CLEAN P CLEAN CONTINUE TO LD DP FROM 5,240' TO 1,500' MD 11/4/2009 00:00 - 02:00 2.00 CLEAN P CLEAN CONTINUE TO LD 3 -1/2" DP FROM 1,500' TO SURFACE. 02:00 - 03:00 1.00 CLEAN P CLEAN CLEAN AND CLEAR RIG FLOOR. 03:00 - 04:00 1.00 RUNCOMP RUNCMP RU TO RUN 4 -1/2" NSCT COMPLETION. - CHANGE ELEVATORS. 04:00 - 06:00 2.00 RUNCOMP RUNCMP RUN 4 -1/2" NSCT COMPLETION. -PJSM WITH RIG CREW AND NABORS CASING. -PU /MU SEAL ASSEMBLY. -START RUNNING IN HOLE PER RUNNING ORDER. 06:00 - 06:30 0.50 RUNCO RUNCMP SERVICE RIG. INSPECT DERRICK. CHECK ALARMS. Printed: 11/19/2009 11:38:19 AM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: MPI -19 Common Well Name: MPI -19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 10/20/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/5/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 11/4/2009 06:30 - 18:00 11.50 RUNCOMP RUNCMP CONTINUE TO RUN IN HOLE WITH 4 -1/2" NSCT COMPLETION. 18:00 - 18:30 0.50 RUNCOMP RUNCMP SERVICE RIG. INSPECT DERRICK. CHECK ALARMS. 18:30 - 19:00 0.50 RUNCOMP RUNCMP CONTINUE TO RUN IN HOLE WITH 4 -1/2" NSCT COMPLETION. -TAG UP @ 16' IN ON JT # 172 @ 7,134' MD. - SWALLOW 9'. -25' IN ON JT # 172, NO -GO. SET 1 OK DOWN WT. 19:00 -19:30 0.50 RUNCOtF RUNCMP FILL IA WITH 33 BBLS. -TEST IA TO 500 PSI FOR 5 CHARTED MINUTES.- OK. 19:30 - 21:00 1.50 RUNCOMP RUNCMP SPACE OUT COMPLETION ASSEMBLY. -LD: JT'S 172,171 & 170. -PU: 1 -PUP (2.08') & JT'S # 171 & 180. 21:00 - 22:00 1.00 RUNCOMP RUNCMP MU TBG HANGER & LANDING JT. -LAND COMPLETION IN COMPRESSION. RILDS. -PUW = 60(K) -SOW = 38(K) 22:00 - 00:00 2.00 RUNCOMP RUNCMP SET TWC. TEST TWC: -FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES - PASS. -FROM ABOVE TO 3500 PSI FOR 10 CHARTED MINUTES - PASS. -RD TBG RUNNING EQUIPMENT. -BLOW DOWN LINES. 11/5/2009 00:00 - 02:30 2.50 RUNCOMP RUNCMP ND BOP'S. 02:30 - 06:00 3.50 RUNCOMP RUNCMP NU TREE AND ADAPTER FLANGE. -TEST HANGER VOID TO 5,000 PSI F/ 30 MINUTES. -TEST TREE TO 5,000 PSI. 06:00 - 07:00 1.00 WHSUR P RUNCMP TWC. -R/U WELL SUPPORT LUBRICATOR. -TEST TO 500 PSI WITH DIESEL. PULL TWC. 07:00 - 13:00 6.00 WHSUR P RUNCMP FREEZE PROTECT: IA AND TBG. -R/U LINES. R/U MPU L.R.S. TEST LINES TO 3,000 PSI. -PUMP 85 BBLS DIESEL. 1.5 BPM AT 480 PSI. -SET AND TEST 3" BPV TO 500 PSI FROM BELOW. -R/D L.R.S. 13:00 - 13:30 0.50 WHSUR RUNCMP SECURE WELL. 13:30 -15:30 2.00 RUNCOMP RUNCMP CLEAN PITS. -SUCK OUT & RD TIGER TANK. - DETACH PIT LINES. 15:30 - 16:00 0.50 RUNCOMP RUNCMP A.A.R. RELEASE RIG @ 16:00 HRS. Printed: 11/19/2009 11:38:19 AM Tree: 4-1/16"- 5M FMC "1-19 T @ m rg Workstr�n Or' F elev. = 69.10' (Doyon 14) Wellhead: 11" x 11" 5M FMC YY (Il�4t' Or L elev. = 24.80' (Doyon 14) 4 -112" Tbg HGPr NSCT Wplbh X "M BPV profile 1 L 20 ", 92 # /ft, H -40 112' "Note" 10 3/4" 45.5 ppf L -80 & K -55 BTC -M (Drift ID = 10.050, cap. = .0981 bpf) Collapse / Internal Yield K -55 2090 psi. / 3580 psi. 2514 4 -tt2'x 1' ICDt32 {t7G11YarE 111Air,9} L -80 2480 psi. / 5210 psi. K -55 161 ` thru 2,879' 10 3/4" Howco Float Shoe 2999' 3007' 4-1re x Mpple 8.813 OD KOP @ 300' 50+ degree from 2500 PXX PLUG INSTALLED 44 Max hole angle = 75 degrees @ 6450' MD PLUG PULLED 11/9109 7 5/8" 29.7 ppf, L -80, BTC -M casing (Drift ID = 6.750 ", cap = 0.0459 bpf) 4-112' 12.8# NSCT 1b9. 6.78' Me 8rak8wlAa9mb1y 7137` Baker HRD ZXP Liner 7144` Top Packer WLEG 7147` LEM sleeve (Internal 18092' 7174` x 4.00" GS FN) Baker LEM #1, 4 -1/2" x 7187` 7 -5/8" 13CR Window in 75/8" Casing @ 7,192'- 7,204' Well Angle @ window = 72° 4 -1/2" Hook Hanger inside casing 7,187' 6 3/4" Hole td @ 12,225 Btm Baker Float Shoe 12,198' outside hook point 7,204' 118 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L -80 IBT OA Lateral Baker Tie Back Sleeve 7,315' 2W XN Nipple 2 - 7/8 ", 2.323" 7263' Baker ZXP Liner Top Packer 7,326 Pkg Bore Baker HMC Liner Hng. 7,332' Baker Seal bore ext. 7,340' , L -1 Non locating Seal Assy. 7310' / 6 3/4" Hole td @ 9720' Btm HES Type V Float Shoe 9720' 7 -5/8" Weatherford Float Collar 7344' 7 -5/8" Weatherford Float Shoe 7428' 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L -80 IBT OB Lateral DATE REV. BY COMMENTS M I LN E POINT UNIT 09/13/04 MDO Drilled & Completed Doyon 14 WELL 1 -1 9 02/12/05 MDO ESP RWO Nabors -4es 10/17/08 REH ESP RWO/ Install LEM API NO: 50- 029 - 23218 -00 11/4/09 REH Pull ESP/ Run 4.5" Workstring - Nabors 4ES 50- 029 - 23218 -60 BE EXPLORATION (AK) ~~ ~. STATE OF ALASKA ~.,08 ALA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPE~TION . ~~ . 1. Operations Performed: ^ Abandon ®Repair Well ' ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development'^ Exploratory 204-135 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 _ 50-029-23218-00-00 7. KB Elevation (ft): KBE = 69.1' ~ 9. Well Name and Number: MPI-19 ~ 8. Property Designation: 10. Field /Pool(s): ADL 025906 ~ Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9720' • feet true vertical 4088' ~ feet Plugs (measured) None Effective depth: measured 9720' ' feet Junk (measured) None true vertical 4088' ' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 2964' 10-3/4" 2999' 2550' 5210 2480 Intermediate Production 7395' 7-5/8" 7428' 4076' 6890 4790 Liner 2405' 4-1/2" 7315' - 9720' 4053' - 4088' 8430 7500 ff~~~ e~e~~~yy~r77"~ +~~~? [[[~, ~ ~" ~~ F t S ~~C;s'.~...~le LtaL , +~ t E t -, c . , ,s .; L1 tJ Perforation Depth MD (ft): Slotted: 7391' - 9591' Perforation Depth TVD (ft): Slotted: 4070' - 4095' 2-7/8", 6.5# L-80 6635' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 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: Subsequent to operation: 28 61 93 300 310 14. Attachments: [] Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 r(/q Printed Name Terrie Hubble Title Drilling Technologist ~` t1 Prepared By Name/Number: ~D ~ Signature Phone 564-4628 Date U Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 . ~ ~~ ' ,,.~;,~ ~ ~~ Lea Submit Original Only ~~~,,~ • MPI-19 &MPI-19L1, Well History (Pre Rig Workover) Date Summary 8/29/2008 T/I/0= 300/300/150 Freeze Protect (Pre-RWO) Pumped 15 bbls Diesel down tubing. Pumped 2 bbls 60/40 methanol, 2 bbls Diesel, and 2 bbls 60/40 methanol down production and test flowlines. Closed lateral valves and bleed presures down to 0 psi. FWHP= 200/300/150 Master, IA, and OA open. Swab, SSV, Wing, laterals are closed. 8/30/2008 WELL S/I UPON ARRIVAL (RIG PREP). RAN 2.0" DRIVE DOWN BAILER. SAT DOWN @ 6287' SLM. MADE 2' FT OF HOLE TO 6289' SLM. RECOVERED FULL BAILER (3/4 GAL) OF SAND. RIG DOWN. TURN WELL OVER TO DSO. 8/31/2008 WELL S/I (pre rwo). PULLED 1" BEK-DPSOV FROM 2030' MD, SET 1" BK-DGLV. 9/1/2008 WELL SHUT-IN ON ARRIVAL. T/I/O 250/350/0. RU ELINE FOR SMALL 1.56" TUBING PUNCH, 4 SPF.. 9 SHOTS TOTAL ACROSS INTERVAL 6230.5' - 6232.5'. SURFACE AND VISUAL CONFIRMATION OF TBG PUNCHER FIRING. ALE RCULATE WELL. JOB COMPLETE. WELL LEFT SHUT IN. FINAL T/I/O: 230/ 350/ 150 PSI. 9/1/2008 PULLED 1" BEK-DPSOV FROM 167' MD, SET 1" BK-DGLV. DRIFTED W/2.25" CENT, SAMPLE BAILER TO 6287' SLM. JOB COMPLETED. 9/1/2008 T/I/0=200/340/150 Assist E-line (Pre-RWO) -Pumped tbg w/ 25 bbls 50°F diesel to verify tbg to IA circulation following tbg punch. TP fell from 250 psi to 25 psi while pump on line @ 1.6 bpm. IAP increased 40 psi from 340 psi to 380 psi. OAP increased 70 psi from 150 psi to 220 psi. Verify I/OA open to gauges, (E-line still on well) & notify operator. Final WHP's=Vac/380/220 Nabors 3S Moved over the well (See Summaries for 09/17/08 through 09/25/08) 10/1/2008 WELL S/I ON ARRIVAL (post rig, pre coil). PULL BPV. PULL RKP-SHEAR VALVE FROM 2102' MD. MADE MULTIPLE ATTEMPTS TO SET 1.5" DUMMY RKP LATCH @ 2102' MD. RUNNING IN HOLE TO EOULIZE XXN PLUG @ 6789' MD. 10/2/2008 LRS PUMP 20 BBL DIESEL DOWN TUBING TAKING RETURNS UP IA. SET RKP-DGLV IN STA #1 @ 2102' MD. ATTEMPT TO EQUALIZE XXN @ 6789' MD PT TUBING TO 560 PSI. PLUG IS EQUALIZED PRESSURE HOLDING. WELL S/I ON DEPARTURE. 10/2/2008 T/I/0=100/0/160 Assist Slickline Pumped 20 bbls Diesel down tubing while taking returns up IA to a tank. Slickline set DGLV. Pressure test to 1000 psi. with 1 bbl diesel. Bleed pressure back to 200 psi. FWHP=200/0/180 Left slickline still on well. IA, and OA open to gauges. 10/4/2008 MIRU. RIH with BOT fishing string: jars, 2.5" GS. Tag plug @ 6798'. PU 9-12k# over twice. Popped free. POOH. Plug was recovered. Work on I-coil head. 10/5/2008 MU/RIH with I-coil PTC/Sensing package and 2" JSN. Hard tag at 7253 CTM. POOH. R/U N2. Blow reel down with N2. RIH w/ I-coil PTC/Sensing package and 2" JSN & cont. unloading well with 500scf/N2 @ .4bpm. Stop at 6800. Lost i-coil acquisition. Got CCL back but intermittent. POOH to check downhole sensing package. Changeout DHA module and surface comm module. MU new I-coil tools. RIH again. Get to 3000'. Problems with I-coil communication. 10/6/2008 Trouble shoot down hole and surface comm problems with I-coil. Determine to continue job with only CCL~ Re-start N2 lift from 3000' with N2 @ 500 scf/m into ASRC. Make stops @ 4500' and 7100'. RIH dry and tapped at 7251. Start pumping at 2bpm. Looked like bridge at 7251. RIH to 7450. Chased Fill from 7450 to 5800. RIH. i-Coil has indicated that BHA has entered OB lateral. Conducted fill clean out of OB lateral with a fluid rate of 1.0 bpm and a N2 rate of 500 scf each sweep sampled at surface ranged from 1.5%-30% solids. Lost all I-coil functionality. Trip up hole while FE's get it going again. RIH for next bite. Jet 100' bite from 8400' w/ 10 bbl flopro sweep. Chase to 7450'. Take 150' bite w/ 10 bbl sweeps to 8650', chase into tail @ 6700'. Take 150' bite w/ 10 bbl sweep to 8800', chase into tail. Page 1 of 2 • • MPI-19 &MPI-19L1, Well History (Pre Rig Workover) Date Summary 10/7/2008 FCO 150-200' bites w/ 500 scf/m N2 and 10 bbl fropro sweeps from 8800' to 9709'. Tag bottom at 9709 CTM. POOH anc chase sweep to 7450. Pump final 10 bbl sweep and POOH at 60% thru 7-5/8" to 6800'. POOH at 80%. Solids from .25% to 1.2%. Freeze protect well with 26 bbls of 50/50 methanol. Freeze protect coil and all lines and lines to tanks. RDMO. Notify operator on departure. Job Complete. Nabors 3S Moved over the well (See Summaries for 10/09/08 through 10/17/08) Page 2 of 2 • BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 9/17/2008 End: 10/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase j Description of Operations 9/17/2008 08:00 - 10:00 2.00 RIGD P PRE Rig down from well MPJ-06. Limit rig down operations due to inclement weather. Move auxiliary support equipment from MPJ-Pad to MPI-Pad. MPU Roads and Pads working on site preparation around well slot MPI-19. 10:00 - 18:00 8.00 RIGD P PRE Unable to scope and lower the Derrick due to high wind speeds over 25 MPH limit. Winds gusting to as high as 40 MPH. Continue moving equipment to MPI-Pad. Rig on standby with full crews at 1000 hrs 9/17/2008. 18:00 - 00:00 6.00 RIGD P PRE Crew change. Perform light maintenance, house keeping and painting. Winds remain over 25 MPH limit. 9/18/2008 00:00 - 02:00 2.00 RIGD P PRE Unable to scope and lower the Derrick due to high wind speeds over 25 MPH limit. Winds gusting to as high as 40 MPH. 02:00 - 03:30 1.50 RIGD P PRE Rig off of standby with full crew due to weather at 0200 hrs on 9/18/2008. Scope and lower Derrick. 03:30 - 06:00 2.50 RIGD P PRE Move pipe shed away from sub, blow down steam, Jack down Carrier. 06:00 - 08:00 2.00 RIGD P PRE Disconnect all Modules and prepare for trucks. Trucks arrive on location at 0630 hrs. Pre-job safety meeting with truck drivers. Back the Carrier off well slot MPJ-06 at 0730 hrs with the Toolpusher and Pad Operator present. Stage the Modules and Camp at the exit of the Pad for mobilization. 08:00 - 09:00 1.00 MOB P PRE Move the Rig Modules from MPJ-Pad to MPI-Pad. 09:00 - 13:30 4.50 RIGU P PRE Arrive on MPI-Pad. Spot the Camp, Shop, Generator and Parts Trailer per approved Camp Siting Form. Spot the BOPE Cradle behind and rig mats around well slot MPI-19. Back the Carrier over well slot MPI-19. Back the Pipe Shed and Pits Modules and mate with the Carrier. 13:30 - 18:00 4.50 RIGU P PRE Hold pre-job safety meeting. Raise and scope the Derrick. Spot the Tiger Tank. Check the level of the Carrier and have to lower the Derrick and re-level. "Rig accepted at 18:00 hours 9/18/2008*'. 18:00 - 19:30 1.50 KILL P DECOMP Rig up lines to tree for circulation well kill. Load pits with 8.45 # seawater. Complete RU on rig. 19:30 - 21:30 2.00 KILL P DECOMP Test hardline to Tiger tank - 500 psi. Close choke, test upstream to 2500 psi. PUMU lubricator. Test to 500 psi with diesel. Pull BPV. WHP's: TBG=O, IA=300, OA=150 21:30 - 00:00 2.50 KILL P DECOMP PJSM with Vac truck drivers and Rig crew. Bleed IA from 320 psi to 10 psi. Circulate 40 bbls 8.45 ppg Seawater down the tubing at 3 BPM / 20 psi with little returns. Close choke and bullhead 80 bbls 8.45 ppg seawater at 3 BPM / 240 psi. Stop TBG = 0, IA = 150 psi. Circulate 110 bbls 8.45 ppg seawater down the tubing taking returns to the Tiger tank at 3 BPM / 240 psi. Stop due to returns being mostly gas. Bullhead 365 bbls 8.45 ppg seawater down the IA at 3 BPM / 580 psi. Stop, 9/19/2008 00:00 - 03:00 3.00 KILL P DECOMP Stop, bullhead 40 bbls 8.45 ppg seawater down the tubing at 3 BPM / 750 psi. Stop and monitor well for 30 minutes. Tubin and IA on a Vac. 03:00 - 03:30 0.50 KILL DECOMP Monitor well for 30 minutes. 03:30 - 04:00 0.50 KILL P DECOMP Blow down lines and RD kill manifold. 04:00 - 07:00 3.00 WHSUR P DECOMP FMC well head tech dry rod TWC. Test to 3,500 psi from above for 10 charted minutes. Had to work air out of system various times to get a good 10 minute test. Blow down lines and RD kill manifold. Printed: 10/20/2008 12:30:42 PM • • BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 9/17/2008 End: 10/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 Rig Name: NABOBS 3S Rig Number: i ~ Hours Task Code NPT 'Phase Description of Operations Date From - To 9/19/2008 07:00 - 09:00 2.00 WHSUR P DECOMP ND Tree and Adapter Flange. Check Hanger threads with FMC rep - OK. Top Hanger threads are 2-7/8" EUE 8rd. Fill the IA with 20 bbls per hour of seawater while ND/NU. 09:00 - 16:00 7.00 BOPSU P DECOMP NU 11" x 13-5/8" DSA. PU BOPE off of Cradle and NU BOPE. 16:00 - 17:00 1.00 BOPSU P DECOMP Fill BOPE and function test. 17:00 - 21:30 4.50 BOPSU P DECOMP Pressure test BOPF nar RP/AnGC . RPg Jatinns to 250 psi low and 3,500 psi high for 5 charted mins each. Test against the TWC. Test with both 2-7/8" and 3-1/2" Test Joints. The State's right to witness the BOPE test was waived by Chuck Scheve at 1030 hrs on 9/18/2008. The test was witnessed by the BP WSL and Nabors Toolpusher. Maintain 20 bbls per hour fill rate with seawater while testing BOPE. 21:30 - 22:00 0.50 BOPSU P DECOMP Blow down lines and drain BOP stack. 22:00 - 23:30 1.50 WHSUR P DECOMP PU New Opso Lopso, break out pup joint and MU 2-7/8" EUE XO. MU and test lubricator to 500 psi and MPU Well support techs ulled TWC. LD Lubricator and New Opso Lopso. 23:30 - 00:00 0.50 PULL P DECOMP MU TIW valve on landing joint. 9/20/2008 00:00 - 00:30 0.50 PULL P DECOMP MU 2-7/8" landin 'pint screw into han er, FMC well tech BOLDS, pull hanger free with 49 K well on a Vac. 00:30 - 01:00 0.50 PULL P DECOMP Pump 40 bbls seawater down tubing and 20 bbls in IA with no returns. 01:00 - 01:30 0.50 PULL P DECOMP Monitor well for 30 minutes. Both Tubing and IA on a vac. 01:30 - 02:30 1.00 PULL P DECOMP Remove ESP tubing penetrator, LD landing joint and tubing hanger. Install tubing safety valve. Hang cable trunk in Derrick, Fill rate at 20 BPH seawater. 02:30 - 06:00 3.50 PULL P DECOMP POH with 2-7/8" tubing ESP completion and stand in Derrick, LD 8 ft pup, two GLM's, 45 stands pulled at 05:30 hours. 06:00 - 12:30 6.50 PULL P DECOMP Pre-tour checks and service the Rig. Continue POOH with existing 2-7/8" ESP Completion standing back in the Derrick. Maintain 20 bbls per hour fill rate with seawater while POOH. Encounter tubing punch holes in the bottom of stand #99 out of the hole. Encounter sand/fill on top of the XN Nipple down to the top of the ESP Assembly. 12:30 - 16:30 4.00 PULL P DECOMP On surface with ESP Assembly. Break out and lay down ESP Assembly with Centrilift rep. Cut Cable and send over Sheave to Spooling Unit. Maintain 20 bbls per hour fill rate with seawater while on surface. Recovered 111 LaSalle Clamps, 3 Flat Guards and 6 Protectolizers. 16:30 - 17:00 0.50 PULL P DECOMP Clear and clean Rig Floor. 17:00 - 18:30 1.50 PULL N WAIT DECOMP Secure the well and shut down all operations on the Rig. Maintain 20 bbls per hour fill rate with seawater while shut down. At 16:30 hrs, WSL notified Milne Point Security of a fire at the Satellite Camp. Afire had broken out in the central bathroom ceiling. All camp personnel were safely evacuated. Milne Point Fire Department responded to the incident and put out the fire. All notifications were made to appropriate parties by the BP WSL and Nabors Toolpusher. 18:30 - 00:00 0.00 PULL N WAIT DECOMP Stand down all operations on the Rig. Light cleaning and maintenance projects on the Rig. Continue filling the well with 20 bbls per hour fill rate with seawater. Monitor the Rig Camp at all times throughout the night. 9/21/2008 00:00 - 06:00 6.00 PULL N WAIT DECOMP Stand down all operations on the Rig. Light cleaning and maintenance projects on the Rig. Continue filling the well with Printed: 10/20/2008 12:30:42 PM • BP EXPLORATION Operatiolns Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S i i Date From - To Hours ~ Task Code NPT 9/21/2008 00:00 - 06:00 6.00 PULL N ~ WAIT 06:00 - 14:00 ~ 8.00 ~ PULL ~ N ~ WAIT 14:00 - 20:00 I 6.001 CLEAN I P 20:00 - 22:30 I 2.501 CLEAN I P 22:30 - 00:00 1.50 (CLEAN N WAIT 9/22/2008 100:00 - 06:00 I 6.001 CLEAN I N I WAIT 06:00 - 00:00 I 18.00 I CLEAN I C 9/23/2008 100:00 - 04:00 I 4.00 I CLEAN I C 04:00 - 08:00 I 4.00 I CLEAN I C 08:00 - 08:30 0.501 CLEAN C 08:30 - 16:30 I 8.00 I CLEAN I C 16:30 - 17:00 0.50 CLEAN C 17:00 - 22:30 5.50 RNWOR t 22:30 - 00:00 I 1.50 I CLEAN I C 9/24/2008 100:00 - 06:00 I 6.00 I CLEAN I C Start: 9/17/2008 Rig Release: 10/17/2008 Rig Number: Page 3 of 9 Spud Date: 8/28/2004 End: 10/17/2008 Phase Description of Operations DECOMP 20 bbls per hour fill rate with seawater. Monitor the Rig Camp at all times throughout the night. DECOMP Continue light maintenance and wait to continue operations. Confer with Anchorage Engineering and plan forward is to RIH and to to of fill and sus end o erations a ain. Continue feeding the well with 20 bbls/hour fill rate with seawater. Check the well and it is on a vac. Shoot fluid level at 0830 hrs with Well Support Techs - 550 ft. Load and tally additional joints of 2-7/8" EUE 8rd Tubing into the Pipe Shed. Prepare to RIH. CLEAN PU 2-7/8" Nozzle and MU on 2-7/8" Tubing. Strap pipe in Derrick while RIH on stands of 2-7/8" Tubing to 6,344' MD. Pump 13 bbls down the tubing with no returns at 2 BPM / 1,000 psi. Maintain 20 bbls per hour fill rate with seawater while RIH. CLEAN PJSM. PU 28 joints of 2-7/8" tubing from pipe shed and Taf„ with 5K at 7,215' MD. POW = 40K, SOW = 30K, pump down the tubing with no returns at 1 BPM / 40 psi. Confer with RWO Engineer in town. RIH to 7,246' MD with 5K down drag, encounterl5K over pull, stop. Confer with RWO Engineer. POH (LD 6 joints) to 7,060'. Pump down tubing to insure Jet nozzles are clear at 1 BPM / 40 psi. CLEAN Stand down all operations on the Rig. Perform Light cleaning and maintenance projects on the Rig. Continue filling the well with 20 bbls per hour fill rate with seawater. CLEAN Stand down all operations on the Rig. Perform Light cleaning and maintenance projects on the Rig. Continue filling the well with 20 bbls per hour fill rate with seawater. CLEAN Wait on plan forward from W.O. Engineer due to continuous, completion desi n changes., Plan Forward finalized and waiting on equipment/assemblies to be put together and arrive on location. Continue filling the well with 20 bbls per hour fill rate with seawater. CLEAN Wait on plan forward from W.O. Engineer due to continuous completion design changes. Continue filling the well with 20 bbls per hour fill rate with seawater. Pumped 20 bbls down tubing 2 BPM / 100 psi with no returns. Bleed OA from 400 psi to 100 psi. Wait on tubing completion assembly. All assemblies and Tubing arrive on location at 0300 hrs. CLEAN Take 31 joints of 2-7/8" tubing out of pipe shed and load with 3-1/2" IBT-MOD. Maintain hole fill with seawater at 20 bph. CLEAN Pump 40 bbls of seawater down tubing at 2 bpm with 160 psi pump pressure. CLEAN POOH laying down 2-7/8" tubing. Pump 20 bph seawater plus metal displacement. CLEAN Clear rig floor. INTERN R/U handling equipment for running 3-1/2" tubing workstring. Load pipe shed with 3-1/2" NSCT tubing. Tally tubing. Maintain hole fill with seawater at 20 bph. CLEAN RIH with 3-1/2" workstrin run 3-1/2" # - N T tubin . Use Best-O-Life 2000 pipe dope. Make up torque is 2,890 ft/Ibs. Fill tubing every 10 joints. Maintain hole fill with seawater at 20 bph. CLEAN RIH with 3-1/2" workstring, run 3-1/2", 9.2#, L-80, NSCT tubing. Use Best-O-Life 2000 pipe dope. Make up torque is 2,890 Printed: 10/20/2008 12:30:42 PM • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 9/17/2008 End: 10/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ~ Task. Code NPT Phase Description of Operations 9/24/2008 00:00 - 06:00 6.00 CLEAN C CLEAN ft/Ibs. Fill tubing every 10 joints. Maintain hole fill with seawater at 20 bph. P/U 7-5/8" Halliburton Champ IV Packer at 03:00 hours. 06:00 - 06:30 0.50 CLEAN C CLEAN Pre-tour checks and service the Rig. 06:30 - 10:30 4.00 CLEAN C CLEAN Continue RIH with 3-1/2" workstring on 9.2#, L-80, IBT-M Tubing. Making all connections to the mark and using Best-O-Life 2000 dope with an average make up of 3,000 ft-Ibs. Fill the Tubing every 20 Joints as RIH. 165 Joints in at 0700 hrs. 10:30 - 11:30 1.00 CLEAN C CLEAN Change elevators to handle 3-1/2" IF Landing Joint. PU Landing Joint. MU XO to Hanger and MU Hanger. 11:30 - 13:00 1.50 WHSUR C CLEAN Set the Champ IV Packer with Halliburton reps. Stack _12,000# on it from the top. Land the Tubing Hanger and RILDS with FMC rep. Attempt to fill the IA with seawater - no Joy. Pumped a total of 83 bbls with only 120 psi of pressure. 13:00 - 14:00 1.00 WHSUR C CLEAN RD the lines and floor equipment. Check the IA and it is on a vac. Call out for more fluid to be delivered from Milne Point. 14:00 - 15:00 1.00 WHSUR C CLEAN Release the Packer with Halliburton reps. Had to work it up hole indicating the slips had indeed set. Lay down the Landing Joint and Hanger. 15:00 - 16:00 1.00 WHSUR C CLEAN PUMU Landing Joint and Hanger. 16:00 - 16:30 0.50 WHSUR C CLEAN Re-set the Champ IV Packer with Halliburton reps,. Set _20,000# on it from the top. Land the Tubing Hanger and RILDS with FMC rep. PUW = 55K ,SOW = 35K for the workstring. Center of element on the Packer at 4.017' 3SMD. 16:30 - 17:30 1.00 WHSUR C CLEAN Wait on the vac truck to arrive with produced water from Milne Point. 17:30 - 18:00 0.50 WHSUR C CLEAN Fill the IA with 22 bbls of produced water and pressure uo to 1,000 psi. Hold the pressure for 10 mins to ensure the Packer is set - OK. 18:00 - 20:30 2.50 WHSUR C CLEAN Pressure test the tubing to 3,500 psi for 30 minutes on the chart pod test. Bleed the tubing pressure down to 1,500 psi. Pressure up the IA to 3 500 psi for 30 minutes on the chart. pod test. Bleed off pressure on the tubing side. DCR valve sheared at 1,400 psi. Line up and pump both ways through DCR to ensure it is open. 20:30 - 22:00 1.50 WHSUR C CLEAN Set 3" T e "H" TWC with FMC wellhead tech. Test from above to 3,500 si for 10 minutes and from below to 500 si for 10 minutes. Chart tests. 22:00 - 23:30 1.50 WHSUR C CLEAN N/D BOPE, remove riser, choke line, kill line, koomey lines and turnbuckles. Set BOP stack on cradle and lay over. 23:30 - 00:00 0.50 WHSUR C CLEAN Remove 2-9/16" tree from cellar and put 3-1/2" tree in cellar. 9/25/2008 00:00 - 02:00 2.00 WHSUR C CLEAN N/U adaptor flange and 3-1/2" tree. Test adaptor flange to 5,000 psi for 30 minutes. Test tree to 5,000 psi with diesel. Good tests. 02:00 - 03:30 1.50 WHSUR C CLEAN P/U lubricator, Unable to adapt lubricator for 3-1/2" tree. C/O upper flange to fit Otis connection on lubricator. M/U lubricator and test to 500 si with diesel. Pull TWC. 03:30 - 04:00 0.50 WHSUR C CLEAN R/U lines for pumping freeze protect. 04:00 - 07:00 3.00 WHSUR C CLEAN R/U Little Red and pump 90 bbls of crude freeze protect down IA taking returns out the tubing. 2 bpm at 850 psi. U-tube freeze protect from IA to tubing. 07:00 - 09:30 2.50 WHSUR C CLEAN PU T-bar and set 3" Type "H" BPV with Well Support Techs. Printed: 10/20/2008 12:30:42 PM • BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 9/17/2008 End: 10/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/25/2008 ~ 07:00 - 09:30 ~ 2.50 WHSUR ~ C ~ ~ CLEAN RU test pump and test the BPV from below with diesel to 1,000 10/9/2008 06:00 - 11:00 5.00 MOB P 11:00 - 20:00 9.00 MOB P 20:00 - 21:00 1.00 KILL P 21:00 - 22:00 22:00 - 22:30 22:30 - 00:00 10/10/2008 10/11 /2008 00:00 - 01:30 01:30 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 11:30 11:30 - 12:30 12:30 - 13:00 13:00 - 16:00 16:00 - 17:00 17:00 - 19:00 19:00 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 06:00 06:00 - 08:00 1.00 WHSUR P 0.50 KILL P 1.50 KILL P 1.50 KILL P 0.50 KILL P 2.00 WHSUR P 2.00 WHSUR P 5.50 WHSUR P 1.00 WHSUR P 0.50 WHSUR P 3.00 WHSUR P 1.00 WHSUR P 2.00 WHSUR P 3.00 WHSUR P 2.00 WHSUR P 0.50 BOPSU P 5.50 DHB P 2.00 DHB P psi for 10 charte mms - test Ines an equipmen . Remove secondary annulus valve and secure the Tree. The Ri was released at 0930 hrs on 9/25/20 8. PRE Rig released from MPG-04. RDMO location. 24 hour notice to Chuck Scheve with AOGCC for upcoming BOPE test. PRE Arrive on location. Pre-rig inspection. MIRU on MPI-19. Spot carrier, pits, and pipe shed. Raise and scope derrick. Connect all modules and components. DECOMP Install second annulus valve to tree. RU kill manifold in cellar and hard lines to Tiger tank. Pressure test hard lines to 3,500 psi. and down stream of choke to Tiger tank lines to 500 psi. DECOMP PU / MU lubricator to tree and test to 500 psi with diesel. Well support techs pulled BPV. WHP's TBG=550, IA=O, OA=150 DECOMP PJSM hel on well Kill operations with crew and Vac-truck drivers. DECOMP Bleed IA from 550 psi to 90 psi. Bull head 320 bbls 140 Deg heated 8.45 ppg seawater down the tubing at 4 BPM / 400 psi. DECOMP Continue to Bull head 320 bbls 140 Deg heated 8.45 ppg seawater down the tubing at 4 BPM / 400 psi. DECOMP Stop and monitor for 30 minutes. TBG on a vac, IA is static and OA= 150 psi. DECOMP Install TWC with FMC well st to 3 500 si from above for 10 charted minutes. DECOMP Blown down lines and ND production tree. 5-1/2 turns on XO for TC-II top hanger threads. DECOMP NU BOPE. DECOMP Safety meeting discussing hand incidents and injuries. Shut down for 30 minutes for lunch for crew. Incoming crew delayed due to weather in Anchorage. State's right to witness BOPE testing waived by Chuck Scheve. DECOMP Function test BOPE components. Full body test to 250 / 3500 psi. DECOMP Test BOPE. 300 psi below closed pipe rams. Unable to bleed down. Pressure above TWC to 1000 psi, pumping by TWC. Bleed pressure and attempt to surge TWC to net it to seat Unable to do so, WHP stable @ 300 psi. DECOMP Consult with town group and Superintendant. Formulate plan forward. DECOMP ND riser. NU shooting flange,. DECOMP PJSM with Well support techs and crew. PU / MU lubricator and space out with 10 ft extension, test lubricator to ~,~0 nci then bleed to 300 si. Well support techs pull TWC above blind rams, close blind rams and bleed to 0- si. UD lubricator and pump in sub.,, DECOMP Bull head 300 bbls 8.45 ppg seawater down tubing at 4 BPM / 350 psi. TBG on a Vac, OA = 150 psi. DECOMP Monitor well for 30 minutes, TBG on as Vac_. Held PJSM with SLB slickline crew. DECOMP RU SLB slickline crew with ressure control a ui ment and lubricator. DECOMP PUMU 1-7/8" toolstring and 3-1/2" XXN plug. Test Lubricator Printed: 10/20/2008 12:30:42 PM ~ ~ B'P EXP'LORATION Page 6 of 9 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 9/17/2008 End: 10/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To ,Hours Task 'Code NPT Phase Description of Operations 10/11/2008 06:00 - 08:00 2.00 DHB P DECOMP to 500 psi. Attempt to RIH. Unable to enter tubing at hanger. Break out and reconfigure plug. Add tapered bull-nose. 70 psi on tubing. 08:00 - 09:30 1.50 DHB P DECOMP MU SLB toolstring and lubricator. Test to 500 psi above blind rams. RIH (able to work plug into 3-1/2" tubing). RIH and set lu in 3-1/2" XXN lu in ni le (~ 1986'. POH 09:30 - 10:30 1.00 DHB P DECOMP Bleed tubing from 140 psi to 0 psi. Close blinds, Remove SLB lubricator, inspect running tool, Load tubing with 15 Bbls of SW, bleed air/gas from tubing, Test downhole plug to 1000 psi and chart for 10 minutes 10:30 - 11:30 1.00 DHB P DECOMP RD and Lay down SLB lubricator, BOPE, and shieves etc. Clean and clear rig floor. 11:30 - 12:30 1.00 WHSUR P DECOMP FMC dry rod TWC. Test to 250 / 3500 si a ainst blind rams for 10 charte minutes. 12:30 - 17:00 4.50 BOPSU P DECOMP Grease choke manifold. BOPE test 250 / 3500 psi. Test all choke, kill, HCR valves. 17:00 - 18:00 1.00 BOPSU P DECOMP ND shooting flange and NU air boot, riser and flow line.. 18:00 - 22:00 4.00 BOPSU P DECOMP Continue Pressure test BOPE per BP/AOGCC e s to psi ow an psi high for 5 charted mins each. Test against the TWC. Test with both 2-7/8" and 3-1/2" Test Joints. The State's right to witness the BOPE test was waived by Chuck Scheve at 12:00 hrs on 10/10/2008. The test was witnessed by the BP WSL and Nabors Toolpusher. 22:00 - 22:30 0.50 BOPSU P DECOMP BO / LD test joints and blow down lines and choke. 22:30 - 00:00 1.50 DHB P DECOMP PU / MU Opso-Lopso, pump-n-sub, lubricator and test to 500 psi. Well support techs pulled TWC. 10/12/2008 00:00 - 01:00 1.00 BOPSU P DECOMP BO / LD Lubricator and Opso-Lopso and XO's. 01:00 - 03:00 2.00 BOPSU P DECOMP ND riser and air boot and flow line, NU shooting flange. 03:00 - 05:00 2.00 DHB P DECOMP PJSM with slickline crew. PU / MU SLB slickline pressure control, and test lubricator to 500 psi. Bleed pressure, and maintain 100 psi. Open blind rams. 05:00 - 08:30 3.50 DHB P DECOMP RIH to equalize XXN plug at 1,986' md. hold -100 psi on: tubing. Equalize plug, tubing pressure to 0 psi. RIH w/ 3-1/2" GS. Engage and pull XXN plug. POH. Close blind rams, 180 psi on tubing. 08:30 - 09:30 1.00 DHB P DECOMP RD SLB wireline equipment. Clean and clear rig floor. 09:30 - 11:00 1.50 WHSUR P DECOMP ND shooting flange. NU air boot and pitcher nipple. 11:00 - 12:00 1.00 PULL P DECOMP PUMU 3-1/2" landin 'oint. Torque XO for TC-II, MU TIW valve. 180 psi on Tubing. Bullhead 200 Bbls down tubing ~ 4 BPM, 350 psi. SD with tubing on vacuum. 12:00 - 13:00 1.00 PULL P DECOMP Open blind rams, screw landing joint into hanger with 5 turns. Load stack with SW. PU and lift tubing hanger out of spool, observe fluid fallin ,then stable. PU 50 K PU weight (-8"), observe bypass open. Close annular. 13:00 - 16:00 3.00 PULL P DECOMP Bullhead 300 Bbls of SW down annulus ~ 4 BPM, 530 psi. Tbg ~ 0 psi, then to 260 psi when done. Bleed gas from IA. 230 psi on tubing and IA. IA gradually increase to 400 psi. 16:00 - 17:00 1.00 PULL P DECOMP Slack off and re-seat tubing hanger. Bullhead 100 Bbls down tubing ~ 4 BPM, 250 psi. Tubing on vacuum. PU 5' and unseat tubing hanger and HES packer. Bleed gas from IA. 17:00 - 18:00 1.00 PULL P DECOMP Call for load of SW. Rig up LRS to double valve on IA. Bleed gas from IA slowly. Tbg on vacuum. At 17:30 IA pressure to 0 psi. Shut in to see if it builds back up. Call for well techs to Printed: 10/20/2008 12:30:42 PM • BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 3S Date _ 'From - To Hours Task Code NPT 10/12/2008 17:00 - 18:00 1.00 PULL P 18:00 - 20:00 2.00 PULL P 20:00 - 21:00 I 1.001 PULL I P 21:00 - 21:30 I 0.501 PULL I P 21:30 - 23:00 ~ 1.50 ~ PULL ~ P 23:00 - 00:00 I 1.001 PULL I P 10/13/2008 100:00 - 04:00 4.001 PULL P 04:00 - 05:00 1.00 PULL P 05:00 - 09:30 4.50 PULL P 09:30 - 10:00 0.50 CLEAN P 10:00 - 15:00 5.00 CLEAN P 15:00 - 22:30 7.50 CLEAN P 22:30 - 00:00 I 1.50 I CLEAN I P 10/14/2008 100:00 - 02:00 I 2.001 CLEAN I P 02:00 - 08:30 6.50 CLEAN P 08:30 - 10:00 1.50 CLEAN P 10:00 - 13:00 I 3.00 Spud Date: 8/28/2004 Start: 9/17/2008 End: 10/17/2008 I Rig Release: 10/17/2008 Rig Number: Phase Description of Operations DECOMP come and shoot a fluid level. DECOMP Pump 20 bbl SW down IA, IA ~ -5 psi, TBG on a vacuum. Well techs shoot fluid levels, TBG = 850 ft IA = 850 ft. Pump 10 bbls SW down TBG and 20 bbls SW down IA. DECOMP Monitor shut in WHP's for 30 minutes, TBG = 0 psi, IA =less then 5 psi. Bleed gas from IA slowly. TBG on a vacuum, IA = 0 psi. DECOMP POH LD tubing hanger and landing joint assembly, POW = 51 K. Fill rate at 20 BPH. DECOMP POH slow LD 10 joints of 3-1/2" work string, MU floor safety valve. Well techs shot fluid level, IA = 1000 ft. POH slow LD 10 more joints and shot fluid level, IA = 800 ft. Continuous fill rate at 25 BPH with no returns. Received 290 bbls Source water from MPU due to PBU STP shut down. DECOMP Continue to POH slowly, UD 3-1/2" TBG work string. Maintain continuous fill rate of 20-25 BPH with no returns. 40 joints UD at 00:00 hours. DECOMP Continue to POH UD 3-1/2" work string to -2,800', (UD 126 joints) Maintain continuous fill rate at 20-25 BPH. DECOMP Pump 10 bbls SW down tubing and 20 bbls down the IA, TBG on a vacuum. BOLD champ packer. All elements and packer. " like new" condition. DECOMP Continue to POH UD 3-1/2" work string, Maintain continuous fill rate at 20-25 BPH. DECOMP Clean and clear floor. DECOMP MU 3-1/2" down 'et nozzle on 2-7/8" tubin from i e shed. RIH maintaining charge pump on hole ~ -20 Bbl/Hr. DECOMP 60 joints in hole. Flush nozzle C~ 2-1/2 BPM, 150 psi. Continue to RIH w/jet nozzle, picking up 2-7/8" tubing. Flush nozzle at joint 120 ~ 1.5 BPM / 290 psi and joint 220 @ 1.5 BPM / 300 psi. Maintaining charge pump on hole ~ -20 Bbl/Hr. DECOMP PJSM with LRS. Recipro pir~and flush down from 7 093' md, and tagged with 5 K down wt @ 7 125' md. while pumping 2 BPM / 300 psi down the tubing and Little Red pumping 3 BPM down IA C~ 0 psi with no returns. Tubing and IA on a Vaccuum. DECOMP Reciprocate pipe and flush down from 7,125' and to 7,370' md, while pumping 2 BPM / 300 psi down the tubing and Little Red pumping 3 BPM down IA @ 0 psi with no returns. PUW = 40 K, SOW = 30 K, P/U drag = 55 K. OA = 200 psi, Tubing and IA on a Vaccuum. DECOMP POH LD 14 joints and stand 2-7/8 tubing in Derrick. Maintain continuous fill rate ~ -20 BPH. 35 stands out at 05:30 hours. DECOMP BOLD nozzle. Maintain continuous hole fill ~ -20 Bbl/Hr. Clean and clear rig floor. Prep for running completion. RUNCMP PUMU ZXP lin r t a d isolation sleeve installed. Sleeve tested in shop to 2500 psi. 2 joints of 4-1/2" tubing below LEM, with XN in the middle, and seal mandrel on bottom. 13:00 - 19:00 6.00 BUNCO RUNCMP RIH slowly with ZXP packer on 112 stands of 2-7/8" tubing from Derrick and PU 5 joints from pipe shed to _7,350' md. Maintain continuous hole fill ~ -20 Bbl/Hr. Printed: 10/20/2008 12:30:42 PM • • BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: MPI-19 Common Well Name: MPI-19 Spud Date: 8/28/2004 Event Name: WORKOVER Start: 9/17/2008 End: 10/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours I' Task Code NPT Phase Description of Operations 10/14/2008 19:00 - 22:00 3.00 BUNCO RUNCMP Establish parameters with Baker rep. SOW = 30 K, PUW = 42 K. Locate LEM with collets and confirm by PUW = 65 K. Drop 1.5" ball, MU safety valve with circulating hose and test lines to 4,200 psi. Observed ZXP packer set at 3 000 psi~ctitfithe ton of the ZXP at 7 144' md. Fill the IA with 37 bbls SW (-975 ft) and pressure test the IA (7-5/8" csg & Packer) to 1,500 psi with 117 stk for 5 ch minutes. Good test. Bleed to 0 psi. Pressure up the tubing to 4,000 psi to shear release from LEM running tool, bleed to 0 psi. Observed drag drop off when pulling out of seal assembly, TBG and IA on a Vacuum. 22:00 - 00:00 2.00 BUNCO RUNCMP LD 25 joints and POH w /running tool, standing 2-7/8" tubing in Derrick, Maintain continuous hole fill C~3 -20 Bbl/Hr. 24 stands out at 00:00 hours. Continue to receive source water from MPU, due to PBU STP shut down. 10/15/2008 00:00 - 03:00 3.00 BUNCO RUNCMP POH w /running tool, standing 2-7/8" tubing in Derrick. Maintain continuous hole fill (~3 -20 Bbl/Hr. 03:00 - 04:30 1.50 BUNCO RUNCMP BO / LD LEM /ZXP running tool. 04:30 - 05:00 0.50 BUNCO RUNCMP Clean and clear rig floor. 05:00 - 06:00 1.00 BOPSU P RUNCMP ND pitcher nipple and air boot. 06:00 - 06:30 0.50 BOPSU P INTERN Service the Rig and Derrick inspection. Perform pre-tour checks. 06:30 - 08:00 1.50 BOPSU P INTERN NU the Shooting Flange. Spot the slickline unit. Feed the well 20 bbls of source water. 08:00 - 12:00 4.00 EVAL P 1NTERV PJSM with the rig crew and Schlumberger slickline. RU slickline with full pressure control and 10' lubricator extension. Pressure test Lubricator against the top of the blind rams to 500 psi - OK. 12:00 - 12:30 0.50 EVAL P INTERN RIH with 2-7/8" CAT Standing Valve on slickline. 12:30 - 13:30 1.00 EVAL P INTERN Set the 2-7/8" CAT Standing Valve in the XN Nipple at 7,263' 3SMD (7,275' SLMD). Beat down a couple of times to ensure it is set goo .Line up to pump down the Tubing with the Rig pump. Fill the Tubing with source water and it took 27 bbls to catch fluid (-4,655'). Pressure up to 500 psi and shut down the Rig pump. Pressure up to 1,000 Dsi with the Test pump and pressure test to 1,000 psi for 10 charted mins - OK. Bleed off the pressure to zero. Have slickline pull up to open the equalizing ports and allow the Tubing to equalize above and below the CAT Standing Valve. 13:30 - 14:00 0.50 EVAL P INTERN POOH with slickline and 2-7/8" CAT Standing Valve. Resume 20 bbls/hour fill rate with source water. 14:00 - 15:30 1.50 EVAL P INTERN RD slickline and lubricator extension. Recovered the 2-7/8" CAT Standing Valve. 15:30 - 16:30 1.00 BOPSU P INTERN ND the Shooting Flange. 16:30 - 17:30 1.00 BOPSU P INTERN NU the Flow Riser and Air Boot. 17:30 - 19:00 1.50 BUNCO RUNCMP Hang new ESP /Heat trace sheave in Derrick. RU to run ESP completion. Spot the Spooling Unit and load reels. 19:00 - 00:00 5.00 BUNCO RUNCMP PU / MU ESP pump and motor assembly with Centrilift reps. 10/16/2008 00:00 - 05:00 5.00 BUNCO RUNCMP Run ESP completion on 2-7/8" L-80 6.5# EUE 8rd tubing from. Derrick. Utilizing Best-O-Life 2000 pipe dope and MU Torque = 2,300 ft-Ibs. Maintain continuous fill rate at -20 BPH, with no returns. Every 2,000' RIH stop and check conductivity of cable. Fill the Tubing and flush ESP pump with 10 bbls seawater. 1/2 BPM / 1,000 psi. Printed: 10/20/2008 12:30:42 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From. - To 10/16/2008 05:00 - 06:00 06:00 - 06:30 06:30 - 11:00 MPI-19 MPI-19 WORKOVER NABOBS ALASKA DRILLING NABOBS 3S Hours .Task Code i NPT Start: 9/17/2008 Rig Release: 10/17/2008 Rig Number: Page 9 of 9 Spud Date: 8/28/2004 End: 10/17/2008 1.001 BUNCO 0.50 4.50 11:00 - 14:00 3.00 14:00 - 00:00 10.00 10/17/2008 100:00 - 00:30 I 0.501 BUNCO 00:30 - 01:30 I 1.00 01:30 - 02:30 I 1.00 02:30 - 06:30 I 4.00 06:30 - 07:30 I 1.00 07:30 - 08:30 I 1.001 WHSUR I P 08:30 - 13:00 I 4.501 BOPSUR P 13:00 - 15:30 I 2.501 WHSUR I P 15:30 - 17:00 I 1.501 WHSUR I P 17:00 - 18:00 I 1.00 I W HSUR I P Phase ', Description of Operations ___ RUNCMP Start Heat Trace on joint #122 and continue running completion from Derrick. This should give -2,742' and of heat trace coverage to surface. 122 Joints in hole at 05:30 hours. RUNCMP Service the Rig and pre-tour checks. RUNCMP Continue RIH with ESP and Heat Trace on 2-7/8" Tubing from the Derrick. Continue filling the hole with 20 bbls per hour. Stop with 79 stands (158 Jts) in the hole to perform a reel to reel splice. Fill the Tubing and flush the pump with 10 additional bbls of source water at a rate of 0.5 bpm / 900 psi. RUNCMP Perform reel to reel splice on the ESP Cable with Centrilift reps. RUNCMP Resume RIH with ESP and Heat Trace on 2-7/8" Tubing from the Derrick. Maintain 20 bbls per hour fill rate. Flush the pump every 2,000 ft at a rate of 0.5 bpm / 1,000 psi. RUNCMP Continue run ESP / HT completion assembly, PU 3 joints and 10 ft pup from pipe shed. Run total of 207 joints w/ -2,742' and of heat trace. 66 -LaSalle clamps, 5 - protectolizers, Flat guards 6 ft = 438, 4 ft = 1, 3 ft = 29. 1,380- steel bands, 3 - Armster guards. Maintain continuous fill rate at -20 BPH, with RUNCMP Flush pump w/ SW ~ 1/2 BPM / 1,000 psi. Centrilift rep make ESP / HT conductivity test. RUNCMP PUMU landing joint and tubing hanger. Orient hanger, install penetrators with FMC well head tech. RUNCMP Centrilift rep make penetrator splices for ESP and Heat Trace Cables. RUNCMP Establish final PUW = 48K ,SOW = 36K. Attach final band to secure cables on surface making the total 1,381 bands. Land the Tubing Hanger and RILDS with FMC rep. RUNCMP PU T-bar and set 2-1/2" T e "H" TWC with FMC re . Pressure test to 3,500 psi from above for 10 charted mins - OK. RUNCMP Drain the Stack and blow down all lines. Remove Shooting Flange from the Cellar. Move off driller's side steam heater out of the way to lay over the Cradle safely (heater is down for repair). ND BOPE. Place Stack on Cradle flange and lay over in the Cradle. RUNCMP Bring in the 2-9/16" Tree and Adapter Flange into the Cellar. NU the Adapter Flange and Tree with FMC rep. RUNCMP Test the Hanger void to 5,000 psi for 30 minutes with FMC rep - OK. Fill the Tree with diesel and test to 5,000 psi - OK. Obtain final ESP and Heat Trace conductivity readings with Centrilift rep. The ESP Cable: phase to phase = 3.6 Ohms , phase to ground = 1.8 GigaOhms ,The Heat Trace Cable: phase to phase = 4.0 Ohms ,phase to ground = 50 GigaOhms. The pressure at intake = 1,217 psi ,The temperature at intake = 73.8 degF ,The temperature at motor = 72.6 degF. RUNCMP PU Lubricator and pull TWC with Well Suooort_Techs. Set 2-1/2" Type "H" BPV., Secure the Tree and Cellar. The Rig was released at 18:00 hrs on 10/17/2008. Printed: 10/20/2008 12:30:42 PM Tree: 2-9/16" - 5M FMC i Orig. DF elev. = 69.10' (Doyon 14) Wellhead: 11" x 11" 5M FMC M P I - I ~ Orig. GL elev. = 24.80' (Doyon 14) Gen 5, w 2-7/8" FMC Tbg. 2-7/8" T EU 8rd on t&b, 2.5" CIW-H BPV Profile ~~~ 20", 92#/ft, H-40 1L 12' Camco 2-7/8" x1" ' "NOt@„ KBMM-2 Gas lift mandrel 139 10 3/4" 45.5 ppf L-80 & K-55 BTC-M (Drift I D = 10.050, cap. _ .0981 bpf) Collapse / Internal Yield KBMG Gas/8ift mandrel 416` K-55 2090 psi. 3580 psi. L-80 2480 psi. / 5210 psi. K-55 161' thru 2,879' 10 3/4" Howco Float Shoe 2ggg° ~ Heat Trace to 2742' KOP @ 300' 50+ degree from 2500' Camco 2-7/8" x1" 6,416' Max hole angle = 75 degrees @ 6450' MD KBMM-2 Gas lift mandrel I HES 2-7/8" XN-Nipple (2.250" id) 6,556' Tandem Centrilift Pump 7 5/8" 29.7 ppf, L-80, BTC-M casing 18-P75 SXD Pump 6,577' (Drift ID = 6.750", cap = 0.0459 bpf) 141-P6 SXD Pump 2-7/8" 6.5 ppf, L-80 8rd eue tbg. Tandem Centrilift (400 Internals) Intake 600' 6 ( drift id = 2.347" cap = .00592 bpf) , GRSFTX AR H6 Centrilift Tandem Seal section GSB3DBUT SB/SB PFSA 6 606` , Centrilift Motor 114 hp / KMH 6,620' 2330 volt / 30 amps. Phoenix XTO Sensor 6 631' , w/6 fin centralizer Halliburton HRD ZXP Liner 7144` Top Packer LEM sleeve (Internal 18092` 7174` x 4.00" GS FN) Baker LEM #1, 4-1/2" x 7187 7-5/8" 13CR Window in 75/8" Casing @ 7,192' - 7,204' Well Angle @ window = 72° 4-1/2" Hook Hanger inside casing 7,187' 6 3/4` Hole td @ 12,225' Btm Baker Float Shoe 12,198' outside hook point 7,204' 118 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT OA Lateral Baker Tie Back Sleeve 7,315' ~ XN Nipple 2-7/8", 2.323" 7263` Baker ZXP Liner Top Packer 7,326' r Pkg Bore Baker HMC Liner Hng. 7,332' Baker Seal bore ext. 7,340' L-1 Non locating Seal Assy. 7310` / 6 3/4" Hole td @ 9720' Btm HES Type V Float Shoe 9720` 7-5/8" Weatherford Float Collar 7344' 7-5/8" Weatherford Float Shoe 7428' 47 jts. - 4 1 /2" Slotted Liner 8 jts, 12.6# L-80 IBT OB Lateral DATE REV. BY COMMENTS MILNE POINT UNIT 09/13/04 MDO Drilled & Completed Doyon 14 WELL I-19 02/12/05 MDO ESP RWO Nabors -4es 10/17/08 REH ESP RWO/ Install LEM API NO: 50-029-23218-00 0-0 9- 18-60 BP EXPLORATION (p~Kl_ r~ ~ ~ S7ATE ~F A1..~#SKA 11/14/07 Q~L AN~ GAS CC~NSERVATIt3N CC>~IAl1~SSilON BODE. Test Report Subsrtit to: Contractor: Nabors Rig Rep.: G. Sweatt / J. Frrtts Operator: Bp Rep.: W. Hoffman ! D. Rhodes, Field/Unit & Well No.: MP f-'f9 Operation: Drag: Test: initial: x Test Pressure: Rams: 250/3500 Rig No.: 3S DATE: 9/19/2008 Rig Phone: 659-4487 Rig Fax: 659-4486 Op. Phone: 659-4485 Op. Fax: 659-4628 PTD # 2f}47350 Woskover: x Expfor.: Weekly: Bi-UVeekly Annular: 250/3500 Vatires: 250/3500 TEST DATA, MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P 1Ne11 Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK.: Quantity Size Test. Result. CHOKE MANIFO LD: Annular Preventer 1 13 5/8 '5000 I' Quantity Test Result Pipe Rams 1 2 7/8 X 5 P No. Valves 13 P Lower Pipe Rams 0 NA Manual Chokes 1 P Blind Rams 1 Blind P Hydraulic Chokes 1 P Choke Ln. Valves 1 3 1/8'" 5000 P HCR Valves 2 31/8" 5000 FP ACCUMULATOR. SYSTEM: Kill Line Valves 1 2 1/16" 5000 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3050 P Pressure After Closure 1800 P MUD SYSTEM: V~uai Test Alarm Test 200 psi attained 30sec P Trip Tank P P Fi-ff Pressure Attained 1 min 53 sec P Pit Level Indicators P P Bend Switch Covers: AI! stations P Flow Indicator P P Nitgn. Bottles (avgj: t950 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time:. 4=5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, fallow with. written confirmation ts> Supervises at: Remarks: Tested with 2 7/8" and 3 1/2"'test ioint against Twa wav checklareased kill HCR retested snood 24 HOUR l'+IOTICE GNEN YES X NO Waived By Chuck Scheve Date 09118/08 Time: 1030 hrs Witness J. Fritts / D.Rhodes Test start '1700 hrs Finish ~'~~ Sir ~r ?~~$ BOP Test (for rigs) BFL 11/14!07 Nabors 3s 80P Test MP 1-19 9-19-2008.x1s • • ~:~~~ -_ MICROFILMED 03/01 /2008 u.: ~-,,.-' -~ ~ ;$ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doe Permit to Drill 2041350 MD 9720-, REQUIRED INFORMATION )3 tJ~;LÙt.fp DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well Name/No. MILNE PT UNIT SB 1-19 Operator BP EXPLORATION (ALASKA) INC )... #.3 ,¿.f --. ~ '1 API No. 5ß~23218-0o-bo TVD 4088""" Completion Date 9/13/2004 / Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFR 1 CASANDRA, RES, ABI, PWD Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc Logl Data Type J:R> ~ E D Asc :.. D Asc 1:- D Asc e 0 U, ~t ~ D Lis l~ ~ D TIF I~J{ Asc 12946 Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Name Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey G'Ãl"'"'m", Iby ~"" ~..\ l....... Log Log Scale Media Interval Start Stop 7609 9720 7609 9720 7609 9720 7609 9720 o 7799 o 7799 o 7799 o 7799 7457 8532 7457 8532 7457 8532 7457 8532 7640 8468 Run No ~~~,",.:"...t·) 12946 LIS Verification 7488 7734 7640 8468 t \ fl.,¡l# 1/,,:\h. 12945 Gamma ~y 1" "'\.c"'..~:,.. , 12945 LIS Verification T I'¡ il 'f,·...:".4\. 12944 CSffll'l'lB Ray ",,,~V\...t:.,.... n 1 12944 LIS Verification 7488 7734 67 9655 67 9655 . OHI CH Open Open Open Open Open Open Open Open Open Open Open Open Open Received Comments 1017/2004 IIFR I 1017/2004 IIFR i 1017/2004 MWD I 1017/2004 MWD I 1017/2004 IIFR PB1 I 1017/2004 IIFR PB1 I 1017/2004 MWD PB1 I 101712004 MWD PB 1 I 1017/2004 IIFR PB2 ] 1017/2004 IIFR PB2 I 1017/2004 MWD PB2 I 1017/2004 MWD PB2 I 1/27/2005 GRlEWR4/ABIIROP/MWD I PB2 I I Open 1/27/2005 GRlEWR4/ABIIROP/MWD [ PB2 I Open 1/27/2005 PB1 GR/EWR4/ABlfROP/MWD ] Open 1127/2005 PB1 I GRlEWR4/ABI/ROP/MWD I Open 1/27/2005 GRlEWR4/ABIIROP/MWD Open 1/27/2005 GR/EWR4/ABIIROP/MWD I . DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041350 Well Name/No. MILNE PT UNIT SB 1-19 MD 9720 )et:J C Lis Completion Date 9/13/2004 TVD 4088 13575 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y 1ft;¡) Chips Received? ~ Analysis 'N-H- Received? Comments: ~ Compliance Reviewed By: Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L 9720 Open 2/2212006 112 Sent Sample Set Number Comments Received Daily History Received? ~ ~N Formation Tops API No. 50-029-23218-00-00 UIC N - --1 ROP DGR EWR plus Graphics I PB 1 112-7799 ROP DGR EWR plus I Graphics I PB 2 112-8532 ROP DGR EWR plus Graphics_~ -- Date: __7 (')~~ . . . . WELL LOG TRANSMITTAL (~04 - IScJ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1,3575 RE: MWD Formation Evaluation Logs MPI-19 + PBl + PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPI-19 + PBl + PB2: LAS Data & Digital Log Images: 50-029-23218-00, 70, 71 1 CD Rom e;~líJ 1f/ ()þj C{() . STATE OF ALASKA . ALASKÄ AND GAS CONSERVATION CO IssloRECEIVED REPORT OF SUNDRY WELL OPERA TIONi 1'1 Z005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program øa Repair Well øa Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate Alø3ki Oil & r.w.¡ Cons, CarnmisGiol'\ ~n~C2e Out ~SP o Stimulate AnttfEJj'êr- o Waiver 0 Time Extension o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612. Anchorage, Alaska 7. KB Elevation (ft): KBE = 69.1' 8. Property Designation: ADL 025906 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 9720 4088 9720 4088 Casing Length Structural Conductor 78' Surface 2964' Intermediate Production 7395' Liner 2405' 4. Current Well Class: øa Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 204-135-00 6. API Number: 50-029-23218-00-00 99519-6612 9. Well Name and Number: MPI-19 10. Field I Pool(s): Milne Point Unit I Schrader Bluff feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 10-3/4" 2999' 2550' 5210 2480 7-5/8" 7428' 4076' 6890 4790 4-1/2" 7315' - 9720' 4053' - 4088' 8430 7500 Perforation Depth MD (ft): Slotted 7391' - 9591' Perforation Depth TVD (ft): Slotted 4070' - 4095' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# 6634' L-80 N/A NIA Treatment description including volumes used and final pressure: RBDMS 8Ft MAR ] 4 2005 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure 15. Well Class after proposed work: o Exploratory øa Development 0 Service 16. Well Status after proposed work: øa Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Skip Coyner, 564-4395 o Copies of Logs and Surveys run øa Daily Report of Well Operations øa Well Schematic Diagram Printed Name Sondra Stewman ~~~ Form 104ð4Revised 04/2004 Title Technical Assistant POi=( I ~1-~Y\ L Prepared By Name/Number: Date 0')' tJl·oS Sondra Stewman, 564-4750 Submit Original Only ~ 2"9/1 §" -5M FMG ~ellhe~d: t.1 "x 11" 5M FM... Gen 5, W 2-7/8" FMC Tbg. 2 EU 8rd on t&b, 2.5" CIW-H SPV Profile 20", 92#/ft, HAO 103/4" Howco Float Shoe I 2999' I JA KOP @ 300' 50+ degree from 2500' Max hole angle = 75 degrees @ 6450' MD 75/8" 29.7 ppl, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpi) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) Window in 75/8" Casing @ 7,192' - 7,204' Well Angle @ window = 72° 4-1/2" Hook Hanger inside casing 7,187' outside hook point 7,204' Baker Tie Back Sleeve 7,315' Baker ZXP Liner Top Packer 7,326' Baker HMC Liner Hng. 7,332' Baker Seal bore ex!. 7,340' f .4~ / 7-5/8" Weatherford Float Collar 7344' 7-5/8" Weatherford Float Shoe 7428' DATE 09/13/04 02/12/05 REV. BY MDO MDO COMMENTS Drilled & Completed Doyon 14 ESP RWO Nabors -4es MPI-19 OA Lateral ~OB Lateral Orig. DF elev. = 69.10' (Doyon 14) eg. GL elev. = 24.80' (Doyon 14) L Cameo 2-7/8" x1" KBMG Gas lift mandrel ~ Cameo 2-718" x1" KBMG Gas lift mandrel Cameo 2-7/8" x1" KBMG Gas lift mandrel HES 2-7/8" XN-Nipple (2.250" id) Tandem Centrilift Pump 95 stg.GC1700 119 stg. GC8200 GPMTAR 1:1 Tandem Centrilift (400 Internals) Intake GRSFTX AR H6 Centrilift Tandem Seal section 513 GSB3DBUT AB/HSN PFSA I Centrilift Motor 114 hp I KMH 2330 volt I 30 amps. PumpMate w/6 fin centralizer I 167' I I 2,030' I 6,406'1 I 6,578' I 6,597' I I 6,610" 16,602' I 6,616' 16,628'1 16,634'1 L... 63/4" Hole td @ 12,225' Blm Baker Float Shoe 12.198' ~ 1./././././././././ I ~ 118 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT rSS~>S>)'1 1111111,'" ~ 6 314" Hrno <d @ 972œ ,~ "" '",'" '"'' ''"'" "" ~ r,'IIII"'" ~ 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L-80 IBT I' , I I I I I I II MILNE POINT UNIT WELL 1-19 API NO: 50-0?9-?3?18-00 50-0?9-?3?18-60 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 WORKOVER NABORS ALASKA DRILLING J NABORS 4ES Start: 2/10/2005 Rig Release: 2/12/2005 Rig Number: Spud Date: 8/28/2004 End: 2/912005 21 :00 - 00:00 3.00 RIGD P PRE Rig Down and move to MPI-19 2/10/2005 00:00 - 00:00 24.00 MOB P PRE Move to MPI-19, Rig on location at 20:45 2/11/2005 00:00 - 02:00 2.00 MOB P PRE Spot Rig on to location, Accept Rig at 02:00 02:00 - 03:00 1.00 RIGU P PRE Pull BPV, Rig up lines to kill well, fill pits with seawater T/I/O = 1100/1200/130 03:00 - 06:00 3.00 RIGU P PRE PJSM. Spot tiger tank & rig up lines. Rig up lines to kill well. PT lines to 1500 psi, OK. 06:00 - 10:30 4.50 KILL P DECOMP PJSM. Bleed gas from tubing & I/A to tiger tank. Line up & circulate heated seawater @ 4 bpm 1300 psi, down tubing. After circulating tubing volume, bullhead (1) tubing volume @ 3 bpm / 250 psi. Continue cirulating thru choke to tiger tank, not seeing any fluid returns. After pumping 550 bbls (total), close choke & bullhead 225 bbls down itA @ 5 bpm 1350 psi. 10:30 - 11 :00 0.50 KILL P DECOMP Monitor well & blow down lines. Tubing & itA both on vacuum. 11 :00 - 13:00 2.00 BOPSUF P DECOMP PJSM. Set two way check. N/D existing wellhead, (tree, adapter, HCR). 13:00 - 15:00 2.00 BOPSUP P DECOMP PJSM. N/U 135/8" x 5M BOPE & secondary annulus valve. 15:00 - 17:00 2.00 BOPSUP P DECOMP PJSM. Conduct full test as per AOGCC & BP requirements, 350 low & 3500 psi high pressure, @ 5 minutes per test. (1) failure, to be repaired prior to next test. Witnessing of test waived by AOGCC state rep Lou Grimaldi. Tests witnessed by Company man and toolpusher. 17:00 - 18:00 1.00 BOPSUF P DECOMP Test pipe rams- 3 failed attempts at low and high pressure. Decide to replacee rams, have new set of 2-7/8" x 5" varible rams sent from Dead Horse, proceed with Annular and Accumulator Tests. 18:00 - 19:00 1.00 BOPSUP P DECOMP Pressure test BOP annular low and high pressure - test good. Test accumulator - test good. 19:00 - 20:30 1.50 BOPSUF P DECOMP Drain stack and pull out pipe rams. 20:30 - 21 :30 1.00 BOPSUP P DECOMP New set of 2-7/8" x 5" variable pipe rams installed. Start low and high pressure test on pipe rams. 21 :30 - 00:00 2.50 BOPSUF P DECOMP Attempt multiple low and high tests on pipe rams. Could not get rams to hold pressure firmly. Would loose -1 OOpsi in 5 mins on high pressure test. Change to another set of pipe rams. 2/12/2005 00:00 - 01 :00 1.00 BOPSUF P DECOMP Finish installing 2-7/8" rams. Test pipe rams to 350 psi low and 3500 psi high - passed. Re-test failed valve 13 from yesterday, 350 psi low and 3500 psi high - passed. All tests have been witnessed and successfully passed. 01 :00 - 02:00 1.00 BOPSUP P DECOMP Pull TWC 02:00 - 03:00 1.00 KILL P DECOMP Pump 100 bbls of seawater down lA, monitor pressure. IAon vac. 03:00 - 04:00 1.00 PULL P DECOMP Pull hanger to the floor and laydown same. 04:00 - 10:00 6.00 PULL P DECOMP POOH wI ESP completion string, double displacing hole. 10:00 - 12:00 2.00 PULL P DECOMP PJSM. UD ESP assembly. Shaft twisted in seals. 12:00 - 14:30 2.50 RUNCOtvP RUNCMP PJSM. Pick up new ESP assembly. 14:30 - 18:00 3.50 RUNCOtvP RUNCMP RIH wI ESP completion, pumping down tubing & checking conductivity of ESP cable every 2000'. 18:00 - 18:30 0.50 RUNCOtvP RUNCMP M/U Landing Joint Up WT = 44K Down WT = 30K 18:30 - 20:00 1.50 RUNCOtvP RUNCMP Make field connector splice, pump 15 bbls at 1/2 bpm@ 130 psi. RD tubing handling equipment and spooling unit. 20:00 - 20:30 0.50 RUNCOtvP RUNCMP Land hanger and run in lock down screws. Lay down landing joint and install TWC Printed: 2/14/2005 9:25:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/10/2005 Rig Release: 2/12/2005 Rig Number: Spud Date: 8/28/2004 End: 2/12/2005 20:30 - 21 :30 21 :30 - 23:00 1.00 RUNCOW 1.50 RUNCOW RUNCMP Nipple down BOP's RUNCMP Nipple up tree and adapter flange. test void and tree to 5000 psi. POST Pull TWC and set BPV. Secure well and Centrilift perform final check- good. Rig Released at 2400 23:00 - 00:00 1.00 RIGD P Printed: 2/14/2005 9:25:24 AM . . 2-D if - /3Ç WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 17, 2004 RE: MWD Formation Evaluation Logs MPI-19 PB1, AK-MW-3258923 1 LIS formatted Disc with verification listing. API#: 50-029-23218-70 17. <=l-1( ìt PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETI'ER TO THE A ITENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LRZ-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: f Iv . . 2-0 c./ -(35 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 17, 2004 RE: MWD Formation Evaluation Logs MPI-19 PB2, AK-MW-3258923 1 LIS formatted Disc with verification listing. API#: 50-029-23218-71 -111), ~ vl(P PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMIITAL LEITER TO THE ATTENTION OF: Sperry -Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Daœ: ffô Signed:~ J' ~~<I' ~ ~- _ STATE OF ALASKA . ALASKA1IIl AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD , GR , IFRlCASANDRA , RES, ABI , PWD CASING, liNER AND CEMENTING RECORD $ETtINGQEBTH MD SETTING DEBTH1"\tØ BdmoM lOP BdTtdM 112' 34' 112' 2999' 35' 2550' 7428' 33' 4076' 9720' 4053' 4088' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Sox 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2319' NSL, 3521' WEL, SEC. 33, T13N, R10E, UM Top of Productive Horizon: 2136' NSL, 4447' WEL, SEC. 28, T13N, R10E, UM (OS) Total Depth: 4538' NSL, 4284' WEL, SEC. 28, T13N, R10E, UM (OS) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551850 y- 6009437: Zone- ASP4 TPI: x- 550875 y- 6014526 Zone- ASP4 Total Depth: x- 551016 y- 6016929 Zone- ASP4 18. Directional Survey 0 Yes 181 No 22. 20" 10-3/4" 7-518" 4-1/2" 92# 45.5# 29.7# 12.6# H-40 L-80 L-80 L-80 34' 35' 33' 7315' 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Slotted Liner MD TVD MD TVD 7391' - 9591' 4070' - 4095' One Other 5. Date Comp., Susp., or Aband. 09/13/2004 6. Date Spudded 08/28/2004 7. Date T.D. Reached 9/5/2004 8. KB Elevation (ft): KBE = 69.1' 9. Plug Sack Depth (MD+ TVD) 9720 + 4088 10. Total Depth (MD+TVD) 9720 + 4088 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL Revision: 11-02-04 Start Production 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-135 304-303 13. API Number 50- 029-23218-00-00 14. Well Name and Number: MPI-19 15. Field I Pool(s): Milne Point Unit I Schrader Sluff Ft Ft 16. Property Designation: ADL 025906 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 42" 13-1/2" 9-718" 6-3/4" 24. SIZE 2-7/8",6.5#, L-80 25. 260 sx Arctic Set (Approx.) 468 sx AS Lite, 254 sx Class 'G' 757 sx Class 'G' Uncemented Slotted Liner DEPTH SET (MD) 6647' PACKER SET (MD) N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls Dead Crude and 25 Sbls of Diesel. 26. Date First Production: October 20,2004 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD! + Flow Tubing Casing Pressure CALCULATED i + Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl GAs-McF WATER-Bsl Oll-Bsl None RBDMS BFL NOV - 3 2004 Form 10-407 Revised 12/2003 GAs-McF W A TER-SSl r r- ''"\ tAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) RBDMS BFL -:~ ma4 GF .' GEOLOGIC MARKER" 29. .ORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MC NA NB NC NE NF OA 08 5085' 5650' 5665' 5830' 6183' 6543' 6680' 6810' 6900' 7060' 7188' 7300' 3319' 3544' 3550' 3607' 3726' 3828' 3865' 3897' 3920' 3973' 4014' 4048' None 30. List of Attachments: 31. I hereby certify that the foreg?i,r:Jg is true and c.0rrect to the best of my knowledge. Signed .~..--~_ ....-I~ . sondra¡5~~~n~) '"l:'\~~/~ TItle Technical Assistant MPI-19 204-135 304-303 Well Number Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Date t l. - O-¿-04- Sondra Stewman, 564-4750 Skip Coyner, 564-4395 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 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ... I STATEOFALASKA .. ALASKA AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD , GR , IFR/CASANDRA , RES, ABI , PWD CASING, LINER AND CEMENTING RECORD SETTING DEPTH MO Se:T"tINGDEPTH TV!> lOP BOTTOM BOTTOM 34' 112' 34' 112' 35' 2999' 35' 2550' 33' 7428' 33' 4076' 7315' 9720' 4053' 4088' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2319' NSL, 3521' WEL, SEC. 33, T13N, R10E, UM Top of Productive Horizon: 2136' NSL, 4447' WEL, SEC. 28, T13N, R10E, UM (OB) Total Depth: 4538' NSL, 4284' WEL, SEC. 28, T13N, R10E, UM (OB) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551850' y- 6009437' Zone- ASP4 TPI: x- 550875 y- 6014526 Zone- ASP4 Total Depth: x- 551016 r y- 6016929' Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. 20" WriPER Fr. 92# 45.5# 29.7# 12.6# H-40 L-80 L-80 L-80 10-3/4" 7-5/8" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Liner < MD TVD MD TVD 7391' - 9591' 4070' - 4095' 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""'" One Other 5. Date Comp., Susp., or Aband. 09/13/2004 6. Date Spudded 08/28/2004 r 7. Date T.o. Reached 9/5/2004 8. KB Elevation (ft): KBE = 69.1' 9. Plug Back Depth (MD+ TVD) 9720 + 4088 10. Total Depth (MD+TVD) '9720 + 4088' 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 42" 13-1/2" 9-718" 6-3/4" SIZE 2-7/8",6.5#, L-80 25. RECEI\IE[) OCT 1 [) 2004 1b~We~~~ Gas Co. I'. 'i., (',c"c""".'... . '..." '.¡jUfii~r,t~;gfÜf 181 Developm!AltelQ-fMploratory . o StratigraphicLl '§e'ivice 12. Permit to Drill Number 204-135 304-303 13. API Number 50- 029-23218-00-00 14. Well Name and Number: MPI-19i 15. Field I Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 025906 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PUllED 260 sx Arctic Set (Approx.) 468 sx AS Lite, 254 sx Class 'G' 757 sx Class 'G' Uncemented Slotted Liner TUBING DEPTH SET (MD) 6647' PACKER SET (MD) N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls Dead Crude and 25 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BBl GAs-McF WATER-BBl Oll-BBl 27. GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none", None ORIGI~\lAL CONTINUED ON REVERSE SIDE ;:;:tí~ Form 10-407 Revised 12/2003 T . ',:;;i::: ì~?:t:i~ê{ .0'1 \ !l~:ig~!J \ ~-'.''''., ¡ I \!t11{W \ \~.=J ~ç ftMlt15 28. . 29. eRMATlON TESTS GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MC NA NB NC NE NF OA OB 5085' 5650' 5665' 5830' 6183' 6543' 6680' 6810' 6900' 7060' 7188' 7300' 3319' 3544' 3550' 3607' 3726' 3828' 3865' 3897' 3920' 3973' 4014' 4048' None RECE OCT 1 52004 A!aska Oi! & 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and Leak Off Test Summary. 31. I hereby certify that the fore Signed Technical Assistant Date (0 ·-1 L~-OY MPI-19i Well Number Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Skip Coyner, 564-4395 Permit No. I 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ 2-9/16"-5M FMC . Wellhead: 11"x11"5MFM· . Gen 5, w 2-7/8" FMC Tbg. 2- EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 Å DJÐ " Note" 103/4" 45.5 ppf L-80 & K-55 BTC-M (Drift ID = 10.050, cap. = .0981 bpf) Collapse / Internal Yield K-55 2090 psi. / 3580 psi. L-80 2480 psi. / 5210 psi. K-55 161' thru 2,879' 103/4" Howco Float Shoe I 2999' I .oIIIIIIII KOP @ 300' 50+ degree from 2500' Max hole angle = 75 degrees @ 6450' MD 7 5/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) Window in 75/8" Casing @ 7,192' - 7,204' Well Angle @ window = 72° 4-1/2" Hook Hanger inside casing 7,187' outside hook point 7,204' Baker Tie Back Sleeve 7,315' Baker ZXP Liner Top Packer 7,326' Baker HMC Liner Hng. 7,332' Baker Seal bore ext. 7,340' ~ .i /~ 7-5/8" Weatherford Float Collar 7344' 7-5/8" Weatherford Float Shoe 7428' DATE 09/13/04 REV. BY MDO COMMENTS Drilled & Completed Doyon 14 MPI-19 OA Lateral ~B Lateral l Orig. DF elev. = 69.10' (Doyon 14) .. GL elev. = 24.80' (Doyon 14) Cameo 2-7/8" x1" KBMG Gas lift mandrel I 178' I ~ Cameo 2-7/8" x1" KBMG Gas lift mandrel I 2,041' I Cameo 2-7/8" x1" KBMG Gas lift mandrel 1 6,416' I HES 2-7/8" XN-Nipple (2.250" id) 16,568'1 Centrilift Pump 122 stg./ GC2200 GPMTAR 1:1 16,589' 1 Centrilift Intake 400 internals Model - GRSTXAR 16,610' 1 Centrilift Tandem Seal section 513 GSB3DBUTILH6PFSA GSB3DBL TH6FSA 16,615' I 16,629' I 16,641' I I 6,647' I Centrilift Motor 133 hp / KMH 2205 volt / 37 amps. PumpMate w/6 fin centralizer L... 63/4" Hole td @ 12,225' Btm Baker Float Shoe 12.198' ~ 1/////////1 ~ 118 jts. - 4 1/2" Slotted Liner 1 its, 12.6# L-80 IBT r~~~SSSS1 I I I I I I I I I II b Y4" Ho, M @ 9720 "'" H" "" V"". ,.., "'" '- rIIIIIIII¿¡ ~ 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L-80 IBT I' I I I I I I I II .MILNE POINT UNIT WELL 1..19 API NO: 50-029-23218-00 50-029-23218-60 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 8/27/2004 07:00 - 08:00 1.00 MOB P PRE PJSM, Skid rig floor 08:00 - 09:00 1.00 MOB P PRE Move off well, center rig on pad 09:00 - 11 :00 2.00 MOB P PRE Shuffle and double up rig mats, set approach 11 :00 - 12:00 1.00 MOB P PRE Move rig to MPI-19, spot over well 12:00 - 13:00 1.00 MOB P PRE Skid rig floor, rig up 13:00 - 15:00 2.00 RIGU P PRE Nipple up Diverter, Rig was accept @ 11 :00 hrs 8/27/2004 due to Poor pad conditions 15:00 - 22:00 7.00 DRILL P SURF Rig up and picking up pipe and standing in derrick, total of 78 stands, mixing spud mud 22:00 - 00:00 2.00 DRILL P SURF Pickup BHA #1, Orient Bha 8/28/2004 00:00 - 01 :00 1.00 DRILL P SURF Diverter Test, the right to witness test was wavier by John Chrisp AOOGC, rig up Sperry- Sun Gyro unit 01 :00 - 02:00 1.00 DRILL P SURF Spud meeting with all hands, fill hole with mud check for leaks 02:00 - 03:30 1.50 DRILL P SURF Spud well, drill 112' to 254' 03:30 - 04:00 0.50 DRILL P SURF Pooh to pickup flex dc, 04:00 - 05:30 1.50 DRILL N DFAL SURF Check MWD, install new probe in MWD 05:30 - 06:00 0.50 DRILL P SURF Picking up flex dc, Rih 06:00 - 23:30 17.50 DRILL P SURF Drill 256' to 1,977' with 80 rpm. 513 gpm, 2000 psi,AST 6.37, Art 5.73, (Run Gyros every 100 ft from 254' to 632') 23:30 - 00:00 0.50 DRILL P SURF Circ 2 bottoms up, with 513 gpm, 2000 psi, 80 rpms 8/29/2004 00:00 - 00:30 0.50 DRILL P SURF Finish Circ 2 bottoms up, with 513 gpm, 2000 psi, 80 rpms 00:30 - 01 :30 1.00 DRILL P SURF Pumping out to HWDP at full drilling rate 01 :30 - 02:00 0.50 DRILL P SURF Trip back to bottom, ream last stand to bottom 02:00 - 10:00 8.00 DRILL P SURF Drill 1,977' to 3,010' with 80 rpm. 513 gpm, 2400 ps 10:00 - 12:30 2.50 CASE P SURF Circ 2 bottoms up with 513 gals min., 2280 psi, 80 rpms 12:30 - 13:30 1.00 CASE P SURF Pump out with full drilling rate to 1400', hole not taking proper fill 13:30 - 14:00 0.50 CASE P SURF Rih to 2950', wash to bottom 3010' 14:00 - 15:30 1.50 CASE P SURF Circ. 2 bottoms up, weight up to 9.6, flow check, well static 15:30 - 17:00 1.50 CASE P SURF Pump out to HWDP, with full drilling rate 17:00 - 18:30 1.50 CASE P SURF Stand back HWDP, lay down BHA 18:30 - 19:30 1.00 CASE P SURF Clear floor 19:30 - 20:30 1.00 CASE P SURF PJSM, Rig up to pick up 103/4 Csg 20:30 - 23:30 3.00 CASE P SURF Picking up 10 3/445.5# L-80 and K-55 csg, total of 5 jts L-80, 66 jts K-55, shoe @ 2999' float @ 2921', pickup wt 180K, S/o 120K 23:30 - 00:00 0.50 CASE P SURF Rig down Franks tool, rig up cement head 8/30/2004 00:00 - 01 :30 1.50 CASE P SURF Circ and Thin mud for cement job. 01 :30 - 04:00 2.50 CEMT P SURF Cement with Schlumberger Pumped 5 bbls water, test lines to 3500 psi, 20 bbls water,20 bbls, CW-100, 75 bbls 10.2 Mud push, drop top plug, 468 sxs. 370 bbls ASL cement mixed @ 10.7,8 bbls min. 200 psi, Tail with Class G 253 sxs, 52 bbls, mixed @ 15.8,8 bbls min. 200 psi, dropped bottom plug, kicked plug with 30 bbls water, displace with rig pump with 9.6 mud 7 bbls 600 psi, Bump plug with 1500 psi, floats held, 190 bbls good cement to surface 04:00 - 05:30 1.50 CASE P SURF Flush Diverter, lines, clear rig floor 05:30 - 06:30 1.00 CASE P SURF Nipple down Diverter 06:30 - 09:30 3.00 CASE P SURF Nipple up starting head, test to 1000 psi for 10 min., Nipple up BOP stack 09:30 - 10:30 1.00 CASE P SURF Change out bales, install test plug, rig up for Bop test 10:30 - 13:30 3.00 CASE P SURF Testing BOPS and Manifold with 250-3500 psi for 5 min. per test, Hydrill 250-2500 psi 5 min. per test, the right to witness Printed: 9/20/2004 11: 12:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/27/2004 9/13/2004 Spud Date: 8/28/2004 End: 9/13/2004 8/30/2004 10:30 - 13:30 3.00 CASE P SURF test was wavier by John Crisp AOOGC, 13:30 - 14:00 0.50 CASE P SURF Install wear ring 14:00 - 16:00 2.00 CASE P SURF Picking up BHA # 2, XR bit w/3X15 1X10 jets, 7" sperry drill with 1.5 bend, float sub,Stab, HCIM" Dm, Tm,3 Flex dC,6 Hwdp,jars,3 hwdp, 17 - 5" drill pipe, reamer, 1- 5" drill pipe 16:00 - 17:00 1.00 CASE P SURF RIH to 2900' 17:00 - 18:00 1.00 CASE P SURF Service Top drive, cut and slip drilling line 18:00 - 19:00 1.00 CASE P SURF Test csg to 2000 psi for 30 min. 19:00 - 19:30 0.50 DRILL P INT1 Drill cement and shoe track to 2999', Drill new hole from 3010 to 3030 19:30 - 20:30 1.00 DRILL P INT1 Circ bottoms up, Displace hole with new 9.0# LSND mud 20:30 - 21 :00 0.50 DRILL P INT1 FIT with 9.0 mud wt. 265 psi, TVD 2549 = EMW 11.0 21 :00 - 00:00 3.00 DRILL P INT1 Drill 3030' to 3606 with 500 gpm, 1800 psi, 80 rpms, AST .36, ART 1.6, TO 7K 8/31/2004 00:00 - 10:00 10.00 DRILL P INT1 Directional Drill from 3606' to 5110' - WOB 15 to 20 - PRM 90 - TO on 6 - off 5 - GPM 550 - PP on 2420 - off 2200 - PU 120- SO 85 . ROT 95 10:00 - 11 :00 1.00 DRILL P INT1 CBU 2 X - GPM 550 - PP 2170 - RPM 100 - TO 5 11 :00 - 12:30 1.50 DRILL P INT1 Pump out from 5110' to 3000' to shoe @ drilling rate 12:30 - 13:30 1.00 DRILL P INT1 CBU - Clay balls to surface - Circulate hole clean 13:30 - 14:00 0.50 DRILL P INT1 RIH to 5050' - Precauctionary wash to btm from 5050' to 5110' 14:00 - 00:00 10.00 DRILL P INT1 Directional Drill from 5110' to 6294' - WOB 10 to 20 - PRM 80 - TO on 9 - off 6 - GPM 550 - PP on 2690· off 2470 - PU 150- SO 80 - ROT 105 9/1/2004 00:00 - 17:00 17.00 DRILL P INT1 Directional Drill from 6294' to 7438' - TD 9 7/8" hole - WOB 20 to 25 - RPM 80 - TO on 9 - off 8 - GPM 550 - PP on 3090 - off 2850 - PU 155 - SO 80 - ROT 105 17:00 - 18:30 1.50 CASE P INT1 CBU 2 X - GPM 550 - PP 2800 - RPM 90 - TO 8 - Flow check - Well static 18:30 - 20:00 1.50 CASE P INT1 Pump out to 5000' from 7438' - Pump at drlg rate - Slight pack off @ 6920' - No other problems 20:00 - 21 :00 1.00 CASE P INT1 CBU 2 X - Lots of cuttings over shakers 21 :00 - 21 :30 0.50 CASE P INT1 RIH from 5000' to 7350' - Wash to btm from 7350' to 7438' - No problems - Hole in good shape 21 :30 - 23:30 2.00 CASE P INT1 CBU 3 X - GPM 550 - RPM 100 - PP 2850 - Flow check - Well static 23:30 - 00:00 0.50 CASE P INT1 Pump out to shoe from 7438' to 6100' - Pump out at drilling rate 9/2/2004 00:00 - 03:00 3.00 CASE P INT1 Con't pump out to shoe from 6100' to 3000' - Pump at drlg rate - No problems 03:00 - 03:30 0.50 CASE P INT1 CBU 3 X - GPM 550 - PP 1850 03:30 - 04:00 0.50 CASE P INT1 Flow check - Well static - Pump dry job 04:00 - 05:00 1.00 CASE P INT1 Con't POH to BHA from 3000' to 1015' 05:00 - 07:00 2.00 CASE P INT1 Lay down 97/8" BHA - Flush motor - Clear rig floor 07:00 - 07:30 0.50 CASE P INT1 Pull wear ring and Install test plug 07:30 - 09:00 1.50 CASE P INT1 Change out pipe rams to 7 518" casg rams - Test door seals to 1500 psi 09:00 - 10:00 1.00 CASE P INT1 Rig up casing tools 10:00 - 10:30 0.50 CASE P INT1 PJSM on running 7 5/8" casing 10:30 - 13:00 2.50 CASE P INT1 Pick up float joints - Check floats - Con't picking up and running 75/8" 29.7# L-80 BTC-M casing to 2997' 13:00 - 13:30 0.50 CASE P INT1 Circulate casg volume - 137 bbls - 1380 strokes 13:30 - 16:00 2.50 CASE P INT1 Con't run 7 5/8" casg from 2997' to 7351' - Break circulation Printed: 9/20/2004 11:12:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/27/2004 9/13/2004 Spud Date: 8/28/2004 End: 9/13/2004 9/212004 13:30 - 16:00 2.50 CASE P INT1 and circ last joint down 16:00 - 16:30 0.50 CASE P INT1 Pick up landing joint - Make up hanger - RIH from 7351' to 7428' - Land casing - Rig down Franks fill up tool - Rig up Dowell cementing head and cement lines - Shoe Depth 7428' - Float Collar 7344' 16:30 - 19:00 2.50 CASE P INT1 Circulate two casing volumes - 682 bbls - 6840 strokes - Condition mud for cementing 7 5/8" casing - BPM 6 - PP 500 19:00 - 21 :30 2.50 CEMT P INT1 Give to Schlumberger Dowell Pump 5 bbls water Test cement lines to 3500 psi Pump 25 bbls CW-100 Pump 35 bbls MudPush 11 mixed @ 10.3 ppg - Pump at 5 bpm @ 350 psi Drop bottom plug Mix and pump 157 bbls 15.8 ppg cement yield 1.16 cutVsx 757 sxs Class "G" - Pump rate 5.5 bpm @ 325 psi Drop top plug Displace with 353.6 bbls of Oil base mud - (Calulated bbls 337.4 bbls) Pump rate 6 bpm @ 925 psi Bump plug with 1950 psi 1000 psi over circulating pressure - Hold for 3 mins - Bleed off - Floats holding CIP @ 19:30 hrs 21 :30 - 22:00 0.50 CASE P INT1 Rig down cementing head and lines - Flush stack with fresh water - Blow Oil base mud out of landing joint - Blow down choke and kill lines - Lay down landing joint 22:00 - 00:00 2.00 CASE P INT1 Rig down casing tools - Lay down casing tools - Cementing head - 9/3/2004 00:00 - 01 :00 1.00 CASE P INT1 Install 7 5/8" pack-off - Test to 5000 psi - Hold for 15 mins- Test good 01 :00 - 02:30 1.50 CASE P INT1 Install test plug - Change 7 5/8" casing rams to drill pipe rams - Test rams to 250 low - 3500 high for 5 mins each test - 02:30 - 03:00 0.50 CASE P INT1 Pull test plug - Install wear ring - Rig down testing equipment - Change bails on top drive - Install elevators 03:00 - 03:30 0.50 CASE P INT1 Rig service 03:30 - 05:00 1.50 CASE P INT1 Moblize BHA - Make up 6 3/4" bit - Motor - MWD - Orient same - Con't pick up BHA 05:00 - 05:30 0.50 CASE P INT1 Purge pumps - Surface test MWD 05:30 - 10:00 4.50 CASE P INT1 RIH with BHA # 3 - Picking up 4" DP from pipe shed to 4780' - Con't RIH on DP from 4780' to 7342' tag float collar 10:00 - 10:30 0.50 CASE P INT1 Test casing to 2500 psi for 30 mins - Test good 10:30 - 11 :30 1.00 CEMT P INT1 Drill float equip from 4742' to 7428' - Drill 20 new hole from 7438' to 7458' 11 :30 - 12:30 1.00 CASE P INT1 CBU - Circulate condition mud for FIT 12:30 - 13:00 0.50 EV AL P INT1 Preform FIT - TVD 4077' - MD 7328' - Mud weight 9 ppg - Surface pressure 635 = EMW 12 ppg 13:00 - 14:30 1.50 DRILL P PROD1 Directional Drill from 7458' to 7639' - DHT Failure - WOB 8- RPM 80 - TQ on 4 - off 3 - GPM 252- PP on 2480 - off 2290 - PU 125 - SO 85 - ROT 105 14:30 - 15:30 1.00 DRILL N DFAL PROD1 CBU - For trip due to DHT failure· Flow check· Well static 15:30 - 18:00 2.50 DRILL N DFAL PROD1 POOH from 7639' to BHA @ 267' 18:00 - 20:30 2.50 DRILL N DFAL PROD1 Down load MWD - Change out motor - Orient - Up load MWD - Surface test 20:30 - 23:00 2.50 DRILL N DFAL PROD1 RIH from 268' to 7375' - Fill pipe every 25 stands on trip in Printed: 9/20/2004 11: 12:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 9/3/2004 23:00 - 00:00 1.00 DRILL P PROD1 Cut drlg line - Top drive service - Rig service 9/4/2004 00:00 - 00:30 0.50 DRILL N DFAL PROD1 Con't RIH from 7375" to 7639' 00:30 - 02:30 2.00 DRILL P PROD1 Directional Drill from 7639' to 7799' - Prepare to POH to 7480' for open hole sidetrack - (Dip went from flat to 2 + degree - found top of sand (not a real clean sand at 7720') - WOB 8 to 10 - RPM 80 - TO on 4 - off 3.4 - GPM 275 - PP on 2950 - off 2700 - PU 128 - SO 85 - ROT 105 02:30 - 03:00 0.50 DRILL P PROD1 Pull from 7799' to 7488' - For open hole sidetrack 03:00 - 03:30 0.50 DRILL P PROD1 Cut trough from 7488' to 7498' 03:30 - 16:00 12.50 DRILL P PROD1 Directional Drill from 7488' to 8532' - Prepare to POH to 7640' for open hole sidetrack - WOB 8 to 10 - RPM 80 - TO on 4 - off 3.4 - GPM 297 - PP on 3240 - off 3090 - PU 140 - SO 65 - ROT 100 16:00 - 16:30 0.50 DRILL P PROD1 Pump out from 8532' to 7640' 16:30 - 18:30 2.00 DRILL P PROD1 Cut trough from 7640' to 7657' 18:30 - 00:00 5.50 DRILL P PROD1 Directional Drill from 7640' to 7790' - WOB 8 to 10 - RPM 80 - TO on 4.5 - off 3.4 - GPM 297 - PP on 3100 - off 2970 - PU 135 - SO 80 - ROT 1 02 9/5/2004 00:00 - 16:00 16.00 DRILL P PROD1 Directional Drill from 7790' to 9720' - TD OB Lateral - WOB 5 to 10- RPM 80 - TO on 5 - off 4 - GPM 297 - PP on 3360 - off 3190 - PU 135 - SO 70 - ROT 100 16:00 - 19:30 3.50 CASE P PROD1 CBU 5 X - GPM 300 - PP 3100 - RPM 100 - TO 4.5 19:30 - 22:00 2.50 CASE P PROD1 Pump out from 9720' to shoe @ 7640' - Pump out at drlg rate - Work through sidetracks @ 7640' to 7660' - 7488' to 7518'- Con't POH to shoe @ 7400' - Hole in good shape no problems 22:00 - 23:00 1.00 CASE P PROD1 CBU 2 X - GPM 300 - PP 2600 - RPM 60 23:00 - 00:00 1.00 CASE P PROD1 Orient to low side - RIH from 7400' to 9630' - Ream 90' to btm from 9630' to 9720' - No problems running in hole 9/6/2004 00:00 - 02:30 2.50 DRILL P PROD1 CBU 3 X - GPM 300 - RPM 100 - TO 5 - PP 3200 - Flow Check - Well static 02:30 - 04:00 1.50 DRILL P PROD1 Pump out to shoe from 9720' to 7400' - Pump at drlg rate - No problems 04:00 - 05:00 1.00 DRILL P PROD1 CBU 1 X - GPM 300 - RPM 60 - TO 3k - PP 2900 - Flow check - Well static 05:00 - 05:30 0.50 DRILL P PROD1 Top Drive Service 05:30 - 08:00 2.50 DRILL P PROD1 POOH to BHA from 7400' to 268' 08:00 - 09:00 1.00 DRILL P PROD1 Stand back and lay down BHA 09:00 - 10:00 1.00 DRILL P PROD1 Clear rig floor 10:00 - 10:30 0.50 DRILL P PROD1 Rig up casing equipment for running of 4.5" slotted liner 10:30 - 13:00 2.50 DRILL P PROD1 PJSM - PU 47 joints of 4.5" 12.6# L-80 BTC slotted liner - 9 joints of solid liner - Total 56 joints ran - Make up Baker liner hanger - ZXP Liner top packer - 13:00 - 16:30 3.50 DRILL P PROD1 Con't RIH with liner on DP to 9720' - Tag bottom - Pick up 1 foot to 9719' - Top liner 7315' 16:30 - 17:30 1.00 DRILL P PROD1 Drop ball - Pump at 22 spm - Ball on seat - Pressure up to 2000 psi set hanger - Pressure up to 4000 psi set XZP liner top packer - Release from liner 17:30 - 18:00 0.50 DRILL P PROD1 CBU - Flow check - Well static 18:00 - 20:30 2.50 DRILL P PROD1 POOH with Baker running tools - Lay down Baker running tool 20:30 - 21 :30 1.00 STWHIP P PROD2 PU Dc's and 3 1//2" HWT - Stand back in derrick 21 :30 - 23:00 1.50 STWHIP P PROD2 Pick up Baker Whipstock assy - Orient - Con't PU BHA - Surface test 23:00 - 00:00 1.00 STWHIP P PROD2 RIH with Baker whipstock assy Printed: 9/20/2004 11: 12:25 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/27/2004 9/13/2004 Spud Date: 8/28/2004 End: 9/13/2004 91712004 00:00 - 02:30 2.50 STWHIP P PROD2 RIH with Baker Whipstock to 7207' - Filling every 25 stds - 02:30 - 03:00 0.50 STWHIP P PROD2 Orient whipstock 13 degree to left of high side - RIH tag up 7329' which puts TOW @ 7192' - Set 22K down to set anchor - Pull 15K over pick up weight to confirm anchor set - Set 43K down 3 times to shear off 03:00 - 08:00 5.00 STWHIP P PROD2 Milling OA window from 7192' to 7204' 08:00 - 09:00 1.00 STWHIP P PROD2 CBU - Pump sweep - RPM 100 - TO 5K - GPM 347 - PP 2900 09:00 - 12:00 3.00 STWHIP P PROD2 Flow check - Well Static - POH from 7170' to 876' @ BHA- 12:00 - 13:00 1.00 STWHIP P PROD2 Lay down milling assy 13:00 - 13:30 0.50 STWHIP P PROD2 MU stack washer - Flush BOP stack 13:30 - 14:30 1.00 DRILL P PROD2 MU Drlg BHA - Orient - Flow test 14:30 - 16:00 1.50 DRILL P PROD2 RIH from 268' to 6140' 16:00 - 17:00 1.00 DRILL P PROD2 PU 33 joints of 4" HWT 17:00 - 17:30 0.50 DRILL P PROD2 Base line ECD 10.3 ppg - Orient for window exit - Slide through window 17:30 - 00:00 6.50 DRILL P PROD2 Directional Drill from 7212' to 7817' - WOB 2 to 5 - RPM 80 to 90 - TO on 5 - off 4 - GPM 290 - PP on 2800 - off 2680 - PU 145 - SO 95 - ROT 115 9/8/2004 00:00 - 16:00 16.00 DRILL P PROD2 Directional Drill from 7817' to 9065' - WOB 2 to 5 - RPM 80- TO on 6 - off 5 - GPM 297 - PP on 3440 - off 3330 - PU 145 - SO 75 - ROT 110 - ECD 10.8 ppg 16:00 - 18:00 2.00 DRILL P PROD2 Pump swep - CBU 2 X - Circulate clean hole - Reduce ECD to 10.45 ppg 18:00 - 00:00 6.00 DRILL P PROD2 Directional Drill from 9065' to 10170' - WOB 2 to 5 - RPM 80 - TO on 7 - off 5 - GPM 290 - PP on 3480 - off 3350 - PU 150- SO 68 - ROT 106 - ECD 10.92 9/9/2004 00:00 - 04:00 4.00 DRILL P PROD2 Directional Drill From 10170' to 10506' - ECD 11.34 ppg - WOB 2 to 5 - RPM 80 - TO 6.5 - off 5 - GPM 297 - PP 3700 - off 3550 - PU - 150 - SO 55 - ROT 105 04:00 - 06:30 2.50 DRILL P PROD2 Pump sweep - CBU 3 X - GPM 300 - PP 3750 - RPM 100 - TO 7.5 06:30 - 09:30 3.00 DRILL P PROD2 Pump to shoe @ drlg rate with 50 RPM rotary 09:30 - 11 :00 1.50 DRILL P PROD2 Cut drlg line - Service top drive - Check saver sub for wear @ 7100' 11 :00 - 13:00 2.00 DRILL P PROD2 Orient to high side - RI H from 7100' to 10410' - Precauctionary wash from 10410' to 10506' - PU 155 - SO 55 - ROT 105 before short trip - After on bottom PU 135 - SO 85 - ROT 105 13:00 - 23:00 10.00 DRILL P PROD2 Directional Drill from 10506' to 11658' - WOB 2 to 5 - RPM 80 - TO 7 - off 5 - GPM 297 - PP 3860 - off 3760 - PU - 160 - SO 52 - ROT 106 - ECD 11.46 23:00 - 00:00 1.00 DRILL P PROD2 Pump sweep - CBU clean up hole due to high ECD - RPM 92 - TQ 7 - GPM 297 - ICP 3760 9/10/2004 00:00 - 02:00 2.00 DRILL P PROD2 Circulate to clean up hole - GPM 297 - PP 3620 - RPM 92- TO 7 - (PU 160 - SO 52 - ROT 106) 02:00 - 07:30 5.50 DRILL P PROD2 Directional Drill from 11658' to 12225' - TD OA Lateral - WOB 4 to 6 - RPM 90 - TO 7 - off 7 - GPM 297 - PP 3780 - off 3690 - PU 155 - SO 55 - ROT 106 - ECD 11.34 ppg - PU 165 - SO 70 without pump 07:30 - 10:30 3.00 CASE P PROD2 Pump sweep - CBU 3 X - RPM 100 - TO 7 - GPM 300 - PP 3850 psi 10:30 - 15:30 5.00 CASE P PROD2 Pump out to shoe - Backreaming @ 35 rpm - Pump @ drlg rate - Pump to 7282' - Pull through whipstock from 7282' to 7186' without rotating or pumping - TOW 7192' - Observe well - Well Printed: 9/20/2004 11:12:25AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 9/10/2004 10:30 - 15:30 5.00 CASE P PROD2 static 15:30 - 17:30 2.00 CASE P PROD2 Orient to high side - RI H from 7168' to 12140' - Precauctionary wash from 10140' to 12225' - PU 125 - SO 85 17:30 - 20:30 3.00 CASE P PROD2 CBU 3 X - GPM 255 - PP 3450 - RPM 100 - TO 7 - ECO's 10.8 ppg to 11.0 ppg - Flow check - Well static - PU 155 - SO 80 20:30 - 00:00 3.50 CASE P PROD2 Pump out from 12225' to 8050' - Pump rate 250 GPM - No Backreaming 9/11/2004 00:00 - 01 :00 1.00 CASE P PROD2 Con't pump out from 8050' to 7282' - Pull through window from 7282' to 7073' without pumping or rotating - 01 :00 - 01 :30 0.50 CASE P PROD2 CBU - 80 RPM - TO 4 - GPM 290 - PP 2600 01 :30 - 04:00 2.50 CASE P PROD2 POH from 7050' to BHA @ 268' 04:00 - 04:30 0.50 CASE P PROD2 Stand back BHA / LD BHA 04:30 - 05:30 1.00 CASE P PROD2 Down load MWD 05:30 - 06:00 0.50 CASE P PROD2 Flush motor - Lay down same 06:00 - 07:00 1.00 CASE P PROD2 Make up Baker retrieving assy - Surface test MWD - 71 spm @ 1390 psi 07:00 - 09:00 2.00 CASE P PROD2 RIH from 825' to 7130' - Filling every 25 stands 09:00 - 09:30 0.50 CASE P PROD2 Orient hook - Latch onto whipstock - PU 170 - Release unloader sub - PU 190 set jars off to release whipstock - Flow check well- Well static 09:30 - 10:00 0.50 CASE P PROD2 CBU - GPM 305 @ 2570 psi 10:00 - 13:30 3.50 CASE P PROD2 POH with whipstock 13:30 - 16:00 2.50 CASE P PROD2 Handle BHA - Stand back 31/2" HWT - 4 3/4" DC's - Lay down MWD - Break down Baker retrieving tools and whipstock - Tailpipe assy - Service break Baker tools 16:00 - 16:30 0.50 CASE P PROD2 LD Baker equipment - Clean rig floor 16:30 - 17:00 0.50 CASE P PROD2 Rig up 4 1/2" Slotted liner running tools 17:00 - 21 :00 4.00 CASE P PROD2 PJSM - Pick up and run 41/2" slotted liner - 120 joints 4 1/2" L-80 12.6# IBT liner - Total of 163 straight bladed centtralizers ran and 119 stop rings - Make up Baker hook wall hanger - PU 92K SO 80K - Block weight 50K 21 :00 - 00:00 3.00 CASE P PROD2 RIH from 5018' to 9049' with liner on DP - Exited window after fouth attempt - Liner weight at windowPU 110K - SO 87K- Block weight 50K 9/12/2004 00:00 - 02:00 2.00 CASE P PROD2 Con't RIH with 4 1/2" slotted liner from 9049' to 12173' - PU 160 - SO 83 - Block weight 50K 02:00 - 03:30 1.50 CASE P PROD2 Hook wall hanger in BOW @ 7204' Float shoe @ 12198' - Pick up turn pipe 1/4 turn - RIH hook wall hanger to 7214' float shoe to 12210' - Pick back up to 12173' turn pipe three times to get hook wall hanger to hook at 7204' BOW - Float shoe at 12198' - Hook set with 25K on BOW - Drop setting ball pump for 300 strokes at 30 @ 530 psi and 350 strokes at 20 spm @ 350 psi - Ball on seat - Pressure up to 3500 psi to release from hanger - Bleed off pressure - Pick up 25' to confirm released from liner - String weight 135K lost 25K string weight - Pressure up to 3800 psi with rig pump - Isolate rig pump - Con't pressure up with test pump to shear out @ 4300 psi - Pull 2 stds 03:30 - 05:00 1.50 CASE P PROD2 Cut drlg line - Top Drive service - Rig service 05:00 - 08:00 3.00 CASE P PROD2 POH with Baker hook wall hanger running tools 08:00 - 08:30 0.50 CASE P PROD2 Lay down hook wall liner running tools / Clean rig floor 08:30 - 11 :30 3.00 CASE P PROD2 MU circ sub and RIH to 7175' 11 :30 - 12:30 1.00 CASE P PROD2 Circulate mud @ 275 GPM - PP 1800 - RPM 80 - TO 6K- PJSM on displacement Printed: 9/20/2004 11: 12:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 9/12/2004 12:30 - 15:00 2.50 CASE P PROD2 Displace OBM with 9.3 ppg Brine - Pump 50 bbls L VT 30 bbls Hi-Vis Brine @ 9.3 ppg 40 bbl Safe-Sure "0" pill 30 bbls Hi-Vis Brine @ 9.3 ppg 9.3 Brine Clean surface equipment - Flush Kill line - Choke manifold - Hole fill lines - Observe well - Well static 15:00 - 23:30 8.50 CASE P PROD2 POOH from 7175' to 736' Laying down 4" drill pipe - RIH from 736' to 3325' with 4" Drill pipe from derrick - Lay down pipe and HWT from 3325' 23:30 - 00:00 0.50 CASE P PROD2 Pull wear ring - Moblize tubing jewelery to rig floor - 9/13/2004 00:00 - 01 :00 1.00 RUNCOtvP RUNCMP Moblize tubing equipment 01 :00 - 02:00 1.00 RUNCOtvP RUNCMP PJSM Running ESP completion - RU tubing running equipment 02:00 - 05:00 3.00 RUNCOtvP RUNCMP PU / MU 2 7/8" ESP pump assy - Test 05:00 - 16:00 11.00 RUNCOtvP RUNCMP Run 2 7/8" 6.5# tubing and ESP cable - Perform ESP cable integrity test / fill pipe after 1000' and every 2000' on trip in hole 16:00 - 16:30 0.50 RUNCOiIIP RUNCMP Make up tubing hanger - (Ran 207 joints 27/8" 6.5# EUE 8 rd tubing - Ran 5 ea protectolizers - 3 ea flat guards - 111 La Salle clamps 1 per joint from jt# 1 through 19 - 1 every other joint from jt #20 to 207 - 1 on each end of GLM's) - PU 85 - SO 70 16:30 - 19:00 2.50 RUNCOtvP RUNCMP Splice ESP cable tubing penetrator - test continuity - Good test - Make up cable to penetrator - test continuity - Good test - Flush mud circ system 19:00 - 19:30 0.50 RUNCOiIIP RUNCMP Land tubing - RILDS - Test TWC from above to 1000 psi - Good test 19:30 - 20:00 0.50 RUNCOtvP RUNCMP Rig down test equipment - Lay down landing joint 20:00 - 21 :00 1.00 RUNCOtvP RUNCMP Nipple down BOP stack 21 :00 - 23:00 2.00 RUNCOtvP RUNCMP Clean seal area - Nipple up 11" X 2 9/16" Tubing head adapter flange - CIW 2 9/16" 5K production tree - Test ESP cable continuity - Good test 23:00 - 00:00 1.00 RUNCOtvP RUNCMP Test metal to metal seal to 5K for 10 mins - Test tree to 5K for 15 mins - Good test - Secure well - Vac out cellar - Pull TWC with dry rod - Install BPV - Rig released at 24:00 hrs 9/13/2004 Printed: 9/20/2004 11: 12:25 AM Legal Name: MPI-19 Common Name: MPI-19 8/30/2004 9/3/2004 FIT FIT 3,030.0 (ft) 7,428.0 (ft) 2,549.0 (ft) 4,077.0 (ft) 9.00 (ppg) 9.00 (ppg) 265 (psi) 636 (psi) 1,457 (psi) 2,542 (psi) 11.00 (ppg) 12.00 (ppg) . . Printed: 9/20/2004 11: 12: 18 AM -WELL SERVICE REPORT . WELL M PI-19 DATE 9/14/2004 AFE MSD337402 JOB SCOPE NEW WELL POST DAILY WORK FREEZE PROT KEY PERSON FESCO - WILSON MINID 0" I DEPTH OFT . UNIT FESCO 367 DAY SUPV HULME NIGHT SUPV HULME TTL SIZE 0" DAILY SUMMARY [Post rig freeze protect] Pumped 75 bbls crude down the lA, 25 bbls diesel down the tubing to freeze protect the well. Initial WHP=BPV, 0, no gauge. Final WHP=550, 300, O. «<Note: SPM status added to this report to reflect what is in the well bore»»> TIME BPM 13:30 14:34 14:38 14:39 .8 14:43 2.5 14:51 15:01 2.5 15:12 15:13 1.0 15:14 15:22 15:24 1.0 15:38 15:49 Init-> 0 TEMP TBG o 0 IA OA BBLs FLUID --. - Diesel 3000 0 Crude 200 5 1000 25 1375 50 1425 75 Crude 1500 0 Diesel 675 2 3500 o Diesel 15 1800 1975 ;'nn.__ ~~n""""~ n."._« ~_~~g.,~_~~. ",.~.nn_ n___.__'-"'_~_ Final-> 550 300 0 FLUID SUMMARY 75 bbls Crude. 15 bbls Diesel. I SAFETY NOTES No gauges, flowline or well house at this stage. SERVICE COMPANY - SERVICE BP ~ FESCO WAREHOUSE ~~nn~'.~ TOTAL FIELD ESTIMATE: COMMENTS Load fluids AOURig up PT Lines . Start down IA -~- Switch to flush Continue Stop PT Lines --- Start down tubinL SD RDMO ~~,~,~_ ~n~, ~"«~~.~~____ _~~ DAILY COST CUMUL TOTAL $0 $1,560 $4,830 '$6,390 ~~~_A~~_~ $0 $780 $630-- $1~4fO-- . . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPI-19 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,609.52' MD 7,640.00' MD 9,720.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ / _ / Date /r4Þ'/ S· ned ;-t,u/~ú..-J Please call me at 273-3545 if you have any q~ion: or concerns. Regards, William T. Allen Survey Manager Attachment(s) 04-0ct-04 ;'0'1--- / 3 J~ DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-19 . Job No. AKZZ3258923, Surveyed: 5 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292321800 Surface Coordinates: 6009436.50 N, 551849.73 E (70· 26'11.4861" N, 149· 34' 38.1394" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1009436.50 N, 51849.73 E (Grid) Surface Coordinates relative to Structure Reference: 353.71 S, 328.39 W (True) Kelly Bushing Elevation: 69. 10ft above Mean Sea Level Kelly Bushing Elevation: 69. 10ft above Project V Reference Kelly Bushing Elevation: 69. 10ft above Structure Reference SPE!ï'ï'Y-SUf1 DR I L.LIN.G$iSR V I c: is $ A Halliburton Company Survey Ref: svy1477 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19 Your Ref: API 500292321800 Job No. AKZZ3258923, Surveyed: 5 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7609.52 82.630 10.100 4028.65 4097.75 5393.46 N 872.11 W 6014823.77 N 550940.14 E 5453.24 Tie On Point 7640.00 83.220 9.440 4032.41 4101.51 5423.27 N 866.98 W 6014853.61 N 550945.07 E 2.892 5482.39 Window Point 7676.59 82.510 7.430 4036.95 4106.05 5459.18 N 861.65 W 6014889.56 N 550950.15 E 5.786 5517.60 7730.33 86.230 9.850 4042.23 4111.33 5512.04 N 853.62 W 6014942.47 N 550957.81 E 8.246 5569.41 7771.94 87.590 7.530 4044.47 4113.57 5553.11 N 847.34 W 6014983.59 N 550963.80 E 6.456 5609.66 7802.30 89.570 6.640 4045.22 4114.32 5583.23 N 843.60 W 6015013.73 N 550967.34 E 7.150 5639.26 . 7852.21 92.470 5.160 4044.33 4113.43 5632.86 N 838.47 W 6015063.39 N 550972.12 E 6.523 5688.14 7897.45 89.010 1.680 4043.75 4112.85 5678.00 N 835.77 W 6015108.55 N 550974.51 E 10.846 5732.79 7945.70 92.840 1.770 4042.97 4112.07 5726.21 N 834.32 W 6015156.78 N 550975.62 E 7.940 5780.63 7993.52 94.700 2.500 4039.83 4108.93 5773.90 N 832.54 W 6015204.47 N 550977.07 E 4.177 5827.90 8039.39 94.700 1.380 4036.07 4105.17 5819.58 N 830.99 W 6015250.17 N 550978.30 E 2.433 5873.21 8089.87 94.950 1.880 4031.82 4100.92 5869.86 N 829.56 W 6015300.46 N 550979.38 E 1.104 5923.11 8137.19 94.380 0.780 4027.97 4097.07 5917.01 N 828.47 W 6015347.61 N 550980.15 E 2.611 5969.92 8185.60 92.780 1.660 4024.95 4094.05 5965.32 N 827.44 W 6015395.92 N 550980.84 E 3.770 6017.88 8232.62 93.830 2.840 4022.24 4091.34 6012.22 N 825.60 W 6015442.84 N 550982.35 E 3.356 6064.37 8281.15 94.510 2.800 4018.71 4087.81 6060.56 N 823.22 W 6015491.19 N 550984.40 E 1 .404 6112.24 8328.26 93.330 2.380 4015.49 4084.59 6107.51 N 821.09 W 6015538.16 N 550986.20 E 2.658 6158.76 8377.15 89.810 2.710 4014.15 4083.25 6156.33 N 818.92 W 6015586.99 N 550988.03 E 7.231 6207.12 8423.14 88.700 2.160 4014.75 4083.85 6202.27 N 816.97 W 6015632.94 N 550989.66 E 2.694 6252.64 8473.38 88.390 0.680 4016.02 4085.12 6252.48 N 815.72 W 6015683.16 N 550990.56 E 3.009 6302.48 8522.30 87.900 1.690 4017.61 4086.71 6301.36 N 814.71 W 6015732.05 N 550991.23 E 2.294 6351.03 8569.76 89.140 5.020 4018.83 4087.93 6348.72 N 811.94W 6015779.42 N 550993.68 E 7.485 6397.88 . 8615.95 89.510 5.050 4019.38 4088.48 6394.73 N 807.88 W 6015825.46 N 550997.41 E 0.804 6443.26 8665.37 89.260 4.710 4019.91 4089.01 6443.97 N 803.68 W 6015874.72 N 551001.27 E 0.854 6491.84 8712.69 89.200 3.610 4020.54 4089.64 6491.16 N 800.25 W 6015921.94 N 551004.38 E 2.328 6538.46 8762.29 89.200 3.940 4021.24 4090.34 6540.64 N 796.98 W 6015971.44 N 551007.30 E 0.665 6587.38 8810.06 88.890 2.880 4022.03 4091.13 6588.32 N 794.14 W 6016019.14 N 551009.81 E 2.312 6634.55 8858.50 88.770 2.430 4023.02 4092.12 6636.70 N 791.90 W 6016067.53 N 551011.71 E 0.961 6682.47 8904.78 89.510 0.730 4023.72 4092.82 6682.95 N 790.62 W 6016113.80 N 551012.67 E 4.006 6728.37 8954.61 90.310 1.560 4023.79 4092.89 6732.77 N 789.63 W 6016163.62 N 551013.32 E 2.313 6777.85 8999.13 90.490 2.220 4023.48 4092.58 6777.27 N 788.16 W 6016208.12 N 551014.48 E 1.537 6821.98 9050.39 88.460 0.700 4023.95 4093.05 6828.50 N 786.85 W 6016259.37 N 551015.42 E 4.947 6872.84 9098.08 88.330 0.420 4025.29 4094.39 6876.17 N 786.38 W 6016307.04 N 551015.56 E 0.647 6920.23 9146.96 88.640 0.560 4026.58 4095.68 6925.03 N 785.97 W 6016355.90 N 551015.64 E 0.696 6968.81 9194.04 89.320 0.030 4027.42 4096.52 6972.11 N 785.72 W 6016402.98 N 551015.55 E 1.831 7015.62 30 September, 2004 - 10:13 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MP/- MP/·19 Your Ref: AP/500292321800 Job No. AKZZ3258923, Surveyed: 5 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ¡O/100ft) 9242.87 88.890 0.440 4028.18 4097.28 7020.93 N 785.52 W 6016451.80 N 551015.41 E 1.217 7064.19 9294.30 89.070 359.900 4029.10 4098.20 7072.35 N 785.37 W 6016503.22 N 551015.21 E 1.107 7115.34 9338.73 89.320 359.660 4029.72 4098.82 7116.78 N 785.54 W 6016547.64 N 551014.73 E 0.780 7159.57 9389.04 90.930 0.550 4029.61 4098.71 7167.08 N 785.45 W 6016597.95 N 551014.47 E 3.657 7209.62 9434.93 90.620 359.590 4028.99 4098.09 7212.97 N 785.39 W 6016643.83 N 551014.21 E 2.198 7255.28 . 9479.62 90.430 359.830 4028.58 4097.68 7257.66 N 785.62 W 6016688.52 N 551013.67 E 0.685 7299.77 9530.76 91.110 0.640 4027.90 4097.00 7308.79 N 785.41 W 6016739.65 N 551013.53 E 2.068 7350.63 9580.86 92.220 1.090 4026.44 4095.54 7358.86 N 784.65 W 6016789.73 N 551013.93 E 2.391 7400.38 9627.12 93.090 1.540 4024.30 4093.40 7405.06 N 783.59 W 6016835.93 N 551014.67 E 2.117 7446.25 9674.30 93.270 0.710 4021.68 4090.78 7452.16 N 782.67 W 6016883.04 N 551015.27 E 1.797 7493.03 0/ 9720.00 93.270 0.710 4019.07 4088.17 . 7497.78 N 782.10 W - 6016928.66 N 551015.52E - 0.000 7538.37 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 354.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9720.00ft., The Bottom Hole Displacement is 7538.46ft., in the Direction of 354.045° (True). . 30 September, 2004·10:13 Page 3 of4 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 7609.52 7640.00 9720.00 Halliburlon Sperry-Sun Survey Report for Milne Point MPI- MPI-19 Your Ref: API 500292321800 Job No. AKZZ3258923, Surveyed: 5 September, 2004 BPXA Station Coordinates TVD Northin9s Eastings (ft) (ft) (ft) 4097.75 4101.51 4088.17 Comment 5393.46 N 5423.27 N 7497.78 N 872.11 W 866.98 W 782.10 W Tie On Point Window Point Projected Survey . Survey tool prof/ram for MPI-19 From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 0.00 446.83 30 September, 2004 - 10:13 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 447.00 9720.00 446.83 CB-SS-GYRO (MPI-19PB1) 4088.17 MWD+IIFR+MS (MPI-19PB1) . Page 4 of4 DrillQuest 3.03.06.006 . AOGCC Robi,. Dèé:l~LJil f 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well MPI-19 MWD 04-0ct-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,609.52' MD 7,640.00' MD 9,720.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 / ~ Date 1&(7(0'1-" . t{/~ Please call me at 273-3545 if you have any Regards, William T. Allen Survey Manager Attachment(s) ¡¿flti---/ S t- Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-19 (rowd) . Job No. AKMW3258923, Surveyed: 5 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292321800 Surface Coordinates: 6009436.50 N, 551849.73 E (70026'11.4861" N, 149034'38.1394" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1009436.50 N, 51849.73 E (Grid) Surface Coordinates relative to Structure Reference: 353.71 S, 328.39 W (True) Kelly Bushing Elevation: 69. 10ft above Mean Sea Level Kelly Bushing Elevation: 69. 10ft above Project V Reference Kelly Bushing Elevation: 69. 10ft above Structure Reference !!iP,E!!r-"r-"Y-!!iUf"1 [:fA I L. LINGS e A VIe: e s A Halliburton Company Survey Ref: svy1478 Halliburton Sperry-Sun Survey Report for Milne Point MPI - MPI-19 (mwd) Your Ref: API 500292321800 Job No. AKMW3258923, Surveyed: 5 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7609.52 82.630 10.360 4028.66 4097.76 5406.78 N 808.74 W 6014837.53 N 551003.42 E 5460.23 Tie On Point 7640.00 83.220 9.440 4032.41 4101.51 5436.58 N 803.54 W 6014867.36 N 551008.42 E 3.566 5489.37 Window Point 7676.59 82.510 7.780 4036.96 4106.06 5472.48 N 798.10 W 6014903.30 N 551013.60 E 4.902 5524.55 7730.33 86.230 10.150 4042.23 4111 .33 5525.29 N 789.76 W 6014956.17 N 551021.57 E 8.196 5576.29 7771.94 87.590 7.830 4044.47 4113.57 5566.33 N 783.27 W 6014997.25 N 551027.78 E 6.456 5616.48 . 7802.30 89.570 6.890 4045.22 4114.32 5596.43 N 779.39 W 6015027.37 N 551031.46 E 7.219 5646.05 7852.21 92.470 5.400 4044.34 4113.44 5646.03 N 774.04 W 6015077.02 N 551036.45 E 6.532 5694.89 7897.45 89.010 2.160 4043.75 4112.85 5691.16 N 771.06 W 6015122.16 N 551039.12 E 10.477 5739.49 7945.70 92.840 1.770 4042.97 4112.07 5739.37 N 769.41 W 6015170.38 N 551040.44 E 7.979 5787.30 7993.52 94.700 2.900 4039.83 4108.93 5787.04 N 767.47 W 6015218.06 N 551042.05 E 4.548 5834.55 8039.39 94.700 1.890 4036.07 4105.17 5832.71 N 765.56 W 6015263.75 N 551043.64 E 2.194 5879.81 8089.87 94.950 2.380 4031.82 4100.92 5882.98 N 763.68 W 6015314.03 N 551045.17 E 1.087 5929.65 8137.19 94.380 1.320 4027.98 4097.08 5930.12 N 762.16 W 6015361.18 N 551046.36 E 2.537 5976.41 8185.60 92.780 2.090 4024.95 4094.05 5978.41 N 760.72 W 6015409.48 N 551047.46 E 3.667 6024.32 8232.62 93.830 3.170 4022.24 4091.34 6025.30 N 758.57 W 6015456.38 N 551049.29 E 3.201 6070.77 8281.15 94.510 3.110 4018.71 4087.81 6073.63 N 755.92 W 6015504.73 N 551051.61 E 1.407 6118.60 8328.26 93.330 2.740 4015.49 4084.59 6120.57 N 753.52 W 6015551.68 N 551053.68 E 2.624 6165.07 8377. 15 89.810 2.890 4014.15 4083.25 6169.37 N 751.12 W 6015600.50 N 551055.74 E 7.206 6213.40 8423.14 88.700 3.340 4014.75 4083.85 6215.29 N 748.62 W 6015646.44 N 551057.92 E 2.604 6258.84 8473.38 88.390 1.360 4016.03 4085.13 6265.47 N 746.56 W 6015696.63 N 551059.63 E 3.988 6308.57 8522.30 87.900 2.070 4017.61 4086.71 6314.34 N 745.10W 6015745.51 N 551060.75 E 1.763 6357.06 8569.76 89.140 5.340 4018.84 4087.94 6361.68 N 742.03 W 6015792.87 N 551063.49 E 7.366 6403.87 . 8615.95 89.510 5.120 4019.38 4088.48 6407.67 N 737.82 W 6015838.89 N 551067.38 E 0.932 6449.22 8665.37 89.260 4.880 4019.91 4089.01 6456.90 N 733.51 W 6015888.15 N 551071.34 E 0.701 6497.78 8712.69 89.200 3.830 4020.55 4089.65 6504.08 N 729.92 W 6015935.35 N 551074.61 E 2.222 6544.37 8762.29 89.200 4.080 4021.24 4090.34 6553.56 N 726.50 W 6015984.85 N 551077.69 E 0.504 6593.27 8810.06 88.890 3.100 4022.04 4091.14 6601.23 N 723.51 W 6016032.54 N 551080.34 E 2.151 6640.41 8858.50 88.770 2.980 4023.02 4092.12 6649.59 N 720.94 W 6016080.92 N 551082.58 E 0.350 6688.28 8904.78 89.510 1.010 4023.72 4092.82 6695.83 N 719.33 W 6016127.17 N 551083.87 E 4.547 6734.14 8954.61 90.310 2.260 4023.80 4092.90 6745.64 N 717.91 W 6016176.99 N 551084.94 E 2.978 6783.57 8999.13 90.490 3.050 4023.49 4092.59 6790.11 N 715.85 W 6016221.47 N 551086.69 E 1.820 6827.62 9050.39 88.460 0.760 4023.96 4093.06 6841.34 N 714.14 W 6016272.70 N 551088.04 E 5.970 6878.42 9098.08 88.330 0.890 4025.29 4094.39 6889.00 N 713.46 W 6016320.37 N 551088.40 E 0.385 6925.79 9146.96 88.640 1.040 4026.58 4095.68 6937.86 N 712.63 W 6016369.24 N 551088.88 E 0.705 6974.32 9194.04 89.320 0.110 4027.42 4096.52 6984.93 N 712.16 W 6016416.31 N 551089.03 E 2.447 7021.11 30 September, 2004 - 10:12 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19 (mwd) Your Ref: API 500292321800 Job No. AKMW3258923, Surveyed: 5 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/10aft) 9242.87 88.890 0.660 4028.19 4097.29 7033.75 N 711.83 W 6016465.13 N 551089.01 E 1 .430 7069.66 9294.30 89.070 0.210 4029.10 4098.20 7085.17 N 711.44W 6016516.55 N 551089.05 E 0.942 7120.79 9338.73 89.320 0.030 4029.73 4098.83 7129.60 N 711.35 W 6016560.98 N 551088.83 E 0.693 7164.99 9389.04 90.930 1.300 4029.62 4098.72 7179.90 N 710.77 W 6016611.28N 551089.07 E 4.076 7214.99 9434.93 90.620 359.910 4028.99 4098.09 7225.78 N 710.28 W 6016657.17 N 551089.23 E 3.103 7260.60 . 9479.62 90.430 0.580 4028.59 4097.69 7270.47 N 710.09 W 6016701.86 N 551089.11 E 1.558 7305.05 9530.76 91.110 228.410 4027.24 4096.34 7287.27 N 746.95 W 6016718.40 N 551052.13 E 258.404 7325.42 9580.86 92.220 1.390 4024.36 4093.46 7303.88 N 782.79 W 6016734.76 N 551016.18 E 265.212 7345.48 9627.12 93.090 2.100 4022.22 4091.32 7350.07 N 781.39 W 6016780.96 N 551017.26 E 2.426 7391.31 9674.30 93.270 0.790 4019.60 4088.70 7397.16 N 780.20 W 6016828.06 N 551018.12 E 2.798 7438.05 9720.00 93.270 0.790 4017.00 4086.10 7442.78 N 779.57 W 6016873.68 N 551018.44 E 0.000 7483.39 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 354.330' (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9720.00ft., The Bottom Hole Displacement is 7483.50ft., in the Direction of 354.021' (True). . 30 September, 2004 - 10:12 Page 3 of4 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 7609.52 7640.00 9720.00 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19 (mwd) Your Ref: API 500292321800 Job No. AKMW3258923, Surveyed: 5 September, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4097.76 4101.51 4086.10 Comment 5406.78 N 5436.58 N 7442.78 N 808.74 W 803.54 W 779.57 W Tie On Point Window Point Projected Survey . Survey tool program for MPI-19 (mwd) From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 0.00 446.83 30 September, 2004 - 10:12 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 447.00 9720.00 446.83 CB-SS-GYRO (MPI-19PB1 (mwd) 4086.10 MWD Magnetic (MPI-19PB1 (mwd)) . Page 4 of4 DrillQuest 3.03.06.006 . . 04-0ct-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPI-19 PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,799.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 n;~ ' ! f\ Date ItfJf/c/ S¡gnVß,h .jJ~ Please call me at 273-3545 if you have any qu ions or concerns. Regards, William T. Allen Survey Manager Attachment(s) (°10 ") ;(d,/-/J'-- Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-19PB1 Job No. AKZZ3258923, Surveyed: 4 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292321870 Surface Coordinates: 6009436.50 N, 551849.73 E (70· 26' 11.4861" N, 149· 34' 38.1394" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009436.50 N, 51849.73 E (Grid) Surface Coordinates relative to Structure Reference: 353.71 S, 328.39 W (True) Kelly Bushing Elevation: 69. 10ft above Mean Sea Level Kelly Bushing Elevation: 69. 10ft above Project V Reference Kelly Bushing Elevation: 69. 10ft above Structure Reference sps'r-ar-ay-sul'1 CAIL.L.ING seRVices A Halliburton Company DEFINITI l: . . Survey Ref: svy1453 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB1 Your Ref: API 500292321870 Job No. AKZZ3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastin9s Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 0.00 0.000 0.000 -69.10 0.00 0.00 N 0.00 E 6009436.50 N 551849.73 E 0.00 CB-SS-GYRO 171.00 0.750 130.000 101.90 171.00 0.72 S 0.86 E 6009435.79 N 551850.59 E 0.439 -0.80 261.00 0.900 61.000 191.89 260.99 0.76 S 1.93 E 6009435.76 N 551851.66 E 1.047 -0.94 353.00 2.300 12.000 283.85 352.95 1 .40 N 2.94 E 6009437.92 N 551852.66 E 1.999 1.10 447.00 3.600 3.000 377.73 446.83 6.19 N 3.49 E 6009442.72 N 551853.18 E 1.464 5.82 MWD+IIFR+MS 478.75 3.770 3.250 409.41 478.51 8.23 N 3.60 E 6009444.76 N 551853.27 E 0.538 7.83 . 574.86 6.240 354.670 505.15 574.25 16.59 N 3.29 E 6009453.11 N 551852.91 E 2.678 16.18 671.01 7.930 348.570 600.56 669.66 28.29 N 1 .49 E 6009464.80 N 551851.03 E 1.922 28.01 766.78 8.560 339.810 695.35 764.45 41 .46 N 2.27W 6009477.94 N 551847.17 E 1 .465 41 .48 863.72 9.410 336.920 791.10 860.20 55.52 N 7.87W 6009491.96 N 551841.47 E 0.993 56.03 958.98 10.970 336.600 884.85 953.95 71.00 N 14.52 W 6009507.40 N 551834.71 E 1.639 72.09 1054.13 12.090 339.830 978.08 1047.18 88.67 N 21.56 W 6009525.01 N 551827.56 E 1.358 90.36 1149.15 15.260 338.330 1070.39 1139.49 109.63 N 29.61 W 6009545.92 N 551819.36 E 3.357 112.02 1244.09 18.100 339.560 1161.33 1230.43 135.07 N 39.37 W 6009571.29 N 551809.42 E 3.014 138.30 1340.50 18.920 341.240 1252.75 1321.85 163.90 N 49.63 W 6009600.05 N 551798.96 E 1.015 168.00 1437.18 18.990 342.670 1344.19 1413.29 193.76 N 59.36 W 6009629.84 N 551789.03 E 0.486 198.68 1534.51 19.930 344.950 1435.96 1505.06 224.90 N 68.38 W 6009660.92 N 551779.79 E 1.242 230.55 1630.42 25.250 347.510 1524.48 1593.58 260.68 N 77.06 W 6009696.64 N 551770.86 E 5.640 267.02 1728.56 26.290 348.430 1612.86 1681.96 302.41 N 85.94 W 6009738.31 N 551761.69 E 1.135 309.42 1822.41 27.510 350.000 1696.56 1765.66 344.12 N 93.87 W 6009779.96 N 551753.46 E 1.504 351.71 1918.66 32.950 346.290 1779.69 1848.79 391.48 N 103.95 W 6009827.25 N 551743.06 E 5.973 399.84 2015.04 35.410 343.110 1859.43 1928.53 443.68 N 118.28 W 6009879.34 N 551728.37 E 3.154 453.19 . 2111.79 39.510 342.240 1936.21 2005.31 499.83 N 135.81 W 6009935.37 N 551710.44 E 4.273 510.80 2207.09 42.830 342.800 2007.94 2077.04 559.66 N 154.65 W 6009995.08 N 551691.20 E 3.505 572.20 2302.96 42.610 342.600 2078.37 2147.47 621.76 N 173.99 W 6010057.04 N 551671.42 E 0.270 635.91 2398.20 44.730 343.050 2147.26 2216.36 684.59 N 193.40 W 6010119.73N 551651.58 E 2.250 700.35 2494.64 50.050 344.110 2212.53 2281.63 752.65 N 213.43 W 6010187.65 N 551631.07 E 5.575 770.06 2590.46 52.740 343.940 2272.31 2341 .41 824.64 N 234.04 W 6010259.49 N 551609,96 E 2.811 843.72 2686.70 55.400 343.980 2328.77 2397.87 899.52 N 255.57 W 6010334.23 N 551587.91 E 2.764 920.37 2783.34 58.410 344.500 2381.54 2450.64 977.43 N 277.55 W 6010411.98 N 551565.39 E 3.147 1000.07 2878.72 62.330 344.470 2428.68 2497.78 1057.31 N 299.72 W 6010491.70 N 551542.66 E 4.110 1081.74 2953.01 65.080 343.320 2461.59 2530.69 1121.28N 318.20 W 6010555.55 N 551523.74 E 3.953 1147.24 3063.75 66.710 344.250 2506.82 2575.92 1218.34 N 346.42 W 6010652.41 N 551494.84 E 1.660 1246.61 3160.44 65.230 343.060 2546.19 2615.29 1303.08 N 371.27 W 6010736.97 N 551469.41 E 1.899 1333.39 3255.59 68.630 342.660 2583.47 2652.57 1386.72 N 397.07 W 6010820.43 N 551443.03 E 3.594 1419.17 30 September, 2004 - 10:12 Page 2 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB1 Your Ref: API 500292321870 Job No. AKZZ3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3348.98 70.420 343.160 2616.14 2685.24 1470.34 N 422.78 W 6010903.87 N 551416.74 E 1.981 1504.92 3446.86 70.230 342.610 2649.09 2718.19 1558.43 N 449.90 W 6010991.76 N 551389.01 E 0.564 1595.25 3543.09 69.650 342.830 2682.10 2751.20 1644.74 N 476.75 W 6011077.89 N 551361.56 E 0.640 1683.79 3638.15 69.500 342.870 2715.27 2784.37 1729.86 N 503.02 W 6011162.82 N 551334.70 E 0.163 1771.10 3734.85 68.520 343.830 2749.91 2819.01 1816.36 N 528.89 W 6011249.14 N 551308.23 E 1.373 1859.72 3830.66 68.480 343.030 2785.03 2854.13 1901.80N 554.31 W 6011334.40 N 551282.21 E 0.778 1947.26 . 3927.16 67.390 342.640 2821.28 2890.38 1987.25 N 580.70 W 6011419.66 N 551255.23 E 1.190 2034.90 4023.92 68.850 344.890 2857.34 2926.44 2073.45 N 605.79 W 6011505.69 N 551229.54 E 2.633 2123.16 4120.07 68.770 345.580 2892.09 2961.19 2160.14 N 628.64 W 6011592.21 N 551206.09 E 0.674 2211.68 4215.99 68.760 346.520 2926.84 2995.94 2246.91 N 650.19 W 6011678.83 N 551183.93 E 0.914 2300.15 4311.92 68.360 346.240 2961.90 3031.00 2333.69 N 671.22 W 6011765.46 N 551162.30 E 0.498 2388.58 4408.07 68.810 347.440 2997.01 3066.11 2420.84 N 691.60W 6011852.48 N 551141.32 E 1.253 2477.33 4503.82 68.630 347.470 3031.76 3100.86 2507.94 N 710.98 W 6011939.43 N 551121.33 E 0.190 2565.91 4599.96 68.390 347.270 3066.98 3136.08 2595.23 N 730.54 W 6012026.59 N 551101.17 E 0.316 2654.71 4696.56 67.560 346.700 3103.21 3172.31 2682.48 N 750.70 W 6012113.69 N 551080.40 E 1.019 2743.52 4791.48 67.750 346.460 3139.29 3208.39 2767.87 N 771.08 W 6012198.94 N 551059.43 E 0.308 2830.51 4886.41 68.040 346.770 3175.02 3244.12 2853.43 N 791.44 W 6012284.36 N 551038.47 E 0.430 2917.67 4983.18 67.910 345.660 3211.31 3280.41 2940.56 N 812.81 W 6012371.34 N 551016.49 E 1.072 3006.48 5080.06 67.690 346.150 3247.91 3317.01 3027.55 N 834.66 W 6012458.18 N 550994.04 E 0.520 3095.21 5175.74 66.080 347.190 3285.47 3354.57 3113.18 N 854.95 W 6012543.66 N 550973.16 E 1.957 3182.41 5271.81 65.770 346.630 3324.66 3393.76 3198.61 N 874.82 W 6012628.95 N 550952.70 E 0.622 3269.39 5368.03 66.010 346.150 3363.97 3433.07 3283.97 N 895.48 W 6012714.16 N 550931.44 E 0.519 3356.38 . 5464.24 66.510 345.940 3402.70 3471.80 3369.44 N 916.72 W 6012799.48 N 550909.61 E 0.557 3443.52 5560.56 66.650 344.830 3440.99 3510.09 3454.96 N 939.02 W 6012884.85 N 550886.71 E 1.067 3530.83 5656.59 68.830 348.280 3477.37 3546.47 3541.38 N 959.66 W 6012971.13 N 550865.47 E 4.026 3618.87 5753.10 69.970 351.170 3511.33 3580.43 3630.26 N 975.76 W 6013059.89 N 550848.75 E 3.042 3708.90 5847.97 70.030 351.840 3543.78 3612.88 3718.43 N 988.93 W 6013147.97 N 550834.97 E 0.667 3797.94 5941.88 69.430 357.770 3576.34 3645.44 3806.11 N 996.91 W 6013235.59 N 550826.38 E 5.958 3885.99 6038.10 71.290 1.360 3608.69 3677.79 3896.71 N 997.59 W 6013326.18 N 550825.08 E 4.010 3976.21 6134.44 70.540 1.600 3640.19 3709.29 3987.72 N 995.23 W 6013417.21 N 550826.80 E 0.813 4066.54 6230.01 70.180 0.860 3672.31 3741.41 4077.71 N 993.30 W 6013507.21 N 550828.10 E 0.821 4155.90 6326.73 73.220 358.940 3702.68 3771.78 4169.53 N 993.48 W 6013599.02 N 550827.29 E 3.665 4247.28 6422.91 75.530 359.500 3728.58 3797.68 4262.14 N 994.73 W 6013691.62 N 550825.39 E 2.466 4339.56 6471.97 75.470 359.690 3740.87 3809.97 4309.63 N 995.07 W 6013739.11 N 550824.72 E 0.394 4386.86 6518.30 75.140 359.140 3752.62 3821.72 4354.44 N 995.53 W 6013783.92 N 550823.95 E 1.351 4431.50 30 September, 2004· 10:12 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MP/- MP/-19PB1 Your Ref: AP/500292321870 Job No. AKZZ3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northin9s Eastin9s Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6568.10 74.750 359.940 3765.55 3834.65 4402.53 N 995.91 W 6013832.00 N 550823.23 E 1.738 4479.39 6614.73 74.060 359.820 3778.09 3847.19 4447.45 N 996.01 W 6013876.91 N 550822.83 E 1.500 4524.09 6663.96 73.800 359.880 3791.72 3860.82 4494.75 N 996.13 W 6013924.22 N 550822.37 E 0.541 4571.18 6711.07 75.590 358.900 3804.15 3873.25 4540.19 N 996.62 W 6013969.65 N 550821.57 E 4.297 4616.44 6759.71 76.280 359.450 3815.97 3885.07 4587.36 N 997.30 W 6014016.82 N 550820.57 E 1.793 4663.45 . 6806.68 76.230 359.810 3827.13 3896.23 4632.99 N 997.59 W 6014062.44 N 550819.95 E 0.752 4708.88 6858.40 75.270 0.050 3839.86 3908.96 4683.11 N 997.65 W 6014112.56 N 550819.54 E 1.910 4758.77 6902.57 72.950 0.850 3851.96 3921.06 4725.59 N 997.32 W 6014155.04 N 550819.58 E 5.534 4801.01 6951.02 71.330 2.330 3866.82 3935.92 4771.69 N 996.04 W 6014201.15 N 550820.54 E 4.431 4846.75 6997.65 70.030 3.810 3882.24 3951.34 4815.62 N 993.69 W 6014245.10 N 550822.59 E 4.092 4890.24 7046.94 70.100 5.250 3899.05 3968.15 4861.81 N 990.03 W 6014291.31 N 550825.92 E 2.750 4935.84 7091.72 70.580 7.850 3914.12 3983.22 4903.70 N 985.22 W 6014333.24 N 550830.44 E 5.572 4977.05 7143.99 71.910 11.920 3930.93 4000.03 4952.45 N 976.72 W 6014382.04 N 550838.61 E 7.799 5024.72 7187.91 72.380 14.410 3944.40 4013.50 4993.15 N 967.20 W 6014422.81 N 550847.84 E 5.501 5064.28 7233.43 72.250 14.930 3958.23 4027.33 5035.11 N 956.21 W 6014464.84 N 550858.54 E 1.125 5104.94 7283.97 71.100 14.750 3974.12 4043.22 5081.48 N 943.92 W 6014511.30 N 550870.50 E 2.300 5149.88 7334.54 74.760 14.050 3988.96 4058.06 5128.30 N 931.91 W 6014558.20 N 550882.19 E 7.357 5195.28 7376.25 79.330 13.270 3998.31 4067.41 5167.79 N 922.31 W 6014597.75 N 550891.51 E 11.1 07 5233.63 7457.24 83.750 14.300 4010.22 4079.32 5245.57 N 903.23 W 6014675.66 N 550910.06 E 5.600 5309.14 7512.88 87.900 14.910 4014.27 4083.37 5299.25 N 889.23 W 6014729.44 N 550923.68 E 7.538 5361.18 7548.58 87.530 14.860 4015.69 4084.79 5333.73 N 880.07 W 6014763.98 N 550932.60 E 1.046 5394.58 7580.84 87.220 15.220 4017.17 4086.27 5364.85 N 871.71 W 6014795.16 N 550940.74 E 1.472 5424.73 . 7609.70 87.220 14.570 4018.57 4087.67 5392.71 N 864.30 W 6014823.07 N 550947.96 E 2.250 5451.71 7641.41 86.230 14.730 4020.38 4089.48 5423.34 N 856.29 W 6014853.75 N 550955.75 E 3.162 5481.40 7677.21 85.240 12.840 4023.04 4092.14 5458.01 N 847.79 W 6014888.48 N 550964.02 E 5.947 5515.06 7739.00 84.430 9.840 4028.61 4097.71 5518.34 N 835.69 W 6014948.89 N 550975.70 E 5.010 5573.90 7799.00 84.430 9.840 4034.43 4103.53 5577.17 N 825.48 W 6015007.80 N 550985.50 E 0.000 5631.44 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 354.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7799.00ft., The Bottom Hole Displacement is 5637.93ft., in the Direction of 351.581 0 (True). 30 September, 2004·10:12 Page 4 of5 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 7799.00 4103.53 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB1 Your Ref: API 500292321870 Job No. AKZZ3258923, Surveyed: 4 September, 2004 BPXA Station Coordinates TVD Northin9s Eastin9s (ft) (ft) (ft) Comment 5577.17 N 825.48 W Projected Survey . Survey too/øroøram for MP/-19PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 0.00 446.83 30 September, 2004 - 10:12 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 447.00 7799.00 446.83 CB-SS-GYRO 4103.53 MWD+IIFR+MS . Page 50f5 DrillQuest 3.03.06.006 . . 04-0ct-04 AOGCC - RubilJ DeB50n 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-19 PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 7,799.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Jl ) /'ì Date /p¡; ~ý Si~ .diu-£< . Please call me at 273-3545 if you have any que ons or concerns. Regards, -/ William T. Allen Survey Manager Attachment(s) ~'Ct1-/) !- Halliburton Sperry-Sun Milne Point Unit BPXA . Milne Point MPI MPI-19PB1 (mwd) 2004 Job No. AKMW3258923, Surveyed: 4 September, Survey Report 30 September, 2004 Your Ref: API 500292321870 Surface Coordinates: 6009436.50 N, 551849.73 E (70026'11.4861" N, 149034'38.1394" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy1455 L1? Surface Coordinates relative to Project H Reference: 1009436.50 N, 51849.73 E (Grid) Surface Coordinates relative to Structure Reference: 353.71 S, 328.39 W (True) Kelly Bushing Elevation: 69. 10ft above Mean Sea Level Kelly Bushing Elevation: 69. 10ft above Project V Reference Kelly Bushing Elevation: 69. 10ft above Structure Reference S('"1t='i'i'Y-SUi! DRIL.LING seR"Vlt:e!S A Halliburton Company Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB1 (mwd) Your Ref: API 500292321870 Job No. AKMW3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -69.10 0.00 0.00 N 0.00 E 6009436.50 N 551849.73 E 0.00 CB-8S-GYRO 171.00 0.750 130.000 101.90 171.00 0.728 0.86 E 6009435.79 N 551850.59 E 0.439 -0.80 261.00 0.900 61.000 191.89 260.99 0.768 1.93 E 6009435.76 N 551851.66 E 1.047 -0.94 353.00 2.300 12.000 283.85 352.95 1.40 N 2.94 E 6009437.92 N 551852.66 E 1.999 1.10 447.00 3.600 3.000 377.73 446.83 6.19 N 3.49 E 6009442.72 N 551853.18 E 1 .464 5.82 MWD Magnetic . 478.75 3.770 3.220 409.41 478.51 8.23 N 3.60 E 6009444.76 N 551853.27 E 0.537 7.83 574.86 6.240 354.660 505.15 574.25 16.59 N 3.29 E 6009453.11 N 551852.91 E 2.678 16.18 671.01 7.930 348.800 600.56 669.66 28.30 N 1.52 E 6009464.81 N 551851.05 E 1.909 28.01 766.78 8.560 340.070 695.35 764.45 41.48 N 2,20W 6009477.96 N 551847.25 E 1.461 41 .49 863.72 9.410 337.180 791.10 860.20 55.57 N 7.73W 6009492.01 N 551841.61 E 0.993 56.06 958.98 10.970 336.960 884.85 953.95 71.09 N 14,30 W 6009507.48 N 551834.94 E 1.638 72.15 1054.13 12.090 340,110 978.08 1047.18 88.79 N 21.23 W 6009525.14 N 551827.88 E 1.350 90.45 1149.15 15.260 338,640 1070.39 1139.49 109.80 N 29,17 W 6009546.09 N 551819.79 E 3.356 112.14 1244.09 18.100 339.880 1161.33 1230.43 135.29 N 38,80 W 6009571.51 N 551809.99 E 3,015 138.46 1340,50 18.920 341.590 1252.75 1321.85 164.18N 48,89 W 6009600.33 N 551799.70 E 1.020 168.21 1437.18 18.990 343.020 1344.19 1413.29 194.10N 58.43 W 6009630,18 N 551789.95 E 0.486 198.92 1534.51 19.930 345.190 1435.96 1505.06 225.28 N 67.30 W 6009661.31 N 551780.87 E 1.218 230.83 1630.42 25,250 347.710 1524.48 1593,58 261,10 N 75,83 W 6009697.06 N 551772.08 E 5.637 267.31 1728.56 26.290 348.680 1612.86 1681.96 302.86 N 84,56 W 6009738.77 N 551763.07 E 1.143 309.73 1822.41 27.510 350.310 1696.56 1765.66 344.61 N 92,28 W 6009780.46 N 551755.05 E 1.519 352.04 1918.66 32.950 346,910 1779.69 1848.79 392.05 N 101.96 W 6009827.84 N 551745.04 E 5.923 400.21 2015.04 35.410 344.240 1859.42 1928.52 444.47 N 115.49 W 6009880.15 N 551731.16 E 2.989 453.70 . 2111.79 39.510 342.560 1936.21 2005.31 500.83 N 132,33 W 6009936.40 N 551713.92 E 4.367 511.46 2207.09 42.830 342.880 2007,94 2077.04 560.73 N 150,96 W 6009996.17 N 551694,88 E 3.491 572.90 2302.96 42.610 342.700 2078.37 2147.47 622.86 N 170.20 W 6010058.16 N 551675.20 E 0.262 636.62 2398.20 44.730 343.310 2147.26 2216.36 685.75 N 189.41 W 6010120.91 N 551655.55 E 2.269 701.10 2494.64 50.050 344.280 2212.52 2281.62 753.88 N 209.19 W 6010188.91 N 551635.30 E 5.566 770.86 2590.46 52.740 344.510 2272.30 2341 .40 826.00 N 229,33 W 6010260.88 N 551614.66 E 2.814 844.61 2686.70 55.400 344,690 2328.77 2397.87 901.12 N 250,02 W 6010335.86 N 551593.45 E 2.768 921.42 2783.34 58.410 345.050 2381.53 2450.63 979.27 N 271.15W 6010413.86 N 551571.78 E 3.130 1001,27 2878.72 62.330 344.980 2428.68 2497.78 1059.34 N 292.58 W 6010493.78 N 551549.79 E 4.110 1083.07 2953.01 65.080 344.430 2461.59 2530.69 1123.58 N 310,15 W 6010557.90 N 551531.78 E 3.761 1148.72 3063.75 66.710 345.490 2506.82 2575.92 1221,20N 336,37 W 6010655.33 N 551504.87 E 1.712 1248.45 3160.44 65.230 344.870 2546.19 2615.29 1306.57 N 358.96 W 6010740.54 N 551481.70 E 1.639 1335.64 3255.59 68.630 345.800 2583.47 2652.57 1391.24 N 381.11 W 6010825.06 N 551458.96 E 3.685 1422.09 30 September, 2004·10:12 Page 20f5 DríllQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MP/· MP/·19PB1 (mwd) Your Ref: AP/500292321870 Job No. AKMW3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3348.98 70.420 345.190 2616.13 2685.23 1475.94 N 403.02 W 6010909.60 N 551436.46 E 2.012 1508.54 3446.86 70.230 346.190 2649.09 2718.19 1565.25 N 425.80 W 6010998.75 N 551413.05 E 0.981 1599.66 3543.09 69.650 344.970 2682.10 2751.20 1652.79 N 448.31 W 6011086.13 N 551389.94 E 1.335 1688.99 3638.15 69.500 344.660 2715.27 2784.37 1738.76 N 471.65 W 6011171.94 N 551366.01 E 0.344 1776.85 3734.85 68.520 345.180 2749.91 2819.01 1825.93 N 495.13 W 6011258.95 N 551341.91 E 1.131 1865.92 . 3830.66 68.480 343.730 2785.03 2854.13 1911.81 N 519.02 W 6011344.66 N 551317.43 E 1.409 1953.74 3927.16 67.390 344.630 2821.28 2890.38 1997.85 N 543.41 W 6011430.53 N 551292.45 E 1 .422 2041.77 4023.92 68.850 347.230 2857.34 2926.44 2084.94 N 565.22 W 6011517.46 N 551270.03 E 2.914 2130.58 4120.07 68.770 346.680 2892.10 2961.20 2172.28 N 585.46 W 6011604.65 N 551249.18 E 0.540 2219.49 4215.99 68.760 347.280 2926.84 2995.94 2259.38 N 605.60 W 6011691.62N 551228.44 E 0.583 2308.16 4311.92 68.360 347.070 2961.90 3031.00 2346.45 N 625.42 W 6011778.54 N 551208.01 E 0.464 2396.76 4408.07 68.810 347.690 2997.01 3066.11 2433.80 N 644.98 W 6011865.75 N 551187.85 E 0.761 2485.61 4503.82 68.630 348.110 3031.76 3100.86 2521.04 N 663.68 W 6011952.86 N 551168.54 E 0.450 2574.27 4599.96 68.390 347.880 3066.98 3136.08 2608.54 N 682.28 W 6012040.23 N 551149.33 E 0.334 2663.18 4696.56 67.560 346.700 3103.21 3172.31 2695.89 N 701.98 W 6012127.44 N 551129.02 E 1.421 2752.05 4791.48 67.750 346.810 3139.29 3208.39 2781.35 N 722.10 W 6012212.76 N 551108.31 E 0.227 2839.08 4886.41 68.040 346.940 3175.02 3244.12 2867.00 N 742.07 W 6012298.27 N 551087.75 E 0.331 2926.29 4983.18 67.910 345.340 3211.31 3280.41 2954.09 N 763.56 W 6012385.21 N 551065.65 E 1.539 3015.08 5080.06 67.690 346.500 3247.91 3317.01 3041 .1 0 N 785.38 W 6012472.06 N 551043.23 E 1.132 3103.81 5175.74 66.080 347.440 3285.48 3354.58 3126.82 N 805.22 W 6012557.65 N 551022.79 E 1.910 3191.08 5271.81 65.770 346.860 3324.67 3393.77 3212.34 N 824.73 W 6012643.03 N 551002.69 E 0.639 3278.10 5368.03 66.010 346.250 3363.97 3433.07 3297.76 N 845.15 W 6012728.30 N 550981.67 E 0.630 3365.12 . 5464.24 66.510 346.220 3402.70 3471.80 3383.30 N 866.11 W 6012813.69 N 550960.12 E 0.520 3452.31 5560.56 66.650 344.940 3440.99 3510.09 3468.89 N 888.12 W 6012899.14 N 550937.52 E 1.228 3539.67 5656.59 68.830 348.410 3477.37 3546.4 7 3555.36 N 908.57 W 6012985.46 N 550916.46 E 4.042 3627.73 5753.10 69.970 351.170 3511.34 3580.44 3644.26 N 924.58 W 6013074.24 N 550899.84 E 2.926 3717.77 5847.97 70.030 352.110 3543.78 3612.88 3732.46 N 937.54 W 6013162.35 N 550886.27 E 0.933 3806.82 5941.88 69.430 357.830 3576.34 3645.44 3820.16 N 945.27 W 6013250.00 N 550877.93 E 5.749 3894.86 6038.10 71.290 1.360 3608.69 3677.79 3910.76 N 945.89 W 6013340.59 N 550876.67 E 3.959 3985.08 6134.44 70.540 2.350 3640.19 3709.29 4001.76 N 942.95 W 6013431.61 N 550878.99 E 1.245 4075.34 6230.01 70.180 1.390 3672.31 3741.41 4091.72 N 940.01 W 6013521.58 N 550881.30 E 1.018 4164.57 6326.73 73.220 359.450 3702.68 3771.78 4183.53 N 939.35 W 6013613.40 N 550881.32 E 3.675 4255.87 6422.91 75.530 0.440 3728.59 3797.69 4276.15 N 939.43 W 6013706.01 N 550880.59 E 2.598 4348.04 6471.97 75.470 0.160 3740.87 3809.97 4323.64 N 939.18 W 6013753.51 N 550880.51 E 0.566 4395.28 6518.30 75.140 359.700 3752.62 3821.72 4368.46 N 939.24 W 6013798.32 N 550880.14 E 1.196 4439.88 30 September, 2004 - 10:12 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB1 (mwd) Your Ref: API 500292321870 Job No. AKMW3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6568.10 74.750 0.840 3765.56 3834.66 4416.55 N 939.01 W 6013846.41 N 550880.04 E 2.345 4487.71 6614.73 74.060 0.860 3778.09 3847.19 4461.45 N 938.35 W 6013891.32 N 550880.39 E 1 .480 4532.33 6663.96 73.800 0.820 3791.72 3860.82 4508.76 N 937.65 W 6013938.63 N 550880.75 E 0.534 4579.34 6711.07 75.590 359.390 3804.16 3873.26 4554.19 N 937.57 W 6013984.06 N 550880.52 E 4.797 4624.54 6759.71 76.280 359.820 3815.98 3885.08 4601.37 N 937.90 W 6014031.24 N 550879.87 E 1.658 4671.52 . 6806.68 76.230 0.120 3827.14 3896.24 4647.00 N 937.92 W 6014076.86 N 550879.53 E 0.629 4716.93 6858.40 75.270 0.300 3839.87 3908.97 4697.12 N 937.74 W 6014126.99 N 550879.36 E 1.887 4766.79 6902.57 72.950 0.900 3851.96 3921.06 4739.60 N 937.29 W 6014169.47 N 550879.51 E 5.412 4809.02 6951.02 71.330 2.400 3866.82 3935.92 4785.69 N 935.97 W 6014215.57 N 550880.51 E 4.457 4854.75 6997.65 70.030 4.090 3882.25 3951.35 4829.63 N 933.48 W 6014259.52 N 550882.70 E 4.412 4898.22 7046.94 70.100 5.700 3899.05 3968.15 4875.79 N 929.53 W 6014305.71 N 550886.33 E 3.074 4943.77 7091.72 70.580 8.150 3914.12 3983.22 4917.65 N 924.44 W 6014347.60 N 550891.12 E 5.263 4984.92 7143.99 71.910 12.230 3930.93 4000.03 4966.35 N 915.68 W 6014396.36 N 550899.54 E 7.817 5032.52 7187.91 72.380 14.560 3944.40 4013.50 5007.01 N 906.00 W 6014437.09 N 550908.95 E 5.162 5072.03 7233.43 72.250 15.610 3958.23 4027.33 5048.88 N 894.71 W 6014479.04 N 550919.94 E 2.216 5112.58 7283.97 71.100 14.950 3974.12 4043.22 5095.16 N 882.06 W 6014525.41 N 550932.26 E 2.591 5157.38 7334.54 74.760 14.550 3988.96 4058.06 5141.91 N 869.76 W 6014572.24 N 550944.24 E 7.277 5202.68 7376.25 79.330 13.870 3998.31 4067.41 5181.30N 859.79 W 6014611.70 N 550953.94 E 11.071 5240.90 7457.24 83.750 14.300 4010.22 4079.32 5258.98 N 840.30 W 6014689.51 N 550972.89 E 5.483 5316.27 7512.88 87.900 15.120 4014.27 4083.37 5312.64 N 826.21 W 6014743.27 N 550986.61 E 7.602 5368.28 7548.58 87.530 15.100 4015.70 4084.80 5347.08 N 816.91 W 6014777.77 N 550995.67 E 1.038 5401.63 7580.84 87.220 15.470 4017.17 4086.27 5378.17 N 808.41 W 6014808.92 N 551003.95 E 1 .495 5431.72 . 7609.70 87.220 14.820 4018.57 4087.67 5405.99 N 800.88 W 6014836.79 N 551011.28E 2.250 5458.67 7641.41 86.230 14.950 4020.38 4089.48 5436.59 N 792.75 W 6014867.44 N 551019.20 E 3.149 5488.31 7677.21 85.240 13.110 4023.05 4092.15 5471.22 N 784.09 W 6014902.14 N 551027.62 E 5.824 5521.92 7739.00 84.430 10.150 4028.61 4097.71 5531.49 N 771.69 W 6014962.49 N 551039.60 E 4.948 5580.67 7799.00 84.430 10.150 4034.43 4103.53 5590.27 N 761.17 W 6015021.34 N 551049.72 E 0.000 5638.12 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 354.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7799.00ft., The Bottom Hole Displacement is 5641.85ft., in the Direction of 352.246° (True). 30 September, 2004 - 10:12 Page 4 of5 Dri/lQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 7799.00 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB1 (mwd) Your Ref: API 500292321870 Job No. AKMW3258923, Surveyed: 4 September, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4103.53 Comment 5590.27 N 761.17 W Projected Survey . Survey tool program for MPI-19PB1 (mwd) From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 0.00 446.83 30 September, 2004 - 10:12 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 447.00 7799.00 446.83 CB-SS-GYRO 4103.53 MWD Magnetic . Page 50f5 DrillQuest 3.03.06.006 . . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPI-19 PB2 04-0ct-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,457.24' MD 7,488.00' MD 8,532.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, ~KJ9518 y. J ¡Ii Date /~/(}i Si9Ø~j~ Please call me at 273-3545 if you have anyQ'est;ons or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ð~-(3j- ;f Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-19PB2 Job No. AKZZ3258923, Surveyed: 4 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292321871 Surface Coordinates: 6009436.50 N, 551849.73 E (70· 26'11.4861" N, 149· 34' 38.1394" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009436.50 N, 51849.73 E (Grid) Surface Coordinates relative to Structure Reference: 353.71 S, 328.39 W (True) Kelly Bushing Elevation: 69. 10ft above Mean Sea Level Kelly Bushing Elevation: 69. 10ft above Project V Reference Kelly Bushing Elevation: 69. 10ft above Structure Reference SpE!r"'r"'Y-SUI! DRILLING SeRVIceS A Halliburton Company ~ EF/NITIVE . . Survey Ref: svy1476 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB2 Your Ref: API 500292321871 Job No. AKZZ3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7457.24 83.750 14.300 4010.22 4079.32 5245.57 N 903.23 W 6014675.66 N 550910.06 E 5309.14 Tie On Point 7488.00 83.480 11.620 4013.64 4082.74 5275.35 N 896.37 W 6014705.49 N 550916.71 E 8.703 5338.10 Window Point 7513.51 83.260 13.070 4016.59 4085.69 5300.11 N 890.95 W 6014730.28 N 550921.95 E 5.712 5362.20 7559.10 82.630 11.310 4022.19 4091.29 5344.33 N 881.40 W 6014774.57 N 550931.20 E 4.073 5405.26 7609.52 82.630 10.100 4028.65 4097.75 5393.46 N 872.11 W 6014823.77 N 550940.14 E 2.380 5453.24 . 7657.86 83.560 9.060 4034.47 4103.57 5440.78 N 864.12 W 6014871.14 N 550947.80 E 2.875 5499.54 7705.79 86.600 9.320 4038.58 4107.68 5487.92 N 856.50 W 6014918.33 N 550955.10 E 6.366 5545.69 7753.65 88.830 11.450 4040.48 4109.58 5534.95 N 847.88 W 6014965.42 N 550963.39 E 6.441 5591.64 7801.87 89.750 11.700 4041.08 4110.18 5582.18 N 838.20 W 6015012.72 N 550972.74 E 1.977 5637.69 7849.35 90.190 9.940 4041.11 4110.21 5628.82 N 829.29 W 6015059.42 N 550981.33 E 3.821 5683.21 7898.70 90.560 8.870 4040.78 4109.88 5677.50 N 821.23 W 6015108.16 N 550989.05 E 2.294 5730.86 7945.80 88.640 8.280 4041.11 4110.21 5724.07 N 814.21 W 6015154.77 N 550995.75 E 4.265 5776.51 7994.41 86.980 6.190 4042.97 4112.07 5772.26 N 808.09 W 6015203.00 N 551001.53 E 5.488 5823.85 8046.52 87.220 4.820 4045.61 4114.71 5824.06 N 803.10 W 6015254.83 N 551006.16 E 2.666 5874.91 8090.14 90.800 3.240 4046.36 4115.46 5867.55 N 800.03 W 6015298.35 N 551008.93 E 8.971 5917.89 8140.32 92.530 1.110 4044.90 4114.00 5917.67 N 798.13 W 6015348.48 N 551010.48 E 5.467 5967.57 8186.27 92.840 358.800 4042.75 4111.85 5963.57 N 798.16 W 6015394.38 N 551010.13 E 5.067 6013.25 8230.67 91.920 357.870 4040.91 4110.01 6007.91 N 799.45 W 6015438.71 N 551008.53 E 2.945 6057.50 8280.27 94.080 358.140 4038.31 4107.41 6057.41 N 801.18 W 6015488.19 N 551006.46 E 4.389 6106.93 8330.28 94.260 358.180 4034.67 4103.77 6107.26 N 802.78 W 6015538.03 N 551004.51 E 0.369 6156.69 8376.73 95.130 358.270 4030.87 4099.97 6153.53 N 804.21 W 6015584.29 N 551002.76 E 1.883 6202.88 8423.22 94.820 0.300 4026.84 4095.94 6199.84 N 804.79 W 6015630.60 N 551001.86 E 4.401 6249.02 . 8472.92 95.380 358.060 4022.42 4091.52 6249.34 N 805.50 W 6015680.09 N 551000.81 E 4.628 6298.34 8532.00 95.380 358.060 4016.88 4085.98 6308.12 N 807.49 W 6015738.86 N 550998.41 E 0.000 6357.04 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 354.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8532.00ft., The Bottom Hole Displacement is 6359.60ft., in the Direction of 352.705° (True). 30 September, 2004 - 10:12 Page 2 of 3 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 7457.24 7488.00 8532.00 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB2 Your Ref: API 500292321871 Job No. AKZZ3258923, Surveyed: 4 September, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4079.32 4082.74 4085.98 Comment 5245.57 N 5275.35 N 6308.12 N Tie On Point Window Point Projected Survey . 903.23 W 896.37 W 807.49 W Survey too/prOgram for MP/-19PB2 From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 0.00 446.83 30 September, 2004·10:12 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 447.00 8532.00 446.83 CB-SS-GYRO (MPI-19PB1) 4085.98 MWD+IIFR+MS (MPI-19PB1) . Page 3 of 3 DrillQuest 3.03.06.006 . . AOGCC Rouifl DE::èlson 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-19 PB2 MWD 04-0ct-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,457.24' MD 7,488.00' MD 8,532.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. AnChor:g~A~99518 =:J~ Date If}; 7/'lJrt Si9~t'~ Please call me at 273-3545 if you have any stions or concerns. Regards, pL William T. Allen Survey Manager Attachment(s) ¡(rjt.f-I )~- Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-19PB2 (mwd) . Job No. AKMW3258923, Surveyed: 4 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292321871 Surface Coordinates: 6009436.50 N, 551849.73 E (70026'11.4861" N, 149034' 38.1394" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1009436.50 N, 51849.73 E (Grid) Surface Coordinates relative to Structure Reference: 353.71 S, 328.39 W (True) Kelly Bushing Elevation: 69. 10ft above Mean Sea Level Kelly Bushing Elevation: 69. 10ft above Project V Reference Kelly Bushing Elevation: 69. 10ft above Structure Reference SI:JE!I"""I"""Y-'SUI'1 DRIL-LtN·e; 5ie~vlt:e5i A Halliburton Company Survey Ref: svy1456 ~ Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB2 (mwd) Your Ref: API 500292321871 Job No. AKMW3258923, Surveyed: 4 September, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7457.24 83.750 14.300 4010.22 4079.32 5258.98 N 840.30 W 6014689.51 N 550972.89 E 5316.27 Tie On Point 7488.00 83.480 11.620 4013.64 4082.74 5288.77 N 833.44 W 6014719.35 N 550979.54 E 8.703 5345.24 Window Point 7513.51 83.260 13.300 4016.59 4085.69 5313.51 N 827.97 W 6014744.13 N 550984.84 E 6.598 5369.32 7559.10 82.630 11.550 4022.19 4091.29 5357.69 N 818.24 W 6014788.38 N 550994.26 E 4.052 5412.32 7609.52 82.630 10.360 4028.66 4097.76 5406.78 N 808.74 W 6014837.53 N 551003.42 E 2.341 5460.23 . 7657.86 83.560 9.300 4034.47 4103.57 5454.07 N 800.54 W 6014884.87 N 551011.29 E 2.905 5506.48 7705.79 86.600 9.580 4038.58 4107.68 5501.17 N 792.71 W 6014932.03 N 551018.79 E 6.369 5552.57 7753.65 88.830 11.670 4040.49 4109.59 5548.17 N 783.89 W 6014979.08 N 551027.28 E 6.383 5598.4 7 7801.87 89.750 11.800 4041.09 4110.19 5595.37 N 774.09 W 6015026.36 N 551036.76 E 1.927 5644.48 7849.35 90.190 10.010 4041.11 4110.21 5641.99 N 765.11 W 6015073.04 N 551045.42 E 3.882 5689.98 7898.70 90.560 8.940 4040.79 4109.89 5690.67 N 756.98 W 6015121.77 N 551053.20 E 2.294 5737.62 7945.80 88.640 8.340 4041.12 4110.22 5737.23 N 749.91 W 6015168.38 N 551059.95 E 4.271 5783.25 7994.41 86.980 6.240 4042.97 4112.07 5785.41 N 743.74 W 6015216.60 N 551065.78 E 5.504 5830.58 8046.52 87.220 4.910 4045.61 4114.71 5837.20 N 738.69 W 6015268.43 N 551070.48 E 2.590 5881.63 8090.14 90.800 3.360 4046.36 4115.46 5880.70 N 735.54 W 6015311.94 N 551073.32 E 8.943 5924.60 8140.32 92.530 1.310 4044.91 4114.01 5930.81 N 733.50 W 6015362.07 N 551075.01 E 5.344 5974.26 8186.27 92.840 359.040 4042.75 4111.85 5976.71 N 733.36 W 6015407.96 N 551074.84 E 4.981 6019.92 8230.67 91.920 358.160 4040.91 4110.01 6021.05 N 734.44 W 6015452.30 N 551073.44 E 2.866 6064.16 8280.27 94.080 358.470 4038.31 4107.41 6070.56 N 735.90 W 6015501.80 N 551071.64 E 4.399 6113.57 8330.28 94.260 358.510 4034.68 4103.78 6120.42 N 737.22 W 6015551.65 N 551069.98 E 0.369 6163.31 8376.73 95.130 358.620 4030.87 4099.97 6166.70 N 738.37 W 6015597.92 N 551068.50 E 1.888 6209.48 8423.22 94.820 0.620 4026.84 4095.94 6213.01 N 738.68 W 6015644.23 N 551067.87 E 4.337 6255.59 . 8472.92 95.380 358.450 4022.42 4091.52 6262.51 N 739.08 W 6015693.72 N 551067.13 E 4.492 6304.89 8532.00 95.380 358.450 4016.88 4085.98 6321.31 N 740.67 W 6015752.51 N 551065.13 E 0.000 6363.56 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 354.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8532.00fl., The Bottom Hole Displacement is 6364.55fl., in the Direction of 353.317° (True). 30 September, 2004· 10:12 Page 2 of 3 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 7457.24 7488.00 8532.00 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19PB2 (mwd) Your Ref: API 500292321871 Job No. AKMW3258923, Surveyed: 4 September, 2004 BPXA Station Coordinates TVD Northin9s Eastin9s (ft) (ft) (ft) 4079.32 4082.74 4085.98 Comment 5258.98 N 5288.77 N 6321.31 N . 840.30 W 833.44 W 740.67 W Tie On Point Window Point Projected Survey Survey tool program for MPI-19PB2 (mwd) From Measured Vertical Depth Depth (ft) (ft) 0.00 447.00 0.00 446.83 30 September, 2004 - 10:12 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 447.00 8532.00 446.83 CB-SS-GYRO (MPI-19PB1 (mwd») 4085.98 MWD Magnetic (MPI-19PB1 (mwd)) . Page 3 of 3 DrillQuest 3.03.06.006 . 1-04 I ~s . Winton, Please use this one instead. Pat Archey Sr. Drilling Engr. Wk.-564-5803 Cell 240-8035 -----Original Message---- From: Archey, Pat Sent: Monday, September 20, 2004 11 :00 AM To: Winton Aubert (E-mail) Subject: Surface Casing Grade correction for Milne Point Wells 14, 16, 17 & 19 ~ Winton, A-I\'l o6r. \~ ~o '/¡ This update is to correct the surface casing grade used in Milne Point I-Pad wells MPI-14, MPI-16, MPJ-17, MPI-19. There were 3 joints of L-80 casing run at surface and K-55 from that point to TD. Change wasas follows: ~ol.. \-;Ç Well Hole Size Casing Size Weight Grade Coupling MPI-14 13-1/2" 10-3/4" 45.5# K-55 & L-80 BTC-M MPI-16 12-114" 9-5/8" 40# K-55 & L-80 BTC-M MPI-17 13-1/2" 10-3/4" 45.5# K-55 & L-80 BTC-M MPI-19 13-1/2" 10-3/4" 45.5# K-55 & L-80 BTC-M Please let me know if you need anything else. Pat Archey Sr. Drilling Engr. Wk.-564-5803 Cell 240-8035 Content-Type: application/ms-tnef Content-Encoding: base64 .... e STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1!2 ~<, z:.J~ 7~ 1. Type of Request: o Abandon II Alter Casing II Change Approved Program o Repair Well o Pull Tubing o Operation Shutdown o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Re-Enter Suspended Well o Other o Time Extension -2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: a Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 204-135 6. API Number: 50- 029-23218-00-00 99519-6612 KBE = 69.3' 9. Well Name and Number: MPI-19 8. Property Designation: 10. Field I Pool(s): ADL 025906 Milne Point Unit I Schrader Bluff Total Depth MD (ft): Total Depth TVD (ft): N/A N/A Junk (measured): N/A Structural Conductor Surface Intermediate Production Liner t<t:CI:: ·Vt:U Perforation Depth MD (ft): I Perforation Depth TVD (ft): I N/A N/A Packers and SSSV Type: N/A Tubing Size: N/A 'n ?~'\4 14IÆ!ka 011 & Gas Cor S. Commi8øíon Tubing Grade: An~omge Tubing MD (ft): N/A I N/A Packers and SSSV MD (ft): N/A 12. Attachments: a Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory a Development 0 Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer 08/10/04 Date: 15. Well Status after proposed work: aOil o Gas o WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL Contact Skip Coyner, 564-4395 Phone 564-5803 Sundry Number: 1 ð 1/. .~ 3 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance .. Other: ~\.)\~~~ S c\;- a,\:~ ('-...ö..\ o...~~().\ ~~\\\.~~\'-{ , ú.\-<L~ a~ ~~ \ \. ORIGINAL ReDUS Bft Dm·1it¡æte AUG l' (j) 1(\(\-\ COMMISSIONER APPROVED BY THE COMMISSION e e - bp August 5, 2004 Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval MPI-19 204-135 MPI-19 Ll 204-136 As part of the captioned Applications for Permit to Drill, our 10-3/4" surface casing was specified to be set at 2545' MD (2319' TVD). Upon further review, we discovered that we had failed to case off the entire "build section" with this casing string. We now submit for approval the attached FormlO-403: Application. for Sundry Approval. This application is to modify the surface casing setting depth as follows: ~ 2930' MD (2511' TVD) which is through the "build section". Due to the additional 385' of casing, the surface casing cement job will be increased as follows: Casing Size 10-3/4",45.5#, L-80 & K-55, BTC Casing at 2,930' MD (2,511' TVD) Excess from B/Permafrost to Surface = 150% over gauge hole. Use 40% excess below the B/Permafrost. Tail cement = 500' MD. Basis Total Cement Volume: 418 bbl Wash 20 bbl water Spacer Lead Tail 75 bbl of MudPush 364 bbl, 461 sx of Arctic Set Lite: 10.7 ppg and 4.44 ft%x 54 bbl, 257 sx "G" mixed at 15.8Ib/gal & 1.17 ft3/SX If you have any questions or require any additional information, please contact the undersigned at 564-4395. Sincerely, s!t:yn~ Drilling Engineer BP Exploration (Alaska) Inc. e - MPI-19 Motherbore & "08" Lateral 13-1/2" Hole with Spud Mud Revised Setting Depth 10-3/4",40.5#, L-80, BTC at 2930' MD (2511' TVD) TOC < 4625' MD (3158' TVD) 9-7/8" Hole with LSND Mud 7 -5/8" Shoe set at 800 7470' MD (4079' TVD) 6-3/4" Hole with MOBM ..;.. { "~ MPI - 19 Dual-Lateral OA & 08 Producer -------------------------1 08 Sand Lateral: 7470' - 9722' MD 9722' MD 4079' - 4119' TVD S Coyner, 7/21/2004 -------------------------- . Æ\ ,- (E\ Ln.~ ...=¡ UL~ . [ill FRANK H. MURKOWSKI, GOVERNOR A.,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPI-19 BP Exploration (Alaska) Inc. Permit No: 204-135 Surface Location: 2319' NSL, 3521' WEL, SEC. 33, T13N, RlOE, UM Bottomhole Location: 4527' NSL, 4244' WEL, SEC. 28, T13N, RlOE, UM (DB) Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissi~~witness any required test. Contact the Commission's petroleum field inspector at (907) 65{?7(pager). . er~ly, f J .m~orm hair BY ORDER.5lF THE COMMISSION DATED this~ day of July, 2004 cc; Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. . . - bp July 14, 2004 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Request for a maximum 14-day BOPE test frequency for Doyon 14 MPI-19 Mr. Maunder: BP Exploration (Alaska) Inc. ("BP") hereby to requests an exception to 20 AAC 25.035(e)(1O)(A) per 20 AAC 25.035(h)(I) for a maximuml4-day BOPE test frequency for the Doyon 14 drilling rig. The requested exception pertains to the drilling of MPI-19, a dual lateral in the OA and OB sands. In the first 6 months 2004, Doyon 14 performed 21 successful BOPE tests. In these 21 tests, other auxiliary equipment failed on three occasions. On 30 Jan, the upper mop failed and was repaired. On 26 Mar, a gas detector and a floor valve failed and were repaired. On 18 May, the mop valve failed and was repaired. On 01 June, the Annular Preventer failed and was repaired. The BOPE test reports are available if required. The BOPE test record for Doyon 14 is very good. Recently, Doyon 14's BOPE was tested to 4500 psi with no failures. That test was on June 30th 2004, MPJ-25. If you have any questions or require any additional information, please contact the undersigned at 564-4395. Sincerely, /!&~ Drilling Engineer BP Exploration (Alaska) Inc. IBI Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2319' NSL, 3521' WEL, SEC. 33, T13N, R10E, UM ,I Top of Productive Horizon: 2293' NSL, 4438' WEL, SEC. 28, T13N, R10E, UM (OB) Total Depth: 4527' NSL, 4244' WEL, SEC. 28, T13N, R10E, UM (OB) / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551850 ¿ y- 6009437 ,¡ Zone- ASP4 16. Deviated Wells: Kickoff Depth: 300 ~ feet Maximum Hole Angle: 92 degrees . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory IBI Development Oil 0 Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPI-19 6. Proposed Depth: / 12. Field I Pool(s): MD 9722' j TVD 4119' Milne Point Unit I Schrader Bluff 7. Property Designation: ADL 025906 ~rdÝ 8. Land Use Permit: 13. Approximate Spud Date: 08/10104 14. Distance to Nearest Property: 7000' 9. Acres in Property: / 2560 10. KB Elevation KBE = I 15. Distance to Nearest Well Within Pool (Height above GL): 69.3' feet '5t> ~away from MPJ~J -ði~t' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) fÞ c ~ Downhole: 1875./ Surface: 1467 / -',/þ 18.ÇasingProgn:îm: ßp~ificatiol'\s Si:ze Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 92# H-40 Welded 80' 34' 34' 114' 114' 260 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC-M 2515' 30' 30' 2545' 2319' 397 sx AS Lite, 257 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 7440' 30' 30' 7470' 4079' 755 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 BTC 2385' 7337' 4054' 9722' 4119' Uncemented Slotted Liner PRESENT W£;LCCONDITION SUMMARY (To be(X)mpléte(JfÞrRadriIlANDREF~httYPpératìc:ÎnS) "Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): _ Structural Conductor Surface Intermediate Production Liner 20. Attachments 181 Filing Fee, $100 0 BOP Sketch o Property Plat 0 Díverter Sketch IPerfOration Depth TVD (ft): 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program 181 Shallow Hazard Analysis 18120 AAC 25.050 Requirements Date: Contact Skip Coyner, 564-4395 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Phone Permit To Number: Conditions of Approval: 50- ó '7'9 .? 2. ., 10 -Dà I Permit Approval . /- £- L...,JL-fQ Date: 7/3cyof Samples Required 0 Yes~No Mud Log Required 0 Yes RNo Hydroge ffi::~=:S~~::~. ~;:::¡:~:;~~~~~~, -/ 0 RIG I N A L ~~~~~~':~'ON Date ~i~: - bp . . I Well Name: I MPI-19 (Dual-Lateral) I Primary Wellbore & 08 Lateral Drill and Complete Plan Summary L Type of Well: Surface Location: (As Built) 7-5/8" Casinq Point: T/OB sand (Heel) 7470' MD OB Lateral: T lOB sand (Heel) 7470' MD OB Lateral. BHL: OB Lateral (Toe) 9722' MD ,/ OA Lateral. L-1: T/OA sand (Heel) 7187' MD OA Lateral. L-1: OA Lateral (Toe) 12253' MD Distance to Property line Distance to nearest pool I Schrader Bluff Dual-Lateral Producer ~ ,/ 23191 FSL, 2961' FNL, 35211 FEL, 1759' FWL SEC. 33, T13N, R10E./ / E = 551850' N = 6009437' Elevation DF = 69.3' 2293' FSL, 2986' FNL, 4438' FEL, 842' FWL SEC. 28, T13N, R10E E = 550883' N = 6014683' Z = 4079' TVD 2293' FSL, 2986' FNL, 4438' FEL, 842' FWL SEC. 28, T13N, R10E E = 550,883' N = 6,014,683' Z = 4,079' TVD 4527' FSL, 752' FNL, 4244' FEL, 1035' FWL ;" SEC. 28, T13N, R10E ./ E = 551055' N = 6016918' Z = 4119' TVD .. 2023' FSL, 3257' FNL, 4497' FEL, 782' FWL SEC. 28, T13N, R10E E = 550826' N = 6014412' Z = 4021' TVD 5260'FSL,20'FNL,1487'FEL,3793'FWL SEC.29,T13N,R10E E = 548526' N = 6017634' Z = 4054' TVD 7000' 200' from MPJ-09A AFE Number: I Estimated Start Date: August 10, 04 I Rig: I Doyon 14 Rig days to complete: 117 I MD: 19722' 1 I TVD: 14119' I I Max Inc: 1920 I I KOP: 1300' I I KBE: 169.3' Well Design (conventional, slim hole, etc.): I Dual-Lateral Producer Objective: I Schrader Bluff: OB & OA sands 1 . . CasingITubing Program Hole Csg I Tbg WtlFt Grade Conn Length Top Bottom Size O.D. MD I TVD MD I TVD 42" 20-in* 92# H-40 Welded 80' 34' 114' / 114' 13-1/2" 10.75-in 45.5# L-80 BTC-M 2,515' 30' 2,545' / 2,319' 9-7/8" 7.625-in 29.7# L-80 BTC-M 7,440' 30' 7,470' / 4,079' 6-3/4" 4.5-in 7,337' /4,054' 9,722' / 4,119' ,/ OB Slotted 12.6# L-80 BTC 2,385' 6-3/4" 4.5-in L-80 BTC 5,166' 7,087' /3,996' 12,253' I 4,054' OA Slotted 12.6# Mud Program: 13-1/2" Surface Hole (0 - 2545'): Density (ppg) PV YP HTHP pH 9.0 - 9.3 10 - 20 25 - 30 10 - 11 9.0 - 9.5 LSND API FiltratE LG Solids < 6 < 15 9-7/8" Intermediate Hole (2545' - 7470'): Density (ppg) PV YP HTHP pH 9.0 - 9.6 10 - 20 25 - 30 10 - 11 9.0 - 9.5 LSND API Filtratf.. LG Solids < 6 < 15 6-3/4" OB Production Hole (7470' - 9722'): MOBM I Density (ppg) I PV YP ,. HTHP I pH I API Filtrate LG Solids 9.0 - 9.4./ 15 - 25 18 - 25 10 - 11 9.0 - 9.5 < 6 I < 15 6-3/4" OA Production Hole (7187' - 12253'): MOBM I Density (Ppg) PV t YP I HTHP I pH. I API Filtrate 9.0 - 9.4 ,j 15 - 25 18 - 25 10 - 11 9.0 - 9.5 < 6 LG Solids I < 15 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 13-1/2" Surf - 2,545' 2,430' MT .60 - .80 450 - 650 2 9-7/8" 2,545' -7,470' 4,925' PDC .50 - .75 500 - 600 308 6-3/4" 7,470' - 9,722' 2,252' PDC .30 - .50 275 - 325 30A 6-3/4" 7,187' -12,253' 5,066' PDC .30 - .50 275 - 325 2 . . Cement Program: Casing Size Basis 10-3/4",45.5#, L-80, BTC Casing at 2,545' MD. FC at 2,460' MD. Excess from B/Permafrost to Surface = 150% over gauge hole. Use 40% excess below the B/Permafrost. Tail cement = 500' MD. Total Cement Volume: 368 bbl Wash Spacer Lead Tail Temp CasinQ Size Basis Total Cement Volume: 156 bbl 20 bbl water 75 bbl of MudPush 314 bbl, 397 sx of ,Arctic Set Lite: 10.7 ppg and 4.44 ffs/sx 54 bbl, 257 sx "G" mixed at 15.8 Ib/gal & 1.17 ffs/sx Casing Point BHST 450 F (estimated by Dowell) 7-5/8",29.7#, L-80, BTC-M Intermediate Casing at 7,470~· ... . Top of cement to be 500' MD above Ugnu sands [TOC = ~,625' M ] + 40% excess. Shoe Joint = 85 ft [7,385' to 7,470' MD] 5-bbl water Wash 25 bbl CW 100 Spacer 35 bbl of MudPush Tail 156 bbl, 755 sx "G" mixed at 15.8 Ib/gal & 1.16 ft::l/sx Temp BHST ==80°F from SOR Formation Markers: Formation Tops MD TVD (ft) Pore Pressure EMW (ft) (psi) (Ib/gal)* BPRF 1,892 1,819 TUZC 5,125 3,349 1424 8.35 Ugnu-MA 5,689 3,564 1518 8.35 Ugnu-MB1 5,715 3,574 1522 8.35 Ugnu-MB2 5,862 3,629 1546 8.35 Ugnu-MC 6,236 3,759 1602 8.35 SBF2-NA 6,479 3,829 1664 8.5 SBF1-NB 6,624 3,869 1682 8.5 SBE4-NC 6,734 3,899 1695 8.5 SBE2-NE 6,807 3,919 1704 8.5 SBE1-NF 7,007 3,974 1728 8.5 TSBD- Top OA 7,160 4,014 1746 8.5 TSBC-Base OA 7,291 4,044 1759 8.5 TSBB-Top OB 7,471 4,079 1775 8.5 SBAS-Base OB 9,461 4,109 1788 8.5 / OA owe 4,159 OBowe 4,214 3 . . Evaluation ProQram: 13-1/2" Section Open Hole: Cased Hole: MWD/GR IFR/CASANDRA Sperry InSite N/A 9-7/8" Section Open Hole: MWD/GRlRES IFRlCASANDRA Sperry InSite 6-3/4" Sections Open Hole: MWD/GRlRES/ABUPWD IFRlCASANDRA Sperry InSite Well Control: Intermediate/Production hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · BOP Test Interval: · Integrity tests: 1,875 psi at 4,079' TVD (Top of the OB sand) ,/ 1,467 psi at (Based on a full column of gas at 0.1 psi/ft) v 3,000 psi 14 days upon AOGCC approval. The test interval is based upon previously submitted BOP test history for Doyon 14 FIT to 11.0 Ib/gal 20' below the 10-3/4" shoe. FIT to 11.0 Ib/gal20' below the 7-5/8" shoe [OB sand] 75 bbl: 9.3 ppg mud below the 10-3/4" shoe wi 10 ppg LOT. MOBM in Laterals with 9.6 ppg Brine and Diesel above. Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: · Tight hole and packing off due to clays and poor hole cleaning has occurred on I Pad wells. · Over-Pressured sands have been encountered on I Pad due to offset injection wells. ,/ Lost Circulation · We do not expect losses while drilling this well. · Offset wells have not reported losses while drilling. However if seepage and/or losses occur, follow the LOST CIRCULATION DECISION MATRIX in the well plan. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures / · The Schrader Bluff is normally pressured in the targeted hydraulic unit: HU #1. Pad Data Sheet · Please Read the I-Pad Data Sheet thoroughly. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. / 4 . . Faults · One fault is mapped in the intermediate hole section: in the lower Ugnu at ± 6,221' MD. · One fault is mapped that intersects both the "OA" and "OB" laterals: at ± 8,200' MD. · Two additional faults intersect the "OA" lateral (L-1): at ± 10,900' MD and ± 11,500' MD. Hydrogen Sulfide · MPI Pad is not designated as an H2S Pad and no breathing hazards are expected. ./ / v ,/ Anti-collision Issues · MPI-19 passes the Major Risk Criteria in the Mother Bore and the L-1lateral. Gyro surveys will be required for close approach issues and magnetic interference to at least 900 ft MD. Distance to Nearest Property r-- · MPI-19 is 2,030 ft from the nearest Milne Point property line. ,/ Distance to Nearest Well Within Pool · MPI-19 is 200 ft from the nearest Schrader Bluff OB sand penetration in MPJ-09A. ' - DRILL & COMPLETION PROCEDURE Drillina 1. 2. 3. 4. 5. 6. 7. 8. 9. MIRT and NU Diverter Function Test Diverter, PU 4" DP and BHA. Drill 13-1/2" surface hole. Run and cement 1 0-3/4" surface casing. ND diverter, install wellhead and NUrrest BOP. Drill 9-7/8" intermediate hole. Run and cement 7-5/8" intermediate casing. Displace to MOBM. Drill 6-3/4" OB horizontal production hole. Run 4-1/2" slotted liner and hang off in 7-5/8" casing ~ \.. t\\'~-nL~ ""-'\<> ~~~\c)~Q\ /è. 5 I ASP GRID "\ -z-- 2"34'41" I I-PAD PLANT) ^ L----r L L 1.-< .14 .13 .12 .11 · 8 · 7 .4 · 6 · 3 · 5 · 2 · 9 r' !-~ .10 .15 +1-16 +1-17 +1-18 +1-19 _I L- "-- MPU I-PAD LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR ~ I VICINITY MAP N.T.S. è1 N 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.9999031 3. HORIZONTAL CONTROL IS BASED ON MPU I-PAD MONUMENTS 1-1 AND 1-2. 4. DATE OF SURVEY: JUNE 4, 2004. 5. REFERENCE FIELD BOOK: MP04-02 (PGS. 01-02). ~ ~ I ;>--1 I ~ SURVEYOR'S CERTIF1CA TE I HEREBY CERTIFY THAT I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT All DIMENSIONS AND OTHER DETAilS CORRECT AS OF JUNE 04, 2004. ,..; LOCATED WITHIN PROTRACTED SEC. 33, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DO) BOX ELEV. OFFSETS MPI-16 Y= 6,009,440.89 N 1,120.01 70'26'11.535" 70.4365375" 34.5' 2,324' X= 551,759.44 E 1,464.86 149"34'40.788" 149.5779967" 3,611' MPI-17 Y= 6,009,439.29 N 1,119.77 70"26'11.518" 70.4365328" 34.6' 2,323' FSL X= 551,789.57 E 1,495.03 149"34'39.904" 149.5777511" 3,581' FEL Y= 6,009,438.23 N 1,120.05 70"26'11.505" 70.4365292" 34.6' 2,321' FSL MPI-18 X= 551,819.32 E 1,524.80 149"34'39.032" 149.5775089' 3,551' FEL o 6/5/04 ISSUED FOR INF'ORMATlON NO. DATE REVISION F. Robert 1mI ffi~~ŒJ[¡;o DRAWN: JACOBS CHECKED: ALLISON DATE, 6/5/04 -DRAWING; FRB04 MPI 02-00 JOB NO: SCALE: 1'=150' bp MILNE POINT UNIT SHf;ET, AS-BUILT CONDUCTORS WELLS MPI-16. 1--17, 1-18 & 1-19 JJ RFA BY CHK (HGIN(ERSANOlMOSUR~ 8OI-gsr F1REI'ÆftI lANE ANCliORAGE.Al.AS!(Â~ Schrader BI ualLateral I MPI-19 Motherbore & "OB" Lateral 13-1/2" Hole with Spud Mud 10-3/4",40.5#, L-80, BTC at 2545' MD (2319' TVD) TOC < 4625' MD (3158' TVD) 9-7/8" Hole with LSND Mud S Coyner, 7/08/2004 7 -5/8" Shoe set at 800 7470' MD (4079' TVD) 6-3/4" Hole with MOBM MPI - 19 O-Sand, Dual-Lateral OA & 08 Producer . e -------------------------1 OB Sand Lateral: 7470' - 9722' MD 9722' MD "'- 4079' - 4119' TVD -------------------------- ________.-::-_---,----,----,-n--.---.---'''.:~-'c"---n-----____,_,:_'---n-----.-----______c------.=,:::---------~----------n--______c:-.;:::::,,_~~--~.,,~.-;:::--:--~;::::~;:::.-:-:::::::::._::::::=---~~~:.-:=_:_---------------n---------------:-.l 1-19 Motherbore n Lateral With liner in OB L-80, BTC at 2545' MD (2319' TVD) MPI .. 19 O-Sand, Dual-lateral OA & OB Producer TOC <: 4625' MD 58' TVD) S 9722' MD 9-7/8" Hole with LSND Mud HGR & ZXP at ± 7337' MD 6-3/4" --.....-.....---- tIIIIIIIIIi!..- _.-.JIiiIIIIIiIII1; -................ -........ ---; "" - .......- - COMPANY DETAILS REFERENCE INFORM-A. nON SURVEY PROGRAM Depth Fm Depth TQ Survey!PJan 3430 J400JJO !4iliWO 9721.&2 CB-GYRO-SS MWD+!FR+MS SP Amoco / Tool Plan: MPJ- ¡ 9 wp06 (Plan MP¡~ J9!MPI· 19) Dtlte Re\"iewed Created By; Troy Jakabosky Checked 69.30 Date: 5/20/2004 Date CASING DETAILS FORMATION TOP DETAlLS WELL DETAILS N_ +N/-S NOrthing Efu.iing Latiwœ Longitude Slot Plan MPJ-19 1û}¡W9 16J120 600943óJG 551849.84 70"26'11.41WN 149"]4'3íU36W NfA No. TVD MD Name Size No. TVDPath MDPath Formarion 1 1819.30 2 3349.30 3 3564.30 4 3514.30 5 3629.30 6 3759.30 7 3829.30 8 3869.30 9 3899.30 10 3919.30 11 3914.30 12 4014.30 13 4044.30 ¡ 4 4079.30 15 4109.30 BPRF TUZC Ugnu-MA Ugnu-MBl Ugnu-MB2 Ugnu-MC SBF2-NA SBFI-NB SBE4-NC SBE2-NE SBEI-NF TSBD-Top OA TSBC-Base OA TSBB-Top OB SBA5-Base OB TARGET DETAILS 4.5" Name TVD +N!-S +E/-W Northìng Start Dir !lIOO·: 301.3' MD.301.3'TVD SECTION DETAJLS See MD Ine Azi TVD +NI-S +EI-W DLeg TFace 1 0.00 0.00 2 0.00 0.00 3 -1.05 1.00 4 -52.54 2.00 5 -94.89 3.00 6 - 132.86 0.00 7 -319.30 4.00 8 -960.00 0.00 9 - 1000.00 4.00 10 -1000.00 0.00 11 -1000.00 4.00 12 -1000.00 0,00 13 -1000.00 0.00 14 -930,00 4.00 15 -844.16 4.00 16 -831.99 0.00 11 -814.99 4.00 18 -813.13 4.00 19 -800.32 0.00 20 -799.99 4.00 21 -795.73 4.00 22 -742.87 0.00 Stdrt Dir2/100·: SOU· MD, S0L26'TVD Start Dir 31l00·: 1401.3' MD, J38!.!'TVD 2927.26' MD, 2SJO.û2· TVD '¡;' ~ 8 ~ "" & Ç¡ '" " 'E " > " 2700- ~ Easting Shape VSee Target ESP END A MPI-19 Mpl-19 TIC T2A : 623M3' MD, 3759.3'TVD ESP END A MPI- I 9 ø End Dir : 6337.88' MD, 3790.59' TVD Fault I MPI-19 TIC Start Dir 4/100' : 701 1.09' MD, 397S.5'TVD End Dir : 7841.57' MD, 4104.92' TVD / Start Dir4/JOO'; 7918.46' MD, 4102. 18'TVD End Dir ; 8133.1" MD, 4098.96· TVD Fault 2 3600 I ¡I .. f ¡ ¡ ¡ G"OMPANYDETAIlS ßP AwOCú REFERENCE INFORMA nON 6930 720 - TÅ,.' ri,_)h i O~"j ,¡¡;trJJ:. it, it I - !M I - ..... - -.. 0- _. - - "" 'r Iff - 0- Ì"" V - 0- i-, ~. - ¡- Ii - D - ~ - - ~ 0- c···· - .. ¡f '. II T - 1+ ¡ I ¡ - I ! , - - !i ! " - .¡ ! ! ¡ ........... - -. i ...........¡. ···il - ; j\ ~. rvtJ ....... 0- i ~ - I - 0 ! ! l- i c '1 ! I c c ì ¡ 'c' , ¡ , , , j .J , I '. , , 600 480 '" ~ '" '" :: +" € ~ 360 ~ " " If> 240 120 o Depth Fm D¢pth To SUrvey/Plan 3430 1400.00 !400JiO 9721.82 Sec MD 1 2 3 4 5 6 7 8 9 10 1] 12 13 14 15 16 17 18 19 20 21 22 No. TVD 1 2 3 MD 2545.05 7470.00 972 1.00 SURVEY PROORAM Ine CASJNG DETAILS Name FORMAT10N TOP DETAILS No. TVDPath MDPath Nllmc 1'001 CB.G¥RO-$S MWrÞ!FR+MS Reviewed· WELL DETAILS '·Ni-S Nortbipg - Plan: MPI-19 wp06 (Plan MPf- 19/MP!- J 9) (Teated By: Troy Jalmbosky Checked: Date: 5J20/2004 Date: Date: Easring LatitlKk wngítude S!m PIM! MPJ-!9 1038.09 161}2(¡ 6ûü9436.iG 5511549.84 10°26'1 L489N 149°34'38.136W N/A Name Azi TVD TARGET DET ArLS TVD +N/-S +EI-W Northî:ng Basting Shape- SECTION DETAILS +N/·S +E/-W Size 10.750 7.625 4.500 DLeg TF""e 0.00 0.00 l.oo 2.00 3.00 0.00 4.00 0.00 4.00 0.00 4.00 0.00 0.00 4.00 4,00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 VSec Target ESP END A MPI·19 MPI·19 TIC MPI·19 T2A MPI·19T3A MPI·19 T4A MPI-19 T5A e . BP-GDB BP Planning Report Plan: MPI-19 wp06 Date Composed: Version: Tied-to: 4/27/2004 93 From Well Ref. Point Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008388.01 ft 550245.83 ft Latitude: 70 26 Longitude: 149 35 North Reference: Grid Convergence: 1.282 N 25.422 W True 0.39 deg Well: Plan MPI-19 Slot Name: Well Position: +N/-S 1038.09 ft Northing: 6009436.83 ft Latitude: 70 26 11.489 N +E/-W 1611.20 ft Easting : 551849.84 ft Longitude: 149 34 38.136 W Position Uncertainty: 0.00 ft Casing Points 2545.05 2319.00 10.750 13.500 10 3/4" 7470.00 4079.18 7.625 8.500 7-5/8" 9721.00 4119.27 4.500 6.125 4.5" Formations Lithqlogy 1892.23 1819.30 BPRF 0.00 0.00 5125.42 3349.30 TUZe 0.00 0.00 5688.53 3564.30 Ugnu-MA 0.00 0.00 5714.78 3574.30 Ugnu-MB1 0.00 0.00 5862.36 3629.30 Ugnu-MB2 0.00 0.00 6236.43 3759.30 Ugnu-MC 0.00 0.00 6478.80 3829.30 SBF2-NA 0.00 0.00 6624.43 3869.30 SBF1-NB 0.00 0.00 6733.65 3899.30 SBE4-NC 0.00 0.00 6806.47 3919.30 SBE2-NE 0.00 0.00 7006.71 3974.30 SBE1-NF 0.00 0.00 7160.47 4014.30 TSBD-Top OA 0.00 0.00 7290.86 4044.30 TSBC-Base OA 0.00 0.00 7470.72 4079.30 TSBB-Top OB 0.00 0.00 9460.85 4109.30 SBA5-Base OB 0.00 0.00 6370.00 3799.42 Fault #1 0.00 0.00 8170.00 4098.48 Fault #2 0.00 0.00 Targets Map Northing ft ESP END A MPI-19 3759.30 4069.00 -1000.00 6013498.39 550821.68 70 26 51.506 N 149 35 7.500 W MPI-19 T1C 3859.30 4406.00 -1000.00 6013835.35 550819.34 70 26 54.821 N 149 35 7.502 W MPI-19 T2A 4079.30 5253.00 -930.00 6014682.73 550883.44 70 27 3.151 N 149 35 5.449 W MPI-19 Geo Poly 4079.30 5253.00 -930.00 6014682.73 550883.44 70 27 3.151 N 149 35 5.449 W -Polygon 1 4079.30 5655.80 -711.60 6015087.00 551099.00 70 27 7.113 N 149 34 59.036 W -- . . BP-GDB BP Planning Report Company: Field: Site: WeD: WeDpath: Targets BP Amoco Milne Point MPtIPad Plan MPI-19 MPI-19 Date: 6/22/2004 Time: 10:08:54 Page: 2 Co-ordinate(NE) Reference: Well: Plan MPI':19. True North Vertical (TVD) Reference: 69.3 RKB(34.3 + 35) 69.3 Section (VS) Reference: Well (O.OON,O.00E,354.33Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Map <-- Latitude --> <- Longitude -> Name Description TVD +N/-S +EI-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft -Polygon 2 4079.30 7634.58 -644.84 6017066.00 551152.00 70 27 26.573 N 149 34 57.080 W -Polygon 3 4079.30 7642.69 -948.82 6017072.00 550848.00 70 27 26.653 N 149 35 6.011 W -Polygon 4 4079.30 5664.04 -1032.59 6015093.00 550778.00 70 27 7.193 N 149 35 8.464 W -Polygon 5 4079.30 5150.73 -1141.17 6014579.00 550673.00 70 27 2.145 N 149 3511.650 W -Polygon 6 4079.30 5147.72 -709.14 6014579.00 551105.00 70 27 2.116 N 149 34 58.962 W MPI-19 T4A 4089.30 6659.18 -799.99 6016089.64 551003.65 70 27 16.980 N 149 35 1.635 W MPI-19 T3A 4099.30 5847.85 -814.99 6015278.30 550994.29 70 27 9.001 N 149 35 2.073 W MPI-19 T5A 4119.30 7487.24 -742.87 6016918.00 551055.01 70 27 25.124 N 149 34 59.960 W Plan Section Information MD Incl Azim TVD +N/-S +EI~W DLS BUild Tnrn TFØ TaJ:get ft deg deg ft ft ft deg/100ft degl100ft degl100ft deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 301.30 0.00 0.00 301.30 0.00 0.00 0.00 0.00 0.00 0.00 501.30 2.00 342.48 501.26 3.33 -1.05 1.00 1.00 0.00 342.48 1401.30 20.00 342.48 1381.10 166.42 -52.54 2.00 2.00 0.00 0.00 1734.63 30.00 342.48 1682.81 300.59 -94.89 3.00 3.00 0.00 0.00 1986.92 30.00 342.48 1901.30 420.88 -132.86 0.00 0.00 0.00 0.00 2927.26 67.55 345.48 2510.02 1089.94 -319.30 4.00 3.99 0.32 4.55 5692.80 67.55 345.48 3565.93 3564.36 -960.00 0.00 0.00 0.00 0.00 6036.43 70.00 0.00 3690.90 3881.06 -1000.00 4.00 0.71 4.22 82.45 6236.43 70.00 0.00 3759.30 4069.00 -1000.00 0.00 0.00 0.00 0.00 ESP END A MPI-19 6337.88 74.06 0.00 3790.59 4165.48 -1000.00 4.00 4.00 0.00 0.00 6588.02 74.06 0.00 3859.30 4406.00 -1000.00 0.00 0.00 0.00 0.00 MPI-19 T1C 7011.09 74.06 0.00 3975.50 4812.80 -1000.00 0.00 0.00 0.00 0.00 7470.72 80.03 17.85 4079.30 5253.00 -930.00 4.00 1.30 3.88 73.22 MPI-19 T2A 7841.57 92.05 9.12 4104.92 5611.81 -844.16 4.00 3.24 -2.36 -36.38 7918.46 92.05 9.12 4102.18 5687.67 -831.99 0.00 0.00 0.00 0.00 8079.64 90.00 3.00 4099.30 5847.85 -814.99 4.00 -1.27 -3.79 -108.42 MPI-19 T3A 8133.10 90.74 0.99 4098.96 5901.27 -813.13 4.00 1.38 -3.75 -69.79 8872.71 90.74 0.99 4089.42 6640.71 -800.32 0.00 0.00 0.00 0.00 8891.18 90.00 1.00 4089.30 6659.18 -799.99 4.00 -4.00 0.04 179.46 MPI-19 T4A 8986.67 87.80 4.13 4091.13 6754.53 -795.73 4.00 -2.30 3.27 125.12 9721.82 87.80 4.13 4119.30 7487.24 -742.87 0.00 0.00 0.00 0.00 MPI-19 T5A Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE Too V:::omn ft deg deg ft ft ft ft degl100ft ft ft 34.30 0.00 0.00 34.30 -35.00 0.00 0.00 0.00 6009436.83 551849.84 CB-GYRO-SS 100.00 0.00 0.00 100.00 30.70 0.00 0.00 0.00 6009436.83 551849.84 CB-GYRO-SS 200.00 0.00 0.00 200.00 130.70 0.00 0.00 0.00 6009436.83 551849.84 CB-GYRO-SS 301.30 .I 0.00 0.00 301.30 232.00 0.00 0.00 0.00 6009436.83 551849.84 Start Dir 1/100' : 301. 400.00 0.99 342.48 400.00 330.70 0.81 -0.26 1.00 6009437.64 551849.58 CB-GYRO-SS 501.30 2.00 342.48 501.26 431.96 3.33 -1.05 1.00 6009440.15 551848.77 Start Dir 2/100' : 501. 600.00 3.97 342.48 599.82 530.52 8.23 -2.60 2.00 6009445.04 551847.18 CB-GYRO-SS 700.00 5.97 342.48 699.44 630.14 16.50 -5.21 2.00 6009453.29 551844.52 CB-GYRO-SS 800.00 7.97 342.48 798.69 729.39 28.08 -8.86 2.00 6009464.84 551840.78 CB-GYRO-SS 900.00 9.97 342.48 897.46 828.16 42.95 -13.56 2.00 6009479.68 551835.98 CB-GYRO-SS 1000.00 11.97 342.48 995.63 926.33 61.11 -19.29 2.00 6009497.79 551830.13 CB-GYRO-SS 1100.00 13.97 342.48 1093.07 1023.77 82.51 -26.05 2.00 6009519.15 551823.22 CB-GYRO-SS 1200.00 15.97 342.48 1189.67 1120.37 107.15 -33.83 2.00 6009543.73 551815.27 CB-GYRO-SS 1300.00 17.97 342.48 1285.31 1216.01 134.99 -42.61 2.00 6009571.51 551806.29 CB-GYRO-SS 1401.30 20.00 342.48 1381.10 1311.80 166.42 -52.54 2.00 6009602.86 551796.15 Start Dir 3/100' : 140· 1500.00 22.96 342.48 1472.93 1403.63 200.88 -63.41 3.00 6009637.24 551785.04 MWD+IFR+MS . . BP-GDB BP Planning Report Survey 1600.00 25.96 342.48 1563.94 1494.64 240.36 -75.88 3.00 6009676.64 551772.30 MWD+IFR+M3 1700.00 28.96 342.48 1652.67 1583.37 284.33 -89.76 3.00 6009720.50 551758.12 MWD+IFR+M3 1734.63 30.00 342.48 1682.81 1613.51 300.59 -94.89 3.00 6009736.72 551752.87 End Dir : 1734.63' M 1800.00 30.00 342.48 1739.42 1670.12 331.75 -104.73 0.00 6009767.81 551742.82 MWD+IFR+M3 1892.23 30.00 342.48 1819.30 1750.00 375.73 -118.61 0.00 6009811.69 551728.63 BPRF 1900.00 30.00 342.48 1826.03 1756.73 379.43 -119.78 0.00 6009815.38 551727.44 MWD+IFR+MS 1986.92 30.00 342.48 1901.30 1832.00 420.88 -132.86 0.00 6009856.73 551714.07 Start Dir 4/100' : 1981 2000.00 30.52 342.56 1912.60 1843.30 427.16 -134.84 4.00 6009863.01 551712.04 MWD+IFR+MS 2100.00 34.51 343.11 1996.91 1927.61 478.52 -150.69 4.00 6009914.24 551695.84 MWD+IFR+MS 2200.00 38.50 343.56 2077.27 2007.97 535.50 -167.73 4.00 6009971.10 551678.41 MWD+IFR+MS 2300.00 42.49 343.94 2153.30 2084.00 597.84 -185.89 4.00 6010033.30 551659.81 MWD+JFR+MS 2400.00 46.49 344.26 2224.62 2155.32 665.23 -205.08 4.00 6010100.55 551640.16 MWD+IFR+MS 2500.00 50.48 344.55 2290.89 2221.59 737.33 -225.20 4.00 6010172.51 551619.54 MWD+IFR+M3 2545.05 52.28 344.66 2319.00 2249.70 771.27 -234.54 4.00 6010206.37 551609.96 10 3/4" 2600.00 54.48 344.80 2351.78 2282.48 813.81 -246.16 4.00 6010248.83 551598.06 MWD+IFR+M3 2700.00 58.47 345.03 2407.00 2337.70 894.29 -267.85 4.00 6010329.15 551575.81 MWD+IFR+MS 2800.00 62.47 345.24 2456.27 2386.97 978.37 -290.16 4.00 6010413.06 551552.91 MWD+IFR+M3 2900.00 66.46 345.43 2499.37 2430.07 1065.65 -313.00 4.00 6010500.17 551529.47 MWD+IFR+M3 2927.26 67.55 345.48 2510.02 2440.72 1089.94 -319.30 4.00 6010524.42 551523.00 End Dir : 292726' M 3000.00 67.55 345.48 2537.79 2468.49 1155.02 -336.15 0.00 6010589.37 551505.70 MWD+IFR+MS 3100.00 67.55 345.48 2575.97 2506.67 1244.49 -359.32 0.00 6010678.67 551481.91 MWD+IFR+MS 3200.00 67.55 345.48 2614.15 2544.85 1333.97 -382.49 0.00 6010767.98 551458.12 MWD+IFR+M3 3300.00 67.55 345.48 2652.33 2583.03 1423.44 -405.66 0.00 6010857.28 551434.34 MWD+IFR+MS 3400.00 67.55 345.48 2690.51 2621.21 1512.91 -428.82 0.00 6010946.58 551410.55 MWD+IFR+M3 3500.00 67.55 345.48 2728.70 2659.40 1602.39 -451.99 0.00 6011035.88 551386.77 MWD+JFR+MS 3600.00 67.55 345.48 2766.88 2697.58 1691.86 -475.16 0.00 6011125.18 551362.98 MWD+IFR+M3 3700.00 67.55 345.48 2805.06 2735.76 1781.33 -498.32 0.00 6011214.48 551339.19 MWD+IFR+MS 3800.00 67.55 345.48 2843.24 2773.94 1870.81 -521.49 0.00 6011303.79 551315.41 MWD+JFR+MS 3900.00 67.55 345.48 2881.42 2812.12 1960.28 -544.66 0.00 6011393.09 551291.62 MWD+IFR+MS 4000.00 67.55 345.48 2919.60 2850.30 2049.75 -567.83 0.00 6011482.39 551267.83 MWD+IFR+MS 4100.00 67.55 345.48 2957.78 2888.48 2139.23 -590.99 0.00 6011571.69 551244.05 MWD+JFR+MS 4200.00 67.55 345.48 2995.96 2926.66 2228.70 -614.16 0.00 6011660.99 551220.26 MWD+IFR+M3 4300.00 67.55 345.48 3034.14 2964.84 2318.17 -637.33 0.00 6011750.29 551196.47 MWD+IFR+MS 4400.00 67.55 345.48 3072.33 3003.03 2407.65 -660.49 0.00 6011839.59 551172.69 MWD+JFR+MS 4500.00 67.55 345.48 3110.51 3041.21 2497.12 -683.66 0.00 6011928.90 551148.90 MWD+IFR+MS 4600.00 67.55 345.48 3148.69 3079.39 2586.59 -706.83 0.00 6012018.20 551125.12 MWD+IFR+MS 4700.00 67.55 345.48 3186.87 3117.57 2676.07 -730.00 0.00 6012107.50 551101.33 MWD+IFR+MS 4800.00 67.55 345.48 3225.05 3155.75 2765.54 -753.16 0.00 6012196.80 551077.54 MWD+IFR+M3 4900.00 67.55 345.48 3263.23 3193.93 2855.01 -776.33 0.00 6012286.10 551053.76 MWD+IFR+MS 5000.00 67.55 345.48 3301.41 3232.11 2944.49 -799.50 0.00 6012375.40 551029.97 MWD+IFR+M3 5100.00 67.55 345.48 3339.59 3270.29 3033.96 -822.66 0.00 6012464.70 551006.18 MWD+IFR+M3 5125.42 67.55 345.48 3349.30 3280.00 3056.71 -828.55 0.00 6012487.41 551000.14 TUZC 5200.00 67.55 345.48 3377.77 3308.47 3123.43 -845.83 0.00 6012554.01 550982.40 MWD+IFR+MS 5300.00 67.55 345.48 3415.96 3346.66 3212.91 -869.00 0.00 6012643.31 550958.61 MWD+IFR+M3 5400.00 67.55 345.48 3454.14 3384.84 3302.38 -892.17 0.00 6012732.61 550934.82 MWD+IFR+MS 5500.00 67.55 345.48 3492.32 3423.02 3391.85 -915.33 0.00 6012821.91 550911.04 MWD+IFR+M3 5600.00 67.55 345.48 3530.50 3461.20 3481.33 -938.50 0.00 6012911.21 550887.25 MWD+JFR+MS 5688.53 67.55 345.48 3564.30 3495.00 3560.54 -959.01 0.00 6012990.27 550866.19 Ugnu-MA 5692.80 67.55 345.48 3565.93 3496.63 3564.36 -960.00 0.00 6012994.08 550865.18 Start Dir 4/100' : 569: 5700.00 67.59 345.79 3568.68 3499.38 3570.81 -961.65 4.00 6013000.52 550863.48 MWD+IFR+M3 5714.78 67.67 346.43 3574.30 3505.00 3584.07 -964.93 4.00 6013013.76 550860.11 Ugnu-MB1 5800.00 68.18 350.06 3606.34 3537.04 3661.38 -981.01 4.00 6013090.94 550843.49 MWD+JFR+M3 5862.36 68.60 352.71 3629.30 3560.00 3718.69 -989.70 4.00 6013148.19 550834.41 Ugnu-MB2 . . BP-GDB BP Planning Report Survey 5900.00 68.88 354.30 3642.95 3573.65 3753.55 -993.67 4.00 6013183.01 550830.20 MWD+IFR+MS 6000.00 69.68 358.48 3678.34 3609.04 3846.87 -999.54 4.00 6013276.28 550823.67 MWD+IFR+MS 6036.43 70.00 0.00 3690.90 3621.60 3881.06 -1000.00 4.00 6013310.47 550822.98 End Dir : 603ôA3' M 6100.00 70.00 0.00 3712.64 3643.34 3940.80 -1000.00 0.00 6013370.20 550822.57 MWD+IFR+MS 6200.00 70.00 0.00 3746.84 3677.54 4034.77 -1000.00 0.00 6013464.16 550821.92 MWD+IFR+MS 6236.43 70.00 0.00 3759.30 3690.00 4069.00 -1000.00 0.00 6013498.39 550821.68 ESP END A fvF 1-19 6300.00 72.54 0.00 3779.71 3710.41 4129.20 -1000.00 4.00 6013558.58 550821.26 MWD+IFR+MS 6337.88 74.06 0.00 3790.59 3721.29 4165.48 -1000.00 4.00 6013594.85 550821.01 End Dìr : 6337.88' M 6370.00 74.06 0.00 3799.42 3730.12 4196.37 -1000.00 0.00 6013625.74 550820.79 Fault #1 6400.00 74.06 0.00 3807.66 3738.36 4225.21 -1000.00 0.00 6013654.58 550820.59 MWD+IFR+MS 6478.80 74.06 0.00 3829.30 3760.00 4300.98 -1000.00 0.00 6013730.34 550820.07 SBF2-NA 6500.00 74.06 0.00 3835.12 3765.82 4321.37 -1000.00 0.00 6013750.72 550819.92 MWD+IFR+MS 6588.02 74.06 0.00 3859.30 3790.00 4406.00 -1000.00 0.00 6013835.35 550819.34 MPI-19 T1C 6600.00 74.06 0.00 3862.59 3793.29 4417.52 -1000.00 0.00 6013846.86 550819.26 MWD+IFR+MS 6624.43 74.06 0.00 3869.30 3800.00 4441.01 -1000.00 0.00 6013870.35 550819.09 SBF1-NB 6700.00 74.06 0.00 3890.06 3820.76 4513.67 -1000.00 0.00 6013943.00 550818.59 MWD+IFR+MS 6733.65 74.06 0.00 3899.30 3830.00 4546.03 -1000.00 0.00 6013975.36 550818.36 SBE4-NC 6800.00 74.06 0.00 3917.52 3848.22 4609.83 -1000.00 0.00 6014039.15 550817.92 MWD+IFR+MS 6806.47 74.06 0.00 3919.30 3850.00 4616.05 -1000.00 0.00 6014045.36 550817.88 SBE2-NE 6900.00 74.06 0.00 3944.99 3875.69 4705.98 -1000.00 0.00 6014135.29 550817.25 MWD+IFR+M S 7000.00 74.06 0.00 3972.46 3903.16 4802.13 -1000.00 0.00 6014231.43 550816.58 MWD+IFR+MS 7006.71 74.06 0.00 3974.30 3905.00 4808.59 -1000.00 0.00 6014237.88 550816.54 SBE1-NF 7011.09 74.06 0.00 3975.50 3906.20 4812.80 -1000.00 0.00 6014242.10 550816.51 Start Dir 4/100' : 701· 7100.00 75.11 3.52 3999.14 3929.84 4898.45 -997.35 4.00 6014327.76 550818.55 MWD+IFR+MS 7160.47 75.86 5.90 4014.30 3945.00 4956.79 -992.54 4.00 6014386.12 550822.96 TSBD-Top OA 7200.00 76.36 7.44 4023.79 3954.49 4994.90 -988.09 4.00 6014424.26 550827.15 MWD+IFR+M S 7290.86 77.55 10.97 4044.30 3975.00 5082.26 -973.92 4.00 6014511.70 550840.71 TSBC-Base OA 7300.00 77.67 11.32 4046.26 3976.96 5091.02 -972.19 4.00 6014520.47 550842.37 MWD+IFR+MS 7400.00 79.04 15.16 4066.45 3997.15 5186.33 -949.76 4.00 6014615.93 550864.14 MWD+IFR+MS 7470.00 80.02 17.83 4079.18 4009.88 5252.33 -930.21 4.00 6014682.05 550883.23 7-5/8" 7470.72 80.03 17.85 4079.30 4010.00 5253.00 -930.00 4.00 6014682.73 550883.44 MPI-19 T2A 7500.00 80.98 17.15 4084.13 4014.83 5280.54 -921.31 4.00 6014710.33 550891.93 MWD+IFR+MS 7600.00 84.21 14.77 4097.03 4027.73 5375.87 -894.05 4.00 6014805.83 550918.53 MWD+IFR+MS 7700.00 87.45 12.43 4104.30 4035.00 5472.79 -870.61 4.00 6014902.90 550941.29 MWD+IFR+MS 7800.00 90.70 10.09 4105.92 4036.62 5570.83 -851.10 4.00 6015001.07 550960.12 MWD+IFR+MS 7841.57 92.05 9.12 4104.92 4035.62 5611.81 -844.16 4.00 6015042.09 550966.77 End Dìr : 7841.!j7' M 7900.00 92.05 9.12 4102.84 4033.54 5669.46 -834.91 0.00 6015099.80 550975.62 MWD+IFR+MS 7918.46 92.05 9.12 4102.18 4032.88 5687.67 -831.99 0.00 6015118.03 550978.41 Start Dir 4/100' : 7911 8000.00 91.01 6.02 4100.00 4030.70 5768.47 -821.26 4.00 6015198.89 550988.58 MWD+IFR+MS 8079.64 90.00 3.00 4099.30 4030.00 5847.85 -814.99 4.00 6015278.30 550994.29 MPI-19 T3A 8100.00 90.28 2.24 4099.25 4029.95 5868.18 -814.07 4.00 6015298.64 550995.08 MWD+IFR+MS 8133.10 90.74 0.99 4098.96 4029.66 5901.27 -813.13 4.00 6015331.74 550995.78 End Dir : 8133.1' MC 8170.00 90.74 0.99 4098.48 4029.18 5938.16 -812.49 0.00 6015368.62 550996.17 Fault #2 8200.00 90.74 0.99 4098.09 4028.79 5968.15 -811.97 0.00 6015398.62 550996.48 MWD+IFR+MS 8300.00 90.74 0.99 4096.80 4027.50 6068.13 -810.24 0.00 6015498.59 550997.51 MWD+IFR+MS 8400.00 90.74 0.99 4095.51 4026.21 6168.11 -808.51 0.00 6015598.57 550998.55 MWD+IFR+MS 8500.00 90.74 0.99 4094.22 4024.92 6268.08 -806.77 0.00 6015698.55 550999.59 MWD+IFR+MS 8600.00 90.74 0.99 4092.94 4023.64 6368.06 -805.04 0.00 6015798.52 551000.63 MWD+IFR+MS 8700.00 90.74 0.99 4091.65 4022.35 6468.04 -803.31 0.00 6015898.50 551001.67 MWD+IFR+MS 8800.00 90.74 0.99 4090.36 4021.06 6568.01 -801.58 0.00 6015998.48 551002.70 MWD+IFR+MS 8872.71 90.74 0.99 4089.42 4020.12 6640.71 -800.32 0.00 6016071.17 551003.46 Start Dir .4/1 O~' : 887 8891.18 90.00 1.00 4089.30 4020.00 6659.18 -799.99 4.00 6016089.64 551003.65 MPI-19 T4A . . BP-GDB BP Planning Report Survey 8900.00 89.80 1.29 4089.32 4020.02 6667.99 -799.82 4.00 6016098.45 551003.76 MWD+IFR+MS 8986.67 87.80 4.13 4091.13 4021.83 6754.53 -795.73 4.00 6016185.01 551007.25 End Dir : 898-5.57' M 9000.00 87.80 4.13 4091.64 4022.34 6767.82 -794.77 0.00 6016198.30 551008.12 MWD+IFR+MS 9100.00 87.80 4.13 4095.47 4026.17 6867.49 -787.58 0.00 6016298.01 551014.62 MWD+IFR+M5 9200.00 87.80 4.13 4099.30 4030.00 6967.15 -780.39 0.00 6016397.71 551021.11 MWD+IFR+MS 9300.00 87.80 4.13 4103.14 4033.84 7066.82 -773.20 0.00 6016497.42 551027.61 MWD+IFR+MS 9400.00 87.80 4.13 4106.97 4037.67 7166.49 -766.01 0.00 6016597.13 551034.10 MWD+IFR+M5 9460.85 87.80 4.13 4109.30 4040.00 7227.14 -761.64 0.00 6016657.80 551038.05 SBAS-Base OB 9500.00 87.80 4.13 4110.80 4041.50 7266.16 -758.82 0.00 6016696.83 551040.60 MWD+IFR+MS 9600.00 87.80 4.13 4114.63 4045.33 7365.82 -751.63 0.00 6016796.54 551047.09 MWD+IFR+M 5 9700.00 87.80 4.13 4118.46 4049.16 7465.49 -744.44 0.00 6016896.24 551053.59 MWD+IFR+MS 9721.00 87.80 4.13 4119.27 4049.97 7486.42 -742.93 0.00 6016917.18 551054.95 4.5" .I 9721.82 87.80 4.13 4119.30 ~ 4050.00 7487.24 -742.87 0.00 6016918.00 551055.01 MPI-19 T5A WELL DETAILS Nmne .c,.PJ·W Northing Euting Latitude Longitude S!ot PJanMPJ-19 1038.œ 1611.20 6(109436,83 551849.84 70~2ó'IL4&9N ¡49Q}4'38.136W NlA ANTI-COLLISfON SETTrNüS COMPANY DETAILS fnte Dep Maximum Interval: To: Referenc_c: -209 -196 -163 -131 --98 -65 -33 -0 -33 ""'"'65 ~8 -131 -163 -196 SF Amoco ----------j SURVEY PROGR.-\M Depth Fm lx-pth 1'0 Survey!P1an 3430 1400.00 1400.00 9721.82 Too! CB-GYRO-S$ MWD+IfR+MS WELLPA TH DETAILS From Colour ToMD MPJ-I-9 0 0 Rig: 0 500 Ref. [)mum:; 69.3 RKB(3-43 -. 35) 69300 500 1000 Origin Starting +Ni-S From TVD 1000 1500 354j3~ 0.00 0.00 34.30 1500 2000 2000 2500 2500 3000 3000 3500 3500 4000 4000 4500 4500 5000 5000 5500 5500 6500 6500 7500 7500 8500 8500 9500 9500 10500 90 goo Mil me >A.zi 1 2 3 4 5 6 1 , 9 10 11 12 13 14 15 16 17 18 19 20 21 22 TVD SECTION DETAILS +Nf·S +E!-W DLeg TFaœ v~ Target M,P!,.!9T4A MPI·19 TSA ESP END A MPI-!9 MPI~19 TIC MPI~19 T2A lvœJ~19 TJA Anticollision Report SCAN APPLIED: All wellpaths within 2110'+ 1011110110 of reference Method: MD Interval: 25.00 ft 34.30 to 9721.82 ft 1168.75 ft R.eferenee: Error Model: Scan Method: Error Surface: Principal Plan 8< PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North + Casing -~~- Survey Program for Definitive Weilpatli Date: 4/1712004 Validated: No Planned From To Survey ft ft Version: 3 Toolcode Tool Name MWD + IFR + Multi Station -- Planned: MPI-19 wp06 V92 MWD+IFR+MS Casing Points -~_.- Summary 94.91 94.95 94.85 22.04 236.61 38.46 MPtlPad MPI-04 MPI-04 V5 1927.16 1925.00 84.72 46.22 38.50 M Pt I Pad MPI-04 MPI-04A V5 1927.16 1925.00 84.72 46.22 38.50 M Pt I Pad MPI-04 MPI·04AL 1 V2 1927.16 1925.00 84.72 46.22 38.50 M Pt I Pad MPI·04 MPI-04APB1 V1 1927.16 1925.00 84.72 46.22 38.50 MPtlPad MPI·04 MPI-04PB1 V3 1927.16 1925.00 84.72 46.22 38.50 M pt I Pad MPI-05 MPI·05 Vi 1375.00 208.81 22.59 186.22 MPtlPad MPI-07 MPI-07 V1 1225.00 355.45 26.06 329.39 MPtlPad MPI-09 MPI-09 V12 1124.91 1100.00 167.14 19.01 148.13 M Pt I Pad MPI-10 MPI·10V8 812.28 800.00 139.23 12.03 127.20 127.04 84.86 M P I Pad MPI-15 MPI·15L 1 V2 876.37 875.00 99.57 14.50 85.08 M PI! Pad MPI-15 MPI·15PB1 V5 876.37 875.00 99.57 14.76 84.82 M PI! Pad Plan MPI-16 MPI·16 V4 Plan: MPI-16 651.30 650.00 88.86 11.96 76.90 M PtI Pad Plan MPI-17 Thor Plan MPI-17 L 1 VO Plan 575.14 575.00 59.76 10.62 49.15 M Pt I Pad Plan MPI-17 Thor Plan MPI-17 L2 VO Plan 575.00 59.76 10.62 49.15 M Pt I Pad Plan MPI-17 Thor Plan MPI-17 V5 Plan: M 575.00 59.76 10.92 48.84 M Pt I Pad Plan MP!-19 MPI·19L1 VO Plan: MPI 7175.00 7175.00 0.00 0.00 0.00 M PI I Pad Plan MPRINK Plan MPI-LlNK VO Plan: 451.35 450.00 122.20 9.49 112.71 M Pt I Pad Plan MPI-Valhalla Plan MPI-Valhalla VO P 817.81 800.00 327.37 16.53 310.84 MPtJPad MPJ-01 MPJ·01 V3 8790.75 4250.00 910.17 172.14 738.03 M PJ Pad MPJ-01 MPJ·01A V2 9709.07 5050.00 437.51 217.90 219.61 M PI J Pad MPJ-01 MPJ-01AL 1 V6 9705.28 5050.00 442.47 217.33 225.14 MPtJPad MPJ-03 MPJ-03 Vi 5223.16 4500.00 611.37 145.43 465.94 M Pt J Pad MPJ-06 MPJ-06 Vi 9038.62 4650.00 556.66 208.71 347.95 M Pt J Pad MPJ-08A MPJ-08A V7 9462.67 4900.00 332.72 173.73 158.98 M PJ Pad MPJ-08 MPJ-08 Vi 9549.90 5000.00 348.43 196.23 152.20 M PI J Pad MPJ-09 MPJ-09 Vi 8970.16 4425.00 1012.59 164.02 848.57 M PI J Pad MPJ-09 MPJ·09A V2 8974.43 4450.00 1013.82 165.51 848.30 M Pt J Pad MPJ-09 MPJ-09A with IIFR temp 8966.65 4425.00 1011.71 134.41 877.30 M Pt J Pad MPJ-11 MPJ-11 V1 M PI J Pad MPJ-15 MPJ-15 V5 M PtJ Pad MPJ·16 MPJ-16 V1 9715.88 4250.00 990.26 118.61 871.65 M Pt J Pad MPJ-18 MPJ-18 V2 M Pt J Pad MPJ-19A MPJ-19A V1 M Pt J Pad MPJ-19 MPJ-19 Vi -~~- Halliburton Company Anticollision Report Site: M Pi I Pad Well: MPI-13 Wellpath: MPI-13 V6 Rule Assigued: Major Risk Inter-Site Error: 0.00 ft Pass Pass 1925.83 1903.90 2075.00 1950.91 3.23 3.98 285.69 105.69 1011.51 36.25 975.26 Pass 1943.41 1921.16 2100.00 1968.71 3.24 4.10 285.58 105.58 1029.17 36.59 992.58 Pass 1960.57 1938.01 2125.00 1986.09 3.25 4.22 285.46 1 05.46 1047.22 36.92 1010.30 Pass 1990.20 1967.09 2150.00 2003.04 3.26 4.35 285.40 101.92 1065.63 37.42 1028.22 Pass 2057.12 2032.89 2175.00 2019.54 3.26 4.50 285.51 87.58 1083.86 38.30 1045.56 Pass 2129.19 2103.80 2200.00 2035.57 3.25 4.65 285.63 71.75 1101.66 39.23 1062.44 Pass Pass Pass Pass 206.80 206.80 200.00 200.00 0.71 0.36 272.07 272.07 9.625 59.97 5.56 54.41 Pass 231.80 231.80 225.00 225.00 0.83 0.39 271.94 271.94 9.625 59.94 6.23 53.71 Pass 256.80 256.80 250.00 250.00 0.94 0.41 271.79 271.79 9.625 59.91 6.91 53.00 Pass 281.80 281.80 275.00 275.00 1.06 0.44 271.62 271.62 9.625 59.87 7.59 52.28 306.79 306.79 300.00 300.00 1.15 0.46 271.44 91.44 9.625 59.81 8.16 51.66 Pass 331.78 331.78 325.00 325.00 1.15 0.47 271.33 91.33 9.625 59.75 8.43 51.32 Pass 356.78 356.77 350.00 349.99 1.15 0.47 271.34 91.34 9.625 59.67 8.70 50.97 Pass 381.77 381.76 375.00 374.99 1.15 0.48 271.47 91.47 9.625 59.57 8.97 50.60 Pass 406.75 406.74 400.00 399.99 1.13 0.49 271.71 91.71 9.625 59.46 9.21 50.26 Pass 431.74 431.71 425.00 424.98 1.07 0.50 272.07 92.07 9.625 59.35 9.32 50.02 Pass 456.72 456.67 450.00 449.98 1.02 0.52 272.56 92.56 9.625 59.22 9.44 49.78 Pass 481.69 481.62 475.00 474.98 0.96 0.53 273.17 93.17 9.625 59.08 49.52 Pass 506.65 506.55 500.00 499.96 0.92 0.55 273.82 93.82 9.625 58.75 9.73 49.02 Pass 531.60 531.45 525.00 524.94 0.91 0.56 274.52 94.52 9.625 58.15 10.00 48.15 Pass 556.53 556.32 550.00 549.91 0.90 0.58 275.30 95.30 9.625 57.28 10.28 47.01 Pass 581.44 581.16 575.00 574.85 0.90 0.60 276.18 96.18 9.625 56.18 10.55 45.63 Pass 606.33 605.97 600.00 599.79 0.90 0.61 277.25 97.25 9.625 54.96 10.88 44.08 Pass 631.20 630.73 625.00 624.71 0.95 0.63 278.53 98.53 9.625 53.63 11.32 42.31 Pass 656.05 655.44 650.00 649.61 1.00 0.65 280.05 100.05 9.625 52.21 11.77 40.44 Pass 680.87 680.11 675.00 674.51 1.04 0.68 281.82 101.82 9.625 50.74 12.22 38.52 Pass 705.66 699.39 1.10 103.87 49.26 Pass 779.86 0.77 292.13 112.13 9.625 30.62 Pass 804.53 802.60 800.00 798.78 1.43 0.79 295.79 115.79 9.625 43.61 14.90 28.71 Pass 829.21 826.97 825.00 823.58 1.53 0.82 299.91 119.91 9.625 42.32 15.48 26.84 Pass 853.87 851.30 850.00 848.35 1.63 0.84 304.44 124.44 9.625 41.12 16.07 25.05 Pass 878.51 875.58 875.00 873.07 1.73 0.87 309.24 129.24 9.625 39.92 16.65 23.27 Pass 903.12 899.83 900.00 897.74 1.83 0.90 314.35 134.35 9.625 38.73 17.22 21.51 Pass 927.70 924.03 925.00 922.35 1.94 0.93 319.83 139.83 9.625 37.59 17.81 19.78 Pass I Company: Field: Reference Site: Reference Well: Reference Wellpath: Summary < Site M pt J Pad M pt J Pad M pt J Pad M pt J Pad M pt J Pad M pt J Pad M pt J Pad M pt J Pad M Pt J Pad M Pt J Pad M Pt J Pad M Pt J Pad M Pt J Pad M Pt J Pad M Pt J Pad BP Amoco Milne Point M pt I Pad Plan MPI-19 MPI-19 Offset Well path Well MPJ-22 Plan MPJ-14 Plan MPJ-14 Plan MPJ-25 old Plan MPJ-25 old Plan MPJ-25 old Plan MPJ-25 old Plan MPJ-25 Plan MPJ-25 Plan MPJ-26 Plan MPJ-26 Plan MPJ-26 Plan MPJ-26 Plan MPJ-Cipher Plan MPJ-Dozer . BP Anticollision Report . Date: 5/19/2004 2 Time: 17:32:43 Page: Co-ordinate(NE) Reference: Well: Plan MPI-19. True North Vertical (TVD) Reference: 69.3 RKB(34.3 + 35) 69.3 Db: Oracle > Reference Offset Ctr-Ctr No-Go Allowable Well path MD MD Distance Area Deviation Warning ft ft ft ft ft MPJ-22 V4 7292.26 4075.00 901.72 111.23 790.49 Pass: Major Risk Plan MPJ-14 V15 Plan: 9719.38 5175.00 1003.02 125.78 877.24 Pass: Major Risk Plan MPJ-14L 1 V5 Plan: 9719.38 5175.00 1003.02 125.78 877.24 Pass: Major Risk Plan MPJ-25 KlO Plug 0 8539.28 4475.00 284.33 0.00 284.32 Pass: NOERRORS Plan MPJ-25 option VO 8689.88 4550.00 322.33 0.00 322.33 Pass: NOERRORS Plan MPJ-25 VO Plan: M 8629.88 4475.00 259.58 0.00 259.58 Pass: NOERRORS Plan MPJ-25PB1 VO Plan 8672.48 4600.00 199.97 0.00 199.97 Pass: NOERRORS Plan MPJ-25 PB1 VO Pia 8778.17 4400.00 236.85 154.48 82.36 Pass: Major Risk Plan MPJ-25 VO Plan: M 8737.00 4275.00 284.86 112.51 172.35 Pass: Major Risk Plan MPJ-26 V3 Plan: M 6979.70 4075.00 1014.11 120.67 893.45 Pass: Major Risk Plan MPJ-26L 1 VO Plan: 6979.70 4075.00 1014.11 120.52 893.60 Pass: Major Risk Plan MPJ-26L2 V1 Plan: 6979.70 4075.00 1014.11 120.52 893.60 Pass: Major Risk RIG MPJ-26 V2 6974.48 4050.00 1016.98 114.66 902.32 Pass: Major Risk Plan MPJ-Cipher VO Pia Out of range Plan MPJ-Dozer VO Plan 8219.12 7175.00 2.95 0.00 2.95 Pass: NO ERRORS ! 149 00 W 149 J6 00 W ¡ ·1 49 34 00 '';, MPU 1-19 Proposed o Produ 2041350 7/22/2004 N l · q MPU 1-19 Proposed 08 Producer pre # 2041350 -..J o SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 106 "Mastercard Check" DATEO'7 -7D-Oy 1$ {()Q,l!)()--' PAY TO THE Â <-",\;'" /I (1 ORDER OF..r (....../'--~ C. -'" (_ ñ_~ ~ 'j \ ~~! L7 r ) -(¿ uY"'Qr~rl CYvV\.d" (Q/vtt,~ First National arik Alaska Anchorage, AK 99501 ME~;(Yì PI"· \ C\ \ l,,- \ .'- DOLLARS C~~ {-;;~/'-- / ~/(..) .. . I: ¡ 25 2000bOI:£1£1 ¡a....lb 2 27..1 ¡ Sba..u- 0 ¡Ob - . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# {" Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dumber last two (2) digits are between 60-69) .?7 17 u.... 7- /<{' LDt.! - 13> Exploration Stratigraphic ~'CLVE" Tbe permit is for a Dew weJlbore segment of existing weD . Permit No, API No. Production.sbould continue to be reported as a function ·of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), aU records, data and logs acquired for tbe pilot bole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). Pll.-OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fun compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:JCeption. (Company Name) assumes tbe liability of any protest to the spacing . exception tbat may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample hiter:vals tbrough target zones. o o _ Well bore seg Annular Disposal On Program ~DEV On/Off Shore j 1328 Unit 9 _Well Name: MILNE E'LUNJT~B 1-1 DEV / PEN~ GeoArea 890 Entire welUn AOL 025906 Schradßr SIYff Oil i='oo! (525HO). govßrned by CO 4Z7 CO i!,T'- does nQtspecify a miniml!m distanC!:! Jo Qffsetwell~. Glo$esJ approaçb withJI1 OB $al1dj~ 450'Jo J-01AL 1 CO <IT'- ~p~çi{ie.s~goyernmentaJ Qtr-Qtr:Qtr ~eçtjo~n; propo$ed wellconforrns Jo thi$ requiJell)e~nt. ~ Class/Type Yes Y~s ~Y~s Y~s Yes Yßs Yßs Y~s Yßs ~Yßs Yes Yes NA NA ~NA~ ~NA NA Initial 525140 MILNE POINT, SCHRADER BLFF OIL Company BP EXPLORATION (ALASKA) INC p~(rnit fee attach~ Field & Pool MiJnePo[nt _v~~ I WeJ OPßI ~Opß(ator P~rmitc~é P~rmit can be lSSl!ed without - frQm exjsJiog pa~d d r[lIec! WßI :147~. t02(b)(3) Interme.diate~ œmßotpJanlled a~bO\le aJI ~hYdroc.arb~oll~. Slotted Jiller ~completion plallned.~ well(s) J No œseJve~pjtplanoe~d, All wa~te to~Glass Rig js e.q!Jippe.d~with $tßelpjts. G)'rQs~ availablß ~and Ijkßly. Expßcted BHF> 8.5 EMW. ~ F>lan~nßd m!Jd weight~ 9.0 : 9.6 ppg. BOi=' te$tilltßIYalnotmQre th<lo 14 days reçommel1dßd. ~ CalcuJated MASF' t 4ß7 psi.~ PI<lo n~ed BOP Jest pr~ss~ure~ 3000 psJ . MPI pad is 110t desi~Oated fO( H2S~.Mud ~shQuJd RrecJudß aoy~ H2S~ on the rjg. Rig ha~s ~sel1so(sand alarms. Yes NA Yßs No~ No Yßs Yes NA Yes Y~s YßS Yes Yes Yßs Y~s No~ NA C9mmßots)~ (FQr QnJy) AJI wølJs~ within J l4~mile~are.aßf reyißW jdøotlfißd (For servjœ ~well on I)') PJe-produçec! injßçtQr; duration~of prß-:Produc.tionIßss thal13 months (FQrsßIYice WßI ~AGMP~ F'indjngof ""M~;~·~ C~onductor string I S~urfac~casiog pr ~Lßas~e ~number ~apRrORriate ~U~nlque welln~amß~and Ol!mb~er Well Joc<lt~d lna~ define~d pool ~ "'~I' Joc<lt~d proper dlstance~ from driJIing unitb~oundary~ Jocat~d proper distance from Qther wßlJs ~ ~ ~ ~ ~ ~ cientaçrßage~aYaílable [ndJiUiog unjt ~ yiatßd, js~ weJlbore platiocJuded ~ ~ ~ :ator onl)' affectßd party ~ bas~appropr[ateJ¿ond lnJQrce ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ In be iSSl!ed wi1hout conselVation Qrder ~ ~ ac!mioistrativeapprJ:>vaJ ~ ~ re 15-day wait strataauthorlzed by Injectioo Ord~r # (PuUO# in v", ,~v,~v"iOcy~h~as bee~n j~s!Jed~ for~ this p(olect M aq~uife.r~ eXßmpted 40 cm Jrayeling cyJilldeJ plotiocJu~ded pro~imity- anSllysis pe.r(orme~d knowl1 USQWs ~CMT~ vol adequ~ate~ to circ~tate on ~cOnd~uctor~ & surt csg ~CMT \101 ad~qu~ate~ to tie-in iQng ~string to surf csg~ ~CMT Wi!! coveLaJlkoownprod!Jctiye bQri¡Z:Ql1s C~asing designs ac!equaJe for CoT, B~&permaf(ost ~AdequSlte ~tankage~ OJ re~seIYe pit J(are-drill~ bas~a to-403 fQr abandQn~ment beßIl <Ipprovßd AdequSlte ~weUbore. Separ<ltjo~n ~propo~ed ~ ~ ~ ~ ~ ~ ~ _ J(djvøcter requiJed. dQes iLmeet œguJatioos~ _ ~ _Drilliog fJuid~ prQgram sc.hßmatic~& equip Jistadequ<lte ~(put psig incommßots) ChOkemanifQld cQll)pJie~ w/API RF>-53 (May 84) Work will occ_ur withoutoperatjon ~shutdown_ BOPEs,~dJ:) Jhey meßt œguJation _BOPEwe_ss ratiog appropriate; test to 2 3 4 5 6 7 8 9 o 11 12 13 14 15 16 17 18 19 20 121 22 23 24 25 26 27 28 29 30 31 PTD#: 2041350 Administration Date Appr SFD 7/21/2004 Engineering Appr Date TEM 7/26/2004 .~ 11- V ~h 32 33 34 v - Per ~SkipCoYl1er, _BP 0_n7l22{0'k NQ 1:-12$ koow!1 jn $c~hrader_BMfJeservolrs atJ- OJ J-Padsy Expectec! fese.lVoir pre_SSl!re i.s ~8,5_ppg EMW; wm~be ~drilled wjth 9.0 - 9A ppg mud. l-IydJates_h~aYe be_en ßocouoterßd on IF>adwells~betweßn HO_O&2300' TYD. Xes Y~s NA ~NA NA - J~ presence of 1:-12S gas_ prOþablß Meçhan[calC90dit[oo of wells wiJhin AOR yerifiec! (for_serviC!:! well Ql1ly) P~rmit c_an be lSSl!ed w/Q hyd(ogen sulfide measures ~D_ata_PJesßoted on Rote~ntial oveJPres~s!Jr~ ~zooe$ ~ _ Selsmic_analysJs of shaJlow gasz_ooes ~ ~ _ ~Sßabed _coodjtioo SUlVey _Of Qff-shore) Conta_ct l1am_elp\1Ol1efQrweels.ly progresHeRorts [e)(pIQratoryonIYl 35 36 Date 37 7/22/2004 38 139 Geology Appr SFD Date ~~ý ~"e' Date Engineering Commissioner DateilPl'~ 1·V t:et'f' e'awlJwt e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 15 10:09:58 2004 Reel Header Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments. ............... .STS LIS Writing Library. . ~Ðtf- 135 ¢ll), Cj uJuj Scientific Technical Services Tape Header Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin........... ....... .STS Tape Name......... .... ...UNKNOWN Continuation Number.. ... .01 Previous Tape Name... ... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-19 500292321800 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003258923 T. MCGUIRE D. GREEN MWD RUN 2 MW0003258923 T. MCGUIRE D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003258923 R. FRENCH D. GREEN MWD RUN 6 MW0003258923 R. FRENCH D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 T13 RIO 2319 3521 69.10 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS MWD RUN 3 MW0003258923 R. FRENCH D. GREEN MWD RUN 7 MW0003258923 R. FRENCH D. GREEN 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 2999.0 7428.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-19 L1 EXITS FROM THIS WELLBORE AT 7192'MD/4015'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3, 4, 6, 7 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4, 6, 7 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 9/17/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 4, 6, 7 REPRESENT WELL MPI-19 WITH API#: 50-029-23218-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9720'MD/4088'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.......... ...STSLIB.001 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation.... ...04/11/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY 1 and clipped curves; all bit runs merged. .5000 PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 67.0 112.5 2967.0 2967.0 2967.0 2967.0 2967.0 STOP DEPTH 9655.0 9719.5 9662.0 9662.0 9662.0 9662.0 9662.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 67.0 254.0 MWD 2 254.0 3010.0 MWD 3 3010.0 7438.0 MWD 4 7438.0 7488.0 MWD 6 7488.5 7640.0 MWD 7 7640.0 9719.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.... ........... ...0 Data Specification Block Type.....O Logging Direction...... ......... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .1IN Max frames per record........ .....Undefined Absent value........ ........ ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR Mean 4893.25 210.355 68.3009 10.7999 11.9818 13.8676 26.5459 1.11681 Nsam 19306 19215 19177 13391 13391 13391 13391 13391 Min 67 0.43 19.12 0.22 0.07 0.22 0.32 0.0853 Max 9719.5 2059.13 131.85 1648.4 2000 2000 2000 44.4945 MWD MWD MWD MWD MWD MWD MWD First Reading For Entire File........ ..67 Last Reading For Entire File.... ...... .9719.5 First Reading 67 112.5 67 2967 2967 2967 2967 2967 Last Reading 9719.5 9719.5 9655 9662 9662 9662 9662 9662 . File Trailer Service name. ........... .STSLIB.001 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation..... ..04/11/15 Maximum Physical Record..65535 File Type.............. ..LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name... ........ ..STSLIB.002 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type.. .... ........ ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 67.0 112.5 STOP DEPTH 208.0 254.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 28 -AUG- 04 Insite 66.37 Memory 254.0 112.0 254.0 .0 .7 TOOL NUMBER 120557 13 .500 112.0 SPUD MUD 9.15 125.0 8.5 300 10.0 . MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 . 74.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...........Feet Data Reference Point............. . Undefined Frame Spacing.... ...... ........ ...60 .1IN Max frames per record. ........... . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67 254 160.5 375 67 254 ROP MWD010 FT/H 47.48 166.41 130.575 284 112.5 254 GR MWD010 API 21. 47 87.47 44.0474 283 67 208 First Reading For Entire File...... ....67 Last Reading For Entire File.... ...... .254 File Trailer Service name..... ........STSLIB.002 Service Sub Level Name... Version Number... ..... ...1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record. .65535 File Type............. ...LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.002 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 208.5 254.5 STOP DEPTH 2965.0 3010.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB!G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units. ........ ..Feet Data Reference Point............. . Undefined Frame Spacing. .................. ..60 .1IN 29 -AUG- 04 Insite 66.37 Memory 3010.0 254.0 3010.0 .9 65.1 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.30 148.0 7.5 300 7.6 .000 .000 .000 .000 .0 71.6 .0 .0 . Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 208.5 3010 1609.25 5604 208.5 3010 ROP MWD020 FT/H 6.62 1041. 25 179.787 5512 254.5 3010 GR MWD020 API 19.12 118.17 66.3304 5514 208.5 2965 First Reading For Entire File... ...... .208.5 Last Reading For Entire File..... ..... .3010 File Trailer Service name........ .., ..STSLIB.003 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record. .65535 File Type......... .......LO Next File Name.. ....... ..STSLIB.004 Physical EOF File Header Service name........ ... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type.... ..... ...... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2965.5 2967.0 2967.0 2967.0 2967.0 2967.0 3010.5 STOP DEPTH 7401. 0 7393.5 7393.5 7393.5 7393.5 7393.5 7438.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 01-SEP-04 Insite . DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units....... ... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record..... .... ....Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 66.37 Memory 7438.0 3010.0 7438.0 . 65.2 79.3 TOOL NUMBER 124724 127479 9.875 2999.0 LSND 9.20 52.0 8.0 300 6.7 7.000 4.610 8.000 5.000 68.0 106.7 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 · .st Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2965.5 7438 5201.75 8946 2965.5 7438 ROP MWD030 FT/H 0.43 850.17 244.25 8856 3010.5 7438 GR MWD030 API 20 127.83 68.6576 8872 2965.5 7401 RPX MWD030 OHMM 0.22 215.42 10.2383 8854 2967 7393.5 RPS MWD030 OHMM 0.07 2000 11.6906 8854 2967 7393.5 RPM MWD030 OHMM 0.26 2000 12.9857 8854 2967 7393.5 RPD MWD030 OHMM 0.32 2000 21. 4387 8854 2967 7393.5 FET MWD030 HOUR 0.0853 34.6967 0.784938 8854 2967 7393.5 First Reading For Entire File......... .2965.5 Last Reading For Entire File... ....... .7438 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type......... .......LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.. .......... .STSLIB.005 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type... ............ .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7394.0 7394.0 7394.0 7394.0 7394.0 7401.5 7438.5 STOP DEPTH 7488.0 7488.0 7488.0 7488.0 7488.0 7488.0 7488.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 03-SEP-04 Insite 66.37 Memory 7488.0 7438.0 7488.0 . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ......... ....0 Data Specification Block Type.....O Logging Direction...... ...........Down Optical log depth units.......... .Feet Data Reference Point...... ....... .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 83.1 87.6 . TOOL NUMBER 62456 130910 6.750 7428.0 VersaPro 9.05 84.0 .0 185788 .0 .000 .000 .000 .000 .0 96.6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7394 7488 7441 189 7394 7488 ROP MWD040 FT/H 22.09 545.77 269.912 100 7438.5 7488 GR MWD040 API 37.83 113.34 78.3956 174 7401.5 7488 RPX MWD040 OHMM 2.87 1648.4 18.1698 189 7394 7488 RPS MWD040 OHMM 3.08 1648.47 21.2083 189 7394 7488 . . 7394 RPM MWD040 OHMM 0.22 2000 83.1884 189 7488 RPD MWD040 OHMM 1.9 2000 581.915 189 7394 7488 FET MWD040 HOUR 0.2625 44.4945 21. 4423 189 7394 7488 First Reading For Entire File......... .7394 Last Reading For Entire File.......... .7488 File Trailer Service name. ......... ...STSLIB.005 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type................ LO Next File Name.. .........STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type............. ...LO Previous File Name... ....STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD ROP GR RPX RPM FET RPS $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 STOP DEPTH 7640.0 7640.0 7640.0 7640.0 7640.0 7640.0 7640.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 04-SEP-04 Insite 66.37 Memory 7640.0 7488.0 7640.0 83.3 95.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 . $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point. ............ . Undefined Frame Spacing..... .......... ......60 .1IN Max frames per record. ........... . Undefined Absent value........ ............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.750 7428.0 VersaPro 9.20 80.0 .0 197209 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD060 FT/H MWD060 API MWD060 OHMM MWD060 OHMM MWD060 OHMM MWD060 OHMM MWD060 HOUR Mean 7564.25 149.534 87.3682 5.53178 5.62161 5.67112 5.94076 0.822592 Min 7488.5 0.5 60.42 3.03 3.29 3.41 3.61 0.388 Max 7640 274.55 124.52 9.47 9.52 9.43 9.93 15.1997 First Reading For Entire File......... .7488.5 Last Reading For Entire File....... .,. .7640 Nsam 304 304 304 304 304 304 304 304 . .0 113.5 .0 .0 First Reading 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 Last Reading 7640 7640 7640 7640 7640 7640 7640 7640 . File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/15 Maximum Physical Record..65535 File Type............... .LO Next File Name........ ...STSLIB.007 Physical EOF File Header Service name.... .........STSLIB.007 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/11/15 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 7 . header data for each bit run in separate files. 7 .5000 START DEPTH 7585.0 7585.0 7585.0 7585.0 7585.0 7640.5 7640.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9662.0 9662.0 9662.0 9662.0 9662.0 9655.0 9719.5 05-SEP-04 Insite 66.37 Memory 972 0 . 0 7640.0 9720.0 82.5 95.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 6.750 7428.0 . MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ....... ....0 Data Specification Block Type... ..0 Logging Direction...... ........ ...Down Optical log depth units......... ..Feet Data Reference Point..... ....... ..Undefined Frame Spacing. .................. ..60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O VersaPro 9.15 73.0 .0 196627 .0 . .000 .000 .000 .000 .0 113.5 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7585 9719.5 8652.25 4270 7585 9719.5 ROP MWD070 FT/H 4.5 2059.13 187.156 4159 7640.5 9719.5 GR MWD070 API 39.77 131.85 70.0409 4030 7640.5 9655 RPX MWD070 OHMM 3.14 64.11 11.9467 4154 7585 9662 RPS MWD070 OHMM 3.23 123.06 12.5241 4154 7585 9662 RPM MWD070 OHMM 3.33 227.11 13.0261 4154 7585 9662 RPD MWD070 OHMM 3.35 96.2 13.1808 4154 7585 9662 FET MWD070 HOUR 0.3307 14.0002 1.25407 4154 7585 9662 First Reading For Entire File..... .... .7585 Last Reading For Entire File........ ...9719.5 File Trailer Service name......... ....STSLIB.007 Service Sub Level Name. . . Version Number. ......... .1.0.0 Date of Generation...... .04/11/15 ~ .. . Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.008 . Physical EOF Tape Trailer Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ............ ...UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments..... ........... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments........... ..... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 15 14:15:49 2004 Reel Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ............. .UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments.......... ..... ..STS LIS Writing Library. . 201-- /35 ,.- Of U¡J 11- } J.. Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. .... .......... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-19 PB1 500292321870 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003258923 T. MCGUIRE D. GREEN MWD RUN 2 MW0003258923 T. MCGUIRE D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003258923 R. FRENCH D. GREEN MWD RUN 5 MW0003258923 R. FRENCH D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 T13 R10 2319 3521 MSL 0) 69.10 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS MWD RUN 3 MW0003258923 R. FRENCH D. GREEN 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 2999.0 7428.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-19 PB2 EXITS FROM THIS WELLBORE AT 7488'MD/4083'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 & 5 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 9/17/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 5 REPRESENT WELL MPI-19 PB1 WITH API#: 50-029-23218-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7799'MD/4104'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 67.0 112.5 2967.0 2967.0 2967.0 2967.0 2967.0 STOP DEPTH 7734.0 7799.0 7741. 0 7741.0 7741.0 7741.0 7741.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 67.0 254.0 3010.0 7438.0 7639.0 MERGE BASE 254.0 3010.0 7438.0 7639.0 7799.0 # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point........... ...Undefined Frame Spacing. ................... .60 .1IN Max frames per record... ......... .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 67 0.43 19.12 0.22 0.07 0.22 0.32 0.0853 Max 7799 1041. 25 129.25 1648.4 2000 2000 2000 44.4945 Mean 3933 217.272 68.5645 10.0649 11. 4744 13.9047 31.6207 1.28763 Nsam 15465 15374 15335 9549 9549 9549 9549 9549 First Reading For Entire File......... .67 Last Reading For Entire File......... ..7799 First Reading 67 112.5 67 2967 2967 2967 2967 2967 Last Reading 7799 7799 7734 7741 7741 7741 7741 7741 . File Trailer Service name...... .......STSLIB.001 Service Sub Level Name. . . Version Number.. ....... ..1.0.0 Date of Generation... ....04/11/15 Maximum Physical Record. .65535 File Type......... ..... ..LO Next File Name...... .....STSLIB.002 Physical EOF File Header Service name........... ..STSLIB.002 Service Sub Level Name. . . Version Number.. ....... ..1.0.0 Date of Generation.. .....04/11/15 Maximum Physical Record. .65535 File Type. ...... ........ .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 67.0 112.5 STOP DEPTH 208.0 254.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 28-AUG-04 Insite 66.37 Memory 254.0 112.0 254.0 .0 .7 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.15 125.0 8.5 300 10.0 .000 .0 · MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 7. .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction..... ........ ....Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing......... ........ ....60 .1IN Max frames per record............ . Undefined Absent value.... . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67 254 160.5 375 67 254 ROP MWD010 FT/H 47.48 166.41 130.575 284 112.5 254 GR MWD010 API 21. 47 87.47 44.0474 283 67 208 First Reading For Entire File....... ...67 Last Reading For Entire File... ........254 File Trailer Service name....... ......STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type........... .....LO Next File Name...... .....STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation... ....04/11/15 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 208.5 254.5 STOP DEPTH 2965.0 3010.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .................0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point.... ........ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined 29 -AUG- 04 Insite 66.37 Memory 3010.0 254.0 3010.0 .9 65.1 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.30 148.0 7.5 300 7.6 .000 .000 .000 .000 .0 71.6 .0 .0 . Absent value.. ................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 208.5 3010 1609.25 5604 208.5 3010 ROP MWD020 FT/H 6.62 1041. 25 179.787 5512 254.5 3010 GR MWD020 API 19.12 118.17 66.3304 5514 208.5 2965 First Reading For Entire File.. ....... .208.5 Last Reading For Entire File.......... .3010 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type......... .......LO Next File Name....... ....STSLIB.004 Physical EOF File Header Service name..... ...... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/15 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPD RPX RPM ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2965.5 2967.0 2967.0 2967.0 2967.0 2967.0 3010.5 STOP DEPTH 7401.0 7393.5 7393.5 7393.5 7393.5 7393.5 7438.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 01-SEP-04 Insite 66.37 . DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ........ ..0 Data Specification Block Type.....O Logging Direction.. .... ...........Down Optical log depth units.......... .Feet Data Reference Point.... ....... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record... ........ ..Undefined Absent value.......... .......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Memory 7438.0 3010.0 7438.0 65.2 79.3 TOOL NUMBER 124724 127479 9.875 2999.0 LSND 9.20 52.0 8.0 300 6.7 7.000 4.610 8.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 . 68.0 106.7 68.0 68.0 First Last · _ding Name Service Unit Min Max Mean Nsam Reading DEPT FT 2965.5 7438 5201.75 8946 2965.5 7438 ROP MWD030 FT/H 0.43 850.17 244.25 8856 3010.5 7438 GR MWD030 API 20 127.83 68.6576 8872 2965.5 7401 RPX MWD030 OHMM 0.22 215.42 10.2383 8854 2967 7393.5 RPS MWD030 OHMM 0.07 2000 11.6906 8854 2967 7393.5 RPM MWD030 OHMM 0.26 2000 12.9857 8854 2967 7393.5 RPD MWD030 OHMM 0.32 2000 21.4387 8854 2967 7393.5 FET MWD030 HOUR 0.0853 34.6967 0.784938 8854 2967 7393.5 First Reading For Entire File......... .2965.5 Last Reading For Entire File.......... .7438 File Trailer Service name.......... ...STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/11/15 Maximum Physical Record. .65535 File Type........ ........LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.. .......... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/11/15 Maximum Physical Record. .65535 File Type... .... ....... ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7394.0 7394.0 7394.0 7394.0 7394.0 7401.5 7438.5 STOP DEPTH 7590.5 7590.5 7590.5 7590.5 7590.5 7583.5 7639.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 03-SEP-04 Insite 66.37 Memory 7639.0 7438.0 7639.0 83.1 . MAXIMUM ANGLE: 87.6 . # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 7428.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: VersaPro 9.05 84.0 .0 185788 .0 .000 .000 .000 .000 .0 96.6 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ......... ......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point.......... ....Undefined Frame Spacing........... ......... .60 .1IN Max frames per record............ . Undefined Absent value........ .......... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7394 7639 7516.5 491 7394 7639 ROP MWD040 FT/H 12.8 545.77 220.204 402 7438.5 7639 GR MWD040 API 37.83 125.25 90.6512 365 7401.5 7583.5 RPX MWD040 OHMM 2.87 1648.4 10.5735 394 7394 7590.5 RPS MWD040 OHMM 3.08 1648.47 12.0501 394 7394 7590.5 RPM MWD040 OHMM 0.22 2000 41.8188 394 7394 7590.5 RPD MWD040 OHMM FET MWD040 HOUR . 1. 9 2000 0.2292 44.4945 First Reading For Entire File...... ....7394 Last Reading For Entire File.......... .7639 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/15 Maximum Physical Record..65535 File Type. ............. ..LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name.... ....... ..STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.. .....04/11/15 Maximum Physical Record. .65535 File Type......... .......LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 6 281.108 10.4609 394 394 . 7394 7394 7590.5 7590.5 header data for each bit run in separate files. 5 .5000 START DEPTH 7584.0 7591.0 7591. 0 759,1.0 7591. 0 7591.0 7639.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 7734.0 7741. 0 7741. 0 7741. 0 7741.0 7741. 0 7799.0 04-SEP-04 Insite 66.37 Memory 7799.0 7639.0 7799.0 84.2 86.2 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ....... ....0 Data Specification Block Type.....O Logging Direction...... .......... . Down Optical log depth units...........Feet Data Reference Point... ...........Undefined Frame Spacing.................... .60 .1IN Max frames per record.. ...........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.750 7428.0 Versa Pro 9.05 85.0 .0 185788 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD050 FT/H MWD050 API MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 HOUR Max 7799 279.7 129.25 6.28 6.29 6.15 6.14 11. 2064 Min 7584 46.86 63.74 3.29 3.41 3.31 3.37 0.32 First Reading For Entire File........ ..7584 Last Reading For Entire File......... ..7799 Mean 7691. 5 189.621 103.011 4.299 4.36007 4.39957 4.55422 4.06699 Nsam 431 320 301 301 301 301 301 301 . .0 113.5 .0 .0 First Reading 7584 7639.5 7584 7591 7591 7591 7591 7591 Last Reading 7799 7799 7734 7741 7741 7741 7741 7741 . . File Trailer Service name.. ....... ....STSLIB.006 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type............... .LO Next File Name...... .... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ...... ....... ..UNKNOWN Continuation Number......01 Next Tape Name...... ... ..UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.. .......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin.................. .STS Reel Name... ..... ...... ..UNKNOWN Continuation Number......01 Next Reel Name...... .....UNKNOWN Comments............ .....STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ~ . Sperry-Sun Drilling Services LIS Scan Utility . ~oC¡-13S $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 15 14:55:39 2004 -qi) ;¿ C( 1~ Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........ ........UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments............. ....STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. .... .......... . UNKNOWN Continuation Number..... .01 Previous Tape Name.......UNKNOWN Comments.... .... ....... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-19 PB2 500292321871 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15 -NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003258923 T. MCGUIRE D. GREEN MWD RUN 2 MW0003258923 T. MCGUIRE D. GREEN MWD RUN 3 MW0003258923 R. FRENCH D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003258923 R. FRENCH D. GREEN MWD RUN 6 MW0003258923 R. FRENCH D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2319 3521 MSL 0) 69.10 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 2999.0 7428.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-19 EXITS FROM THIS WELLBORE AT 7640'MD/4102'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3, 4, 6 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 & 6 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 9/17/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 4, 6 REPRESENT WELL MPI-19 PB2 WITH API#: 50-029-23218-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8532'MD/4086'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type.... ..... .......LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . START DEPTH 67.0 112.5 2967.0 2967.0 2967.0 2967.0 2967.0 STOP DEPTH 8468.0 8532.5 8475.0 8475.0 8475.0 8475.0 8475.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 6 MERGED MAIN PASS. $ MERGE TOP 67.0 254.0 3010.0 7438.0 7488.5 MERGE BASE 254.0 3010.0 7438.0 7488.0 8532.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing. ................... .60 .1IN Max frames per record.............Undefined Absent value.. ................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 67 0.43 19.12 0.22 0.07 0.22 0.32 0.0853 Max 8532.5 1041. 25 127.83 1648.4 2000 2000 2000 44.4945 Mean 4299.75 211.199 68.8433 10.6547 12.1632 14.1687 29.3053 1.1271 Nsam 16932 16841 16803 11017 11017 11017 11017 11017 First Reading For Entire File......... .67 Last Reading For Entire File........ ...8532.5 First Reading 67 112.5 67 2967 2967 2967 2967 2967 Last Reading 8532.5 8532.5 8468 8475 8475 8475 8475 8475 . File Trailer Service name. ........... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....04/11/15 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name....... ......STSLIB.002 Service Sub Level Name... Version Number.. ....... ..1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record. .65535 File Type......... .......LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 67.0 112.5 STOP DEPTH 208.0 254.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 28-AUG-04 Insite 66.37 Memory 254.0 112.0 254.0 .0 .7 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.15 125.0 8.5 300 10.0 .000 .0 · MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 7. .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... .......... .....0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . .. . . . . . Down Optical log depth units...... .....Feet Data Reference Point... ......... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67 254 160.5 375 67 254 ROP MWD010 FT/H 47.48 166.41 130.575 284 112.5 254 GR MWD010 API 21. 47 87.47 44.0474 283 67 208 First Reading For Entire File... ...... .67 Last Reading For Entire File...........254 File Trailer Service name.. .......... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/11/15 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header Service name..... ....... .STSLIB.003 Service Sub Level Name. . . Version Number..... ......1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record. .65535 File Type.. ..... ........ .LO Previous File Name...... .STSLIB.002 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 . header data for each bit run in separate files. 2 .5000 , START DEPTH 208.5 254.5 STOP DEPTH 2965.0 3010.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction....... ..........Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined 29-AUG-04 Insite 66.37 Memory 3010.0 254.0 3010.0 .9 65.1 TOOL NUMBER 120557 13.500 112.0 SPUD MUD 9.30 148.0 7.5 300 7.6 .000 .000 .000 .000 .0 71.6 .0 .0 . Absent value...................... -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 208.5 3010 1609.25 5604 208.5 3010 ROP MWD020 FT/H 6.62 1041. 25 179.787 5512 254.5 3010 GR MWD020 API 19.12 118.17 66.3304 5514 208.5 2965 First Reading For Entire File..... ." ..208.5 Last Reading For Entire File........ ...3010 File Trailer Service name.... .........STSLIB.003 Service Sub Level Name. . . Version Number.... .......1.0.0 Date of Generation..... ..04/11/15 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name......... ....STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ". ...04/11/15 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPD RPX RPM ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2965.5 2967.0 2967.0 2967.0 2967.0 2967.0 3010.5 STOP DEPTH 7401.0 7393.5 7393.5 7393.5 7393.5 7393.5 7438.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 01-SEP-04 Insite 66.37 . DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction....... ..........Down Optical log depth units. ......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.......... ........... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Memory 7438.0 3010.0 7438.0 65.2 79.3 TOOL NUMBER 124724 127479 9.875 2999.0 LSND 9.20 52.0 8.0 300 6.7 7.000 4.610 8.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 . 68.0 106.7 68.0 68.0 First Last · Aing Name Service Unit Min Max Mean Nsam Reading DEPT FT 2965.5 7438 5201.75 8946 2965.5 7438 ROP MWD030 FT/H 0.43 850.17 244.25 8856 3010.5 7438 GR MWD030 API 20 127.83 68.6576 8872 2965.5 7401 RPX MWD030 OHMM 0.22 215.42 10.2383 8854 2967 7393.5 RPS MWD030 OHMM 0.07 2000 11.6906 8854 2967 7393.5 RPM MWD030 OHMM 0.26 2000 12.9857 8854 2967 7393.5 RPD MWD030 OHMM 0.32 2000 21. 4387 8854 2967 7393.5 FET MWD030 HOUR 0.0853 34.6967 0.784938 8854 2967 7393.5 First Reading For Entire File....... ...2965.5 Last Reading For Entire File.......... .7438 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation. ......04/11/15 Maximum Physical Record..65535 File Type....... .., .... ..LO Next File Name.. ....... ..STSLIB.005 Physical EOF File Header Service name........... ..STSLIB.005 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.......04/11/15 Maximum Physical Record..65535 File Type.. ..... ...... ...LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7394.0 7394.0 7394.0 7394.0 7394.0 7401.5 7438.5 STOP DEPTH 7488.0 7488.0 7488.0 7488.0 7488.0 7488.0 7488.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 03-SEP-04 Insite 66.37 Memory 7488.0 7438.0 7488.0 83.1 . MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ......... .....0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record... ......... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 87.6 . TOOL NUMBER 62456 130910 6.750 7428.0 VersaPro 9.05 84.0 .0 185788 .0 .000 .000 .000 .000 .0 96 .6 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7394 7488 7441 189 7394 7488 ROP MWD040 FT/H 22.09 545.77 269.912 100 7438.5 7488 GR MWD040 API 37.83 113.34 78.3956 174 7401.5 7488 RPX MWD040 OHMM 2.87 1648.4 18.1698 189 7394 7488 RPS MWD040 OHMM 3.08 1648.47 21.2083 189 7394 7488 RPM MWD040 OHMM 0.22 2000 83.1884 189 7394 7488 RPD MWD040 OHMM FET MWD040 HOUR . 1. 9 2000 0.2625 44.4945 581. 915 21. 4423 189 189 First Reading For Entire File... ...... .7394 Last Reading For Entire File......... ..7488 File Trailer Service name........ .... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name......... ....STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/15 Maximum Physical Record..65535 File Type. .... .......... .LO Previous File Name..... ..STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPD RPM RPS RPX GR FET $ 6 . 7394 7394 7488 7488 header data for each bit run in separate files. 6 .5000 START DEPTH 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 8532.5 8475.0 8475.0 8475.0 8475.0 8468.0 8475.0 04-SEP-04 Insite 66.37 Memory 8532.0 7488.0 8532.0 83.3 95.4 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.. ...0 Logging Direction....... ........ ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.750 7428.0 VersaPro 9.20 80.0 .0 197209 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET service Unit FT MWD060 FT/H MWD060 API MWD060 OHMM MWD060 OHMM MWD060 OHMM MWD060 OHMM MWD060 HOUR Min 7488.5 0.5 46.2 2.93 3.09 3.23 3.15 0.388 Max 8532.5 447.84 124.52 1577.31 1868.81 864.02 177.99 15.1997 First Reading For Entire File..... .... .7488.5 Last Reading For Entire File.. .........8532.5 Mean 8010.5 162.117 79.485 11.8027 13.4168 12.8669 11.6797 0.71674 Nsam 2089 2089 1960 1974 1974 1974 1974 1974 . .0 113.5 .0 .0 First Reading 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 7488.5 Last Reading 8532.5 8532.5 8468 8475 8475 8475 8475 8475 . . File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/11/15 Maximum Physical Record. .65535 File Type................ LO Next File Name..... ......STSLIB.007 Physical EOF Tape Trailer Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name......... ...... . UNKNOWN Continuation Number.... ..01 Next Tape Name....... ....UNKNOWN Comments............. ....STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number... ...01 Next Reel Name... ........UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File