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204-136
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: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: $SULO 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 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 N/A 35' 2,999' 42" 468 sx AS Lite, 254 sx Class G If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9,720' 12,199' 757 sx Class G ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD 4,013' 4,052' 7,326' / 4,056' 5,460' TUBING RECORD Uncemented Slotted Liner 4-1/2" SIZE DEPTH SET (MD) 5,456' / 3,468' PACKER SET (MD/TVD) 7,144' / 4,000' 7,187' 7,315' 12.6# 6-3/4" Uncemented Slotted Liner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 204-136 / 320-159 2,319' NSL, 3,521' WEL, SEC. 33, T13N, R10E, UM September 7, 2004 50-029-23218-60-00 September 10, 20MILNE PT UNIT I-19L1 3800 Centerpoint Dr, Suite 1400, Anchorage Alaska 99503 MILNE POINT / SCHRADER BLUFF OIL 69.3' ADL00259067,187' / 4,013' ' / 4,0'551851.0812 6009435.082 GL: 24.8' BF:N/A2,033 NSL, 4,474' WEL, SEC. 28, T13N, R10E, UM 5,260' NSL, 1,475' WEL, SEC. 29, T13N, R10E, UM CEMENTING RECORD 6014494.258 SETTING DEPTH TVD 6017630.014 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' LinerN/A 550863.9417 548532.1319 TOP SETTING DEPTH MD 34' 5,456' BOTTOM 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, HOLE SIZE AMOUNT PULLED 92# 45.5# 112' 33' 7,428' CASING WT. PER FT.GRADE 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" 12.6# 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 10:52 am, May 18, 2020 Suspension Date 4/17/2020 HEW RBDMS HEW 5/21/2020 xG ADL0025517 DSR-5/21/2020 ;ADL0025515 DLB 05/21/2020 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 7,188' 4,014' 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' 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: 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 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 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: 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. 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 22:16:18 -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 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. Tag and pressure test plug (IA and tubing.) t tag Top of Cement at 6,620' w/ Guy P/T tubing and cement to 2,000psi charted minutes w/ Guy Cook w/ AOGCC as witness. 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 3/27/2020 See Schematic See Schematic 4-1/2" 12.6# / L-80 / EZGO-HT 5,460' 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 MILNE PT UNIT I-19L1 MILNE POINT / SCHRADER BLUFF OIL 2,405' 4-1/2" 9,720' 4,088' N/A sporhola@hilcorp.com COMMISSION USE ONLY Authorized Name: N/A PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 3800 Centerpoint Dr, Suite 1400 C.O. 477.05 204-136 Anchorage Alaska 99503 50-029-23218-60-00 Hilcorp Alaska LLC Length Size 4,088' 9,720' 4,088' 112' 112' Tubing Grade: TVD Burst Tubing MD (ft): 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: 12,199'5,012' Tubing Size: 4,045' Perforation Depth MD (ft): 4-1/2" Perforation Depth TVD (ft): 1,041 N/A Authorized Title: 7,255' 7,428' 211' 4,063' & &&&&&& mmmmmmmm sssssss sssssssssssss eeeeeeelllllllllll ededededededed 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 17:19:09 -05'00' Chad Helgeson By Samantha Carlisle at 12:35 pm, Apr 08, 2020 320-159 gls 4/8/20 X DSR-4/8/2020 0025515 X DLB 4/8/2020 ; 0025517 Notify inspector to witness tag and pressure test of plug. Suspended well inspection required within 1 yr per 20 AAC 25.110(e) DLB 10-407 X X Suspend Suspended on Required? Yes No Comm. 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. 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. 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 pressure test of the plug. (2000 psi test) ----> Notify AOGCC inspector to witness tag and _____________________________________________________________________________________ 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 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 4 STATE OF ALASKA RECEIVED •SKA OIL AND GAS CONSERVATION CIDIIISSION REPORT OF SUNDRY WELL OPERATIONS - i MA 0 `` 3 1. Operations Performed: AOCCC ❑ 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 - 136 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 ^ 50. 029 - 23218 - 60 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 & 025517 ``b MPI - 19L1 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 12225' feet Plugs:(measured) None feet true vertical 4045' feet Junk: (measured) None feet Effective depth: measured 12225' feet Packer: (measured) None feet true vertical 4045' 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 7159' 7 -5/8" 33' - 7192' 33' - 4015' 6890 4790 Liner 5012' 4 -1/2" 7187' - 12199' 4013' - 4045' 8430 7500 LEM Tieback 43' 4 -1/2" 7144' - 7187' 4000' - 4013' SCANNED APR 1 9 2013 Perforation Depth: Measured Depth: Slotted 7253' - 12154' feet True Vertical Depth: Slotted 4030' - 4045' 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: 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: tO ❑ 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 N. - Jo; L.k ��° Title: Drilling Technologist / Signature: T „ 1 Phone: 564 -4091 Date: 3/6/13 Form 10-404 Re ed 10/201 R8DMS MAR 06 V l; i c% ; i — ". �, /Submit Original Only 0 ii- 112/13 //� f • • r14 „ e p-raton Sum mary °J epe 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)1IIPI -PAD - LAY MATS AND PREP TO BACK OVER WELL. BACK OVER MPI -19 - WSL / TOOLPUSHER PRESENT. 06:30 - 09:00 2.50 RIGU P r 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.q0 WH 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 • • h America - ALASKA BP Qpera 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 ©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 =r1 IICP = 120 PSI - LD LUBRICATOR PER DSM REPS. 16:00 - 16:45 0.75 KILLW P DECOMP 'RISM,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 GAB ON PAD. 16:45 - 20:00 3.25 KILLW P ' DECOMP R/U TO BULLHEAD WELL VIA WELL KILL MANIFOLD IPtCELLAR. - - 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 2 7/8" TBG AND IA SIMULTANEOUSLY. -BULLHEAD WITH 120 DEGREE 8.5 PPG SEAWATER. - PUMPED 870 BBLS KWF @ 9 BPM. - ICP (BULL HEAD) = 700 PSI. - 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 + • • North America - ALASKA B ' Operation Summary Rep.) . 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 - PUMP DOWN IA @ 9 BPM AND 500 PSI FOR 10 MINS, CHARTED (147 BBLS KWF PUMPED) - TEST TWC FROM ABOVE : 250 PSI LOW & 3500 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 PJ$M TO DRAIN AND NIPPLE DOWN TREE & (.I ll LFInPF_ - NIPPLE DOWN FMC.ADAPTER FLANGE & 2 9/16" , 9 M TREE` - 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 - TEST ANNULAR 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 TEST ACCORDING TO DDI BOPE TESTING SOP. Printed 2/25/2013 10:19:21AM • • North America - ALASKA - BP o ; Operation Summary Report 5 �� 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. CUTA TOTAL 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 • CLOSE ANNULAR AND PRESSURE TEST TO 250 / 3500 PSI AND CHART FOR 5 MINUTES EACH. - PULL TWC AND R/D DSM LUBRICATOR AND 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 PULLT P DECOMP PJSM ON PULLING 2 7/8" TBG HANGER TO FLOOR. - WSL, TOOLPUSHER, FMC REP, RIG CREW IN 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 T+ TBG HANGER. BOLDS PER FMC REP. - WSL VERIFY NO TRAPPED PRESSURE UNDER TBG HANGER. - PULL TBG HANGER OFF SEAT @ 80K 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 { • • Ott z,, � �t� �. h America - ALASKA - BP \ A _ x 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 @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 UD 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 CONTINUA). HOLE FILL WITH 8.5 PPG SEAWATER @' -25 BPH 568 BBLS OF 8:8 PPG SEAWATER LOST IN 24 - HRS 2/12/2013 00:00 - 02:30 2.50 PULL P DECOMP POOH W/ 2 -7/8" EUE 8RD TUBING AND ESP POMP ASSEMBLY CONTINUE 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 • • Uorth America - ALASKA - BP 'NN I‘ � t 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 @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 TQPDRIVE WT. SOW = 60K. LOSS 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 DRAWWORKS.AND 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 OM 2 7/8" TBG FROM DERRICK. • - RIH FROM 6066' MD. TO 6577' MD. - OBTAIN PARAMETERS. PUW = 68K INCLUDING 40K TOP DRIVE WT. $OW = 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 - FILL ANNULUS WITH 77 BBLS KWF PRIOR TO PT 14:30 - 16:00 1.50 EVAL P DECOMPJ 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 -10-45 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 • • North America - ALASKA., ti Op era tion Summary Report v t i t 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 ) _..J'r i t: 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) 16:00 - 18:00 2.00 EVAL P DECOMP PJSM, RD TEST LINES AND CIRC. EQUIPMENT. - BLOW DOWN ALL ASSOCIATED LINES. - POOH WITH 7 -5/8" HES CHAMP PACKER - STAND BACK 2 -7/8" TUBING - MAINTAIN CONTINUOUS HOLE FILL@ -25 ttBPH WITH KWF. 18:00 - 19:00 1.00 EVAL P DECOMP PJSM TO LAY DOWN CHAMP PACKER - L/D 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 PJSMWW /SLICKLINE AND RIG CREW ON RIG UP OF FULL PRESSURE CONTROL AND EQUIPMENT RIG UP SLICKLINE PRESSURE CONTROL - M/U SLICKLINE EQUIPMENT - 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 DFAL 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 • V \' erica - ALASKA - BP Summa 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 @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 ASP SHEAVE IN DERRICK. MOBILIZE CANNON CLAMPS TO RIG FLOOR. R/U TO RUN ESP COMPLETION. 10:00 - 11:30 1.50 RUNCOM P RUNCMP PICK UP BAKER,ESPASSEMBLY. - 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 • • s:. cro 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) 2/14/2013 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 09:00 - 09:30 0.50 WHSUR P WHDTRE MAKE UP FMC 2 7/8" x11 "HANGER - - M/U 2 7/8" EUE LANDING JOINT W/ FOSV TO HANGER 09:30 - 10:00 0.50 WHSUR P WHDTRE PJSM, LANDING 11" TBG HANGER. FMC REP, 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, INSTALL AND 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 WINESSED. Printed 2/25/2013 10:19:21AM • S orth America - ALASKA - BP a s j s Operat 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 ©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 AN© 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 1 rig. DF elev. = 69.10' (Doyon 14) Wellhead; 11" x 11" 5M F M P I -19 /L ` • rig. GL elev. = 24.80' (Doyon 14) r Gen 5, w 2 -7/8" FMC Tbg. 2-7/8" EU 8rd on t &b, 2.5" CIW -H BPV Profile it j Casing tested to 1700 psi from 6572' 0 during 2/13/13 RWO. 20 ", 92 # /ft, H -40 112' 1 ' I Camco 2 -7/8" x1" I "Note" i� KBMM -2 Gas lift mandrel 142' 10 3/4" 45.5 ppf L -80 & K -55 BTC -M j (Drift ID = 10.050, cap. = .0981 bpf) 0 l Collapse / Internal Yield K -55 2090 psi. / 3580 psi. L -80 2480 psi. / 5210 psi. °0' K -55 161' thru 2,879' 10 3/4" Howco Float Shoe 1 2999' A 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 r HES 2 -7/8" XN- Nipple (2.250" id) I 6,512' I 2 -7/8" 6.5 ppf, L -80 8rd eue tbg. Centrilift Pump ( drift id = 2.347" cap = .00592 bpf) 140 - P10 PMSXD I 6,555' I 7 5/8" 29.7 f, L -80, BTC -M casing , - 4. pp g �` Centrilift Gas Separator 6,573` (Drift ID = 6.750 ", cap = 0.0459 bpf) GRSFTX AR Hs - Centrilift Tandem Seal section 6,578` GSD3DB UT /LT SB /SB PFSA MI AM Centrilift Motor (rerated) MSP1 1 6,592` es in 60 HP / 2050 volt / 18 amps. 1 6 WeIlLift MGU Gauge w/6 fin centralizer 1 6,600` r Gauge TVD = 3843' Baker HRD ZXP Liner 7144' I 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 j rim •■ 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. I 7310' / 6 3/4" Hole td @ 9720' Btm HES Type V Float Shoe 9720' 7 -5/8" Weatherford Float Collar 7344' ow •■iii 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 -I 9 02/12/05 MDO ESP RWO Nabors - 4ES 10/17/08 REH ESP RWO/ Install LEM API NO: 50- 029 - 23218 -00 01/09/10 LH ESP RWO - 4ES post lateral FCO 50- 029 - 23218 -60 02/13/13 LH ESP RWO - Doyon 16 BP EXPLORATION (AK) STATE OF ALASKA ALAS~L AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERA ONS REC~IVD .~ 1. Operations Performed: a ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ~~~~~~ ^ Aker 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 204-136 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23218-60-00 7. Property Design ion: 8. Welt Name and Number. ADL 025906& 025517 MPI-19L1 9. Field /Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured ~ 12225' feet true vertical ~ 4045' feet Plugs (measured) None Effective depth: measured 12225' feet Junk (measured) None true vertical 4045' 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 7159' 7-5/8" 7192' 4015' ~ 6890 4790 Liner 5012' 4-1/2" 7187' - 12199' 4013' - 4045' 8430 7500 LEM Tieback 43' 4-1/2" 7144' - 7187' 4000' - 4013' Perforation Depth: Measured Depth: Slotted: 7253' - 12154' ter. ~~~ ~~~ ~ :~ ~(~'~ E~ True Vertical Depth: Slotted: 4030' - 4045' - 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 9,702'. tp, 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 • Well Class after work: ^ Exploratory ®Development ^ Service ort of Well O erations ® Dail Re y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the beat of my knowledge. undry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 N/A Printed Name Terrie Hubble Title Drillin Technolo ist O?j D~ Prepared By Name/Number: t Ph D d a e Signature one 564-4628 Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009' ''vvn~V rGD V i) LUIU e^~ ~ Submit Original Only ,~= s'•/® 2~r/~ U • MPI-19 &MPI-19L1, Well History (Fill Cleanout) Date Summary Operations from 10/05/09 - 11/05/09 (Pre-Rig and N-4ES Ops) Reported Previously (10-404 Dated 11/24/09). 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~ 3,007' MD. RAN 4-1/2" OK-1, SET 1" BK-DGLV IN ST #1 C~3 2,514' MD. PULL PLUG BODY FROM X-NIPPLE ~ 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 Li 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 in hole and performing FCO. Start FCO at 7200, pumping 5bbl geo-vis sweeps and taking 50 ft bites as gel reaches ~ ` ~ nozzle. At 8100', continue clean out. a 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 C~ 7227' start clean out. 12/7/2009 Continue clean out. Clean out to 9702' (ctm up). 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 J WELL S/I ON ARRIVAL. R/U SLICKLINE EQUIPMENT FOR RIG PREP. 1 1/5/2010 MAKE STOPS C~ 7133' SLM FOR 3 HRS, AND 6633' SLM FOR 30 MIN. SET SLIP STOP CATCHER G 2970' SLM. PULL DGLV FROM 2514' MD. POCKET LEFT EMPTY. PULL SLIP STOP CATCHER FROM 2970' SLM. lb5~ SET BPV. WELL S/1 ON DEPART. DSO NOTIFIED. ~r} Page 1 of 1 BP EXPLORATION Page 1 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 Task Code NPT Phase Description of Operations 1/6/2010 01:00 - 07:00 6.00 MOB P PRE RDMO TO MPI-19 BLOW DOWN LINES LOWER DERRICK MOVE PITS & PIPE SHED PREP UNITS TO MOVE FROM E PAD 07:00 - 10:30 3.50 MOB P PRE MOVE FROM MPE PAD TO MPI PAD 10:30 - 14:15 3.75 RIGU P PRE SPOT SUB OVER MPI-19 WELL SPOT PITS & PIPE SHED ALLIGNED TO SUB 14:15 - 16:00 1.75 RIGU P PRE RAISE & SCOPE UP DERRICK =ACCEPT RIG ~ 16:00 HRS= 16:00 - 18:00 2.00 RIGU P PRE CREW CHANGE & HANDOVER PRE TOUR MEETING TO DISCUSS DAYS OPERATIONS 18:00 - 20:00 2.00 RIGU P PRE RIG UP LUBRICATOR PT TO 500 PSI & PULL BPV 20:00 - 20:15 0.25 RIGU P PRE PJSM TO RIG UP TO BULLHEAD & KILL WELL 20:15 - 21:00 0.75 RIGU P 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 21:00 - 22:10 1.17 KILL P 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. 22:10 - 23:40 1.50 KILL P 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 23:40 - 00:00 0.33 KILL P DECOMP PJSM TO INST TWC 1/7/2010 00:00 - 00:45 0.75 WHSUR DECOMP INSTALL TWC PT & CHART TWC ATTEMPT TO TEST FROM BOTTOM CHARTED 50 PSI ~ 3 BPM 3,500 PSI FROM TOP FOR 10 MIN 00:45 - 01:00 0.25 WHSUR DECOMP PJSM TO ND TREE 01:00 - 03:20 2.33 WHSUR DECOMP BLEED VOID IN TREE ND TREE 03:20 - 03:35 0.25 BOPSU DECOMP PJSM TO NU ROPE 03:35 - 05:30 1.92 BOPSU DECOMP PE CALLED AOGCC SPOKE W ITH BOB HE NEEDS 1 HOUR NOTICE TO W ITNESS PT ON BOPE (-FEEDING WELL 20 BPH OF SEA WATER-) 05:30 - 06:00 0.50 BOPSU DECOMP CREW CHANGE OUT PREJOB TO PT BOPE 06:00 - 11:30 5.50 BOPSU DECOMP PT BOPE 250 PSI LOW / 3,500 PSI HIGH 11:30 - 11:45 0.25 BOPSU DECOMP PJSM TO INSTALL DUTCH RISER Printwd• 1/25/2010 12:04:52 PM • • BP EXPLORATION Page 2 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 Task Code NPT Phase Description of Operations 1/7/2010 11:45 - 12:30 0.75 BOPSU DECOMP RU & INSTALL DUTCH RISER 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 I 0.50 ~ PULL 18:00 - 19:15 1.251 PULL 19:15 - 19:30 0.25 PULL 19:30 - 00:00 4.50 PULL 1/8/2010 00:00 - 03:00 3.00 PULL 03:00 - 03:15 0.25 PULL 03:15 - 03:45 0.50 PULL 03:45 - 04:00 0.25 RUNC 04:00 - 04:30 ~ 0.50 04:30 - 06:00 I 1.50 06:00 - 06:15 0.25 06:15 - 07:00 0.75 07:00 - 07:15 0.25 07:15 - 08:30 I 1.25 08:30 - 08:45 0.25 RU 08:45 - 13:00 4.25 RU 13:00 - 17:00 I 4.00 17:00 - 17:30 ~ 0.50 17:30 - 18:45 1.25 18:45 - 20:00 1.25 DECOMP PRE TOUR MEETING WITH ONCOMING CREW PJSM TO RU TO PULL 4.5" TUBING STRING DECOMP RU FLOOR TO PULL 4.5" TUBING DECOMP PJSM TO PULL 4.5" TUBING FROM W ELL DECOMP. D 4.5" TBG PULLED 105 JTS ~ 00:00 DECOMP CONTINUE TO PULL 4.5" TBG DECOMP PJSM TO CLEAR RIG FLOOR FROM PULLING 4.5" TBG DECOMP CLEAR RIG FLOOR RUNCMP PJSM TO RU FLOOR TO SERVICE ESP PUMP ASSEMBLY & PU ESP RUNCMP RU FLOOR TO SERVICE ESP PUMP ASSEMBLY PU ESP PUMP ASSEMBLY RUNCMP INSPECT & SERVICE ESP PUMP ASSEMBLY RUNCMP CHECK 6 HELD A SHORT 15 MINUTE MEETING W/CREW AFTER PTSM - DISCUSSED AAR'S, PURPOSE AND IMPLEMENTATION. RUNCMP RUNCMP PJSM TO SECURE ESP, MU XN-NIPPLE, & TEST ESP CABLE 'RUNCMP ATTACH, MAKE MASTER SPLICE & SECURE ESP MU PUPS & XN-NIPPLE TEST ESP CABLE RUNCMP PJSM TO RIH W ITH 2-7/8" ESP COMPLETION RUNCMP RIH WITH 2-7/8" ESP COMPLETION FLUSH PUMP ~ 2,000' W/ 800 PSI RUNCMP PULL HEAT TRACE OVER SHEAVE & ATTACH TO JT# 104 PINCHED ESP ARMOR WITH AIR SLIPS CUT & SPLICED ESP ~ 3,260' REPLACED AIR SLIPS RUNCMP RIH WITH 2-7/8" ESP COMPLETION CLAMPS CRIMPING ESP CABLE PULL CLAMP & TEST ESP TEST GOOD RUNCMP PTSM & CREW CHANGE OUT RUNCMP CHECK 6 HELD 60 MINUTE MEETING WITH CREW TO n__.-.~. .MCMn1n 17•flA•G~I DI.A • 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 I 4.00 11/s/2oio loo:oo - os:oo I s.oo 06:00 - 07:00 1.00 Start: 1 /4/2010 Rig Release: 1/10/2010 Rig Number: 4ES Spud Date: 8/28/2004 End: 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 W ITH 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 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 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 • 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 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 LAND HANGER, PU WT 45K, SO WT 30K RILDS TEST TWC 3,500 PSI FROM TOP FOR 10 MINUTES 200 PSI FOR 10 MINUTES FROM BOTTOM PUMPED AWAY 50 BBLS ~ 56PM DURING TEST 02:20 - 02:30 0.17 BOPSU P POST PJSM TO BLOW DOWN LINES & ND BOPE 02:30 - 04:30 2.00 BOPSU P POST BLOW DOWN LINES & ND BOPE 04:30 - 06:00 1.50 WHSUR P POST NU 2-9/16" TREE ON WELL MPI-19 06:00 - 07:00 1.00 WHSUR P 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. 07:00 - 07:30 0.50 WHSUR P POST PT TREE TO 5 000 P51 F0H 5 MIND I is CENTRILIFT PERFORMED FINAL CHECKS ON ESP AND HEAT TRACE -GOOD TESTS. 07:30 - 07:40 0.17 WHSUR P POST PJSM WITH CREW AND WELL SUPPORT TO RU LUBRICATOR & TEST, PULL TWC, AND INSTALL BPV. 07:40 - 08:30 0.83 WHSUR P POST RU LUBRICATOR AND TEST WITH DIESEL TO 500 PSI. PULL TWC AND INSTALL BPV. LD LUBRICATOR. 08:30 - 09:00 0.50 WHSUR P POST SECURE WELL AND CELLAR. 09:00 - 10:00 1.00 WHSUR P POST HELD AAR FOR MPI-19 WITH DAY TOUR. 10:00 - 11:00 1.00 WHSUR P POST HELD WEEKLY SAFETY MEETING WITH NABOBS MANAGEMENT. DISCUSSED WEATHER RELATED ISSUES AND SET GOALS FOR UPCOMMING YEAR. 11:00 - 12:00 1.00 WHSUR P 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 DOWN THE IA. '"'RELEASED RIG AT 12:00"' WAITING ON WEATHER FOR TRUCKS. -37 F AMBIENT AT MPI PAD. -46 F AMBIENT AT DEADHORSE AIRPORT. rnnrnu. ucwcu ra rc.~r.sa r-~r~ Tree: 2-9/16" - 5M FMC ~ M P I - ~ ~ Orig~elev. = 69.10' (Doyon 14) Wellhead: 11" x 11" 5M FMC Orig. 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 "Note" 10 3/4" 45:5 ppf L-80 & K-55 BTC-M (Drift ID = 10.050, cap: _ .0981 bpf)` Collapse / Ihternal Yield 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' Camco 2-7/8" x1" KBMM-2 Gas lift mandrel 137` 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' 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 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 563` 6 GRSFTX AR H6 , Centrilift Tandem Seal section 6 568' GSB3D6 UT/LT , Centrilift Motor (rerated) 83 hp / KMHA 6 582` 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` etm 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" Hole td @ 9720' Btm HES Type V Float Shoe 9720' 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L-80 IBT OB Lateral MILNE POINT UNIT WELL I-19 API Nn: 50-029-23218-00 50-029-23218-60 BP EXPLORATION (AKl c STATE OF ALASKA R E CEI VED EQ ALASIWIL AND GAS CONSERVATION COMMIA11ION REPORT OF SUNDRY WELL OPEkMbNS N OV Q ���� Alaska Oil & Gas Cons. Commission 1. Operations Performed: Anchorage ❑ 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 -136 3. Address: ❑ Service ❑ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 -029- 23218 -60 -00 Property Designation: Well Name and Number: ADL 025906 & 025517 MPI - 19L1 Field / Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured '\ 12225' feet true vertical Ns 4045' feet Plugs (measured) None Effective depth: measured 12225 feet Junk (measured) None true vertical 4045' 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 7159' 7 -5/8" 7192' 4015' 6890 4790 Liner 5012' 4-1/2" 7187'- 12199' 4013'- 4045' 8430 7500 �. 2009 Perforation Depth: Measured Depth: Slotted: 7253'- 12154' True Vertical Depth: Slotted: 4030'- 4045' 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 - 4ES 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 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 Terrie Hubble Title Drilling Technologist ' natu Phone 564 -462$ Date T"f arep a'ed Br Name/Number S �9 Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 t� ' /j IZ , 7, - 0 Submit Original Only • 0 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. 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 L/D 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 -LID 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 1 20 DEGREE SEAWATER DOWN THE TUBING,SET_UP TO TAKE.RETURNS Ol1T 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 5b BOF STAC V)X , 7 ')( 5 ",VBR'S AND BLIND SH RAM S. 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: 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 10/31/2009 07:30 - 14:30 7.00 BOPSUF PRE TEST BO - 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 - TEST ING A NNULAR. 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. 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 L/D. Printed: 11119/2009 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- V AND 1- 4', 30-3' FLAT GUARDS -1365 BANDS. 22:30 - 00:00 1.50 PULL P DECOMP BREAK UT 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 -LID 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 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 7- /8" RTTS AND S AS SEMBLY -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 RTTS @ 7,1.16' MD,_SE RTT S._ -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 RTTS, MONITOR WELL POOH AND INSPECT SEALS 03:00 - 07:30 4.50 CLEAN P CLEAN RELEASE RTTS AND P OH. _ -POOH W/ 7-5/8" RTTS 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. -UD 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 RUNCOP IP 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 I 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: 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 11/4/2009 06:30 - 18:00 11.50 RUNCO RUNCMP CONTINUE TO RUN IN HOLE WITH 4 -1/2" NSCT COMPLETION. 18:00 -18:30 0.50 BUNCO 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 O DOWN WT. 19:00 - 19:30 0.50 RUNCOAP RUNCMP FILL IA WITH 33 BBLS. -TEST IA TO 500 PSI FOR 5 CHARTED MINUTES.- OK. 19:30 - 21:00 1.50 RUNCOA IP 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 RUNCOAIP 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 RUNCOAP 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- 1116" - 5M FMC 1 - 19 Tem r8 WorkWn Orl elev. = 69.10' (Doyon 14) Wellhead: 11" x 11" 5M FMC ry g Orig. L elev. = 24.80` (Doyon 14) 4112" 7W Hgf: NSCT Wpdbl n 3" "M BP1t plMfiie 20 ", 92 # /ft, H -40 112' "Note" 10 314" 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 2514 4-112" x 1 KBG-2 (DGI0V *t 11A16) L -80 2480 psi. / 5210 psi. K -55 161' thru 2,879' 10 3/4" Howco Float Shoe 2999' 4-Iff - ' Allppls &818 OD 3007' KOP @ 300' 50+ degree from 2500 PXX PLUG INSTALLED 44AM Max hole angle = 75 degrees @ 6450' MD PLUG PULLED 11/9/09 7 5/8" 29.7 ppf, L -80, BTC -M casing (Drift ID = 6.750 ", cap = 0.0459 bpf) 41/2' 12.6# NSGT Tbg. 8.75 Bebr7W 8a*&WAnw* F 713T 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 t2,19a` outside hook point 7,204' 118 its. - 4 1/2" Slotted Liner 1 its, 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 Pkg Bore Baker HMC Liner Hng. 7,332' " Baker Seal bore ext. 7,340' L -1 Non locating Seal Assy. F731 0' / 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' 47 jts. - 4 112" Slotted Liner 8 its, 12.6# L -80 IBT OB Lateral DATE REV. BY CO MMENTS MILNE POINT UNIT 09/13104 MDO Drilled & Completed Doyon 14 WELL 1 -19 02/12/05 MDO ESP RWO Nabors -4es 10/17/08 REH ESP RWO/ Install LEM API NO: 50- 029 - 23218 -00 50- 029 - 23218 -60 11/4/09 REH Pull ESP/ Run 4.5" Workstring - Nabors 4ES BE EXPLORATION (AK) STATE OF ALASKA ///3-Og ACA OIL AND GAS CONSERVATION CO~.SSION REPORT OF SUNDRY WELL OPERATIONS 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 204-136 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23218-60-00 7. KB Elevation (ft): KBE = 69.1' 9. Well Name and Number: MPI-19L1 8. Property Designation: 10. Field /Pool(s): ADL 025517 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 12225' feet true vertical 4045' feet Plugs (measured) None Effective depth: measured 12225' feet Junk (measured) None true vertical 4045' 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 7159' 7-5/8" 7192' 4015' 6890 4790 Liner 5012' 4-1/2" 7187' - 12199' 4013' - 4045' 8430 7500 ~L` ~r'~' ~; ~ ~ ~ ~ ~ ~~ ~ `g , , Perforation Depth MD (tt): Slotted: 7253' - 12154' Perforation Depth TVD (it): Slotted: 4030' - 4045' 2-7/8", 6.5# L-80 6635' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A NIA 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: 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. 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 Howard West, 564-5471 M!q Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Numbar: ~ Signature ,_ Phone 564-4628 Date ~~ ~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 Submit Originally F ~ t • • 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= 20013001150 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. LRS ABLE TO CIRCULATE 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 EQULIZE XXN PLUG C~3 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 C~? 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. lA, and OA open to gauges. 10/4/2008 MIRU. RIH with BOT fishing string: jars, 2.5" GS. Tag plug C~3 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 C~3 500 scf/m into ASRC. Make stops C~ 4500' and 7100'. RIH dry and tagged 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 Page 1 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 9/17/2008 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 RIGD 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 Tigertank - 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 retums 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. Tubing 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. rnniev: iwzwcwa izsv:vc rm • • BP EXPLORATION Operations Summary Report Legal Well Name: MPI-19 Page 2 of 9 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 I Hours f Task f Code ~ NPT Phase Description of Operations 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 ROPE. 16:00 - 17:00 1.00 BOPSU P DECOMP Fill BOPS and function test. 17:00 - 21:30 4.50 BOPSU P DECOMP Pressure test ROPE per BP/AOGCC Regulations 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 pulled 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" landing joint screw into hanger, 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 rnncea: iu2wzuuu resu:az rm • • BP EXPLORATION Operations Summary Report .Legal Well Name: MPI-19 Common Well Name: MPI-19 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S 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 6.001 CLEAN P 20:00 - 22:30 I 2.501 CLEAN I P 22:30 - 00:00 1.501 CLEAN N I WAIT 00:00 - 06:00 ~ 6.00 ~ CLEAN ~ N ~ WAIT 06:00 - 00:00 I 18.00 I CLEAN C 9/23/2008 100:00 - 04:00 4.00 I CLEAN I C 04:00 - 08:00 4.00 CLEAN C 08:00 - 08:30 I 0.50 I CLEAN I C 08:30 - 16:30 I 8.00 I CLEAN I C 16:30 - 17:00 0.50 CLEAN I C 17:00 - 22:30 5.50 RNWOR 22:30 - 00:00 1.50 CLEAN I C 19/24/2008 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 tag top of fill and suspend operations again. 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 retums at 2 8PM / 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 Tag 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. j 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 design changes. Plan Forward finalized and waiting on equipmenVassemblies 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" workstring, run 3-1/2", 9.2#, L-80, NSCT tubing. Use Best-O-Life 2000 pipe dope. Make up torque is 2,890 fUlbs. 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 rnniea: iwcwcvva icav:vc rm • • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To MPI-19 MPI-19 WORKOVER NABOBS ALASKA DRILLING I NABOBS 3S `Hours Task Code NPT Spud Date: 8/28/2004 Start: 9/17/2008 End: 10/17/2008 Rig Release: 10/17/2008 Rig Number: 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 up 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, good test. Bleed the tubing pressure down to 1,500 psi. Pressure up the IA to 3,500 psi for 30 minutes on the chart, good 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" Type "H" TWC with FMC wellhead tech. Test from above to 3,500 psi for 10 minutes and from below to 500 psi 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-f/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 psi 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. rnntea: iurzwzuue 1Z:JU:4Z YM • • BP EXPLORATION 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 9/25/2008 07:00 - 09:30 2.50 WHSUR C 10/9/2008 06:00 - 11:00 11:00 - 20:00 20:00 - 21:00 21:00 - 22:00 22:00 - 22:30 22:30 - 00:00 10/10/2008 00:00 - 01:30 01:30 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 11:30 11:30 - 12:30 5.00 MOB P 9.00 MOB P 1.00 KILL P 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 12:30 - 13:00 0.50 WHSUR P 13:00 - 16:00 3.00 WHSUR P 16:00 - 17:00 1.00 WHSUR P 17:00 - 19:00 19:00 - 22:00 2.00 WHSUR P 3.00 WHSUR P 22:00 - 00:00 10/11/2008 00:00 - 00:30 00:30 - 06:00 06:00 - 08:00 2.00 WHSUR P 0.50 BOPSU P 5.50 DHB P 2.00 DHB P Start: 9/17/2008 Rig Release: 10/17/2008 Rig Number: Page 5 of 9 Spud Date: 8/28/2004 End: 10/17/2008 Phase ` Description of Operations CLEAN RU test pump and test the BPV from below with diesel to 1,000 psi for 10 charted mins - OK. RD test lines and equipment. Remove secondary annulus valve and secure the Tree. The Rig was released at 0930 hrs on 9/25/2008. PRE Rig released from MPG-04. RDMO location. 24 hour notice to Chuck Scheve with AOGCC for upcoming ROPE 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 held 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 head tech and test to 3,500 psi 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 ROPE. 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 get 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 500 psi then bleed to 300 psi. Well support techs pull TWC above blind rams, close blind rams and bleed to 0-psi. Ub 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. Hetd PJSM with SLB slickline crew. DECOMP RU SLB slickline crew with pressure control equipment and lubricator. DECOMP PUMU 1-7/8" toolstring and 3-1/2" XXN plug. Test Lubricator Nnrnea: iu¢urzuua 7L::1U:4L YM • • BP EXPLORATION 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 plug in 3-1/2" XXN plug in nipple ~ 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 psi against blind rams for 10 charted 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 Regulations 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 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" landing joint. 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 falling, 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 • • BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: MPf-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 10/12/2008 17:00 - 18:00 1.00 PULL P DECOMP come and shoot a fluid level. 18:00 - 20:00 2.00 PULL P DECOMP Pump 20 bbl SW down IA, lA ~ -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. 20:00 - 21:00 1.00 PULL P 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. 21:00 - 21:30 0.50 PULL P DECOMP POH LD tubing hanger and landing joint assembly, POW = 51 K. Fill rate at 20 BPH. 21:30 - 23:00 1.50 PULL P 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. 23:00 - 00:00 1.00 PULL P DECOMP Continue to POH slowly, UD 3-1/2" TBG work string. Maintain continuous fill rate of 20-25 BPH with no retums. 40 joints UD at 00:00 hours. 10/13/2008 00:00 - 04:00 4.00 PULL P DECOMP Continue to POH UD 3-1/2" work string to -2,800', (L/D 126 joints) Maintain continuous fill rate at 20-25 BPH. 04:00 - 05:00 1.00 PULL P DECOMP Pump 10 bbls SW down tubing and 20 bbls down the IA, TBG on a vacuum. BOLD champ packer. All elements and packer in "like new" condition. 05:00 - 09:30 4.50 PULL P DECOMP Continue to POH UD 3-1/2" work string, Maintain continuous fill rate at 20-25 BPH. 09:30 - 10:00 0.50 CLEAN P DECOMP Clean and clear floor. 10:00 - 15:00 5.00 CLEAN P DECOMP PUMU 3-1/2" down jet nozzle on 2-7/8" tubing from pipe shed. RIH maintaining charge pump on hole ~ -20 Bbl/Hr. 15:00 - 22:30 7.50 CLEAN P DECOMP 60 joints in hole. Flush nozzle ~ 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. 22:30 - 00:00 1.50 CLEAN P DECOMP PJSM with LRS. Reciprocate pipe 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 ~ 0 psi with no returns. Tubing and IA on a Vaccuum. 10/14/2008 00:00 - 02:00 2.00 CLEAN P 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. 02:00 - 08:30 6.50 CLEAN P 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. 08:30 - 10:00 1.50 CLEAN P DECOMP BOLD nozzle. Maintain continuous hole fill ~ -20 Bbl/Hr. Clean and clear rig floor. Prep for running completion. 10:00 - 13:00 3.00 BUNCO RUNCMP PUMU ZXP liner top packer BHA with LEM mandrel and 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. Printetl: 10/202Wtl 12:30:42 PM BP EXPLORATION Operations Summary Report Legal Well Name: .Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 WORKOVER Start: 9/17/2008 NABOBS ALASKA DRILLING I Rig Release: 10/17/2008 NABOBS 3S Rig Number: Date From - To .Hours ' Task 'Code' NPT ' Phase 10/14/2008 19:00 - 22:00 3.00 BUNCO RUNCMP 22:00 - 00:00 2.00 BUNCO RUNCMP 10/15/2008 00:00 - 03:00 3.00 BUNCO RUNCMP 03:00 - 04:30 1.50 BUNCO RUNCMP 04:30 - 05:00 0.50 BUNCO RUNCMP 05:00 - 06:00 1.00 BOPSU P RUNCMP 06:00 - 06:30 0.50 BOPSU P INTERN 06:30 - 08:00 ~ 1.50 BOPSU~ P ~ I INTERN 08:00 - 12:00 4.00 EVAL P INTERN 12:00 - 12:30 0.50 EVAL P INTERN 12:30 - 13:30 1.00 EVAL P INTERN 13:30 - 14:00 0.50 EVAL P I INTERN 14:00 - 15:30 1.50 EVAL P 15:30 - 16:30 1.00 BOPSU~ INTERN 16:30 - 17:30 1.00 BOPSU P INTERN 17:30 - 19:00 1.50 BUNCO RUNCMP 19:00 - 00:00 5.00 10/16/2008 00:00 - 05:00 5.00 RUNCMP RUNCMP Page 8 of 9 Spud Date: 8/28/2004 End: 10/17/2008 Description of Operations 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 with the top 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 charted 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. LD 25 joints and POH w /running tool, standing 2-7/8" tubing in Derrick. Maintain continuous hole fill ~ -20 Bbl/Hr. 24 stands out at 00:00 hours. Continue to receive source water from MPU, due to PBU STP shut down. POH w /running tool, standing 2-7/8" tubing in Derrick. Maintain continuous hole fill ~ -20 Bbl/Hr. BO / LD LEM / ZXP running tool. Clean and clear rig floor. ND pitcher nipple and air boot. Service the Rig and Derrick inspection. Perform pre-tour checks. NU the Shooting Flange. Spot the slickline unit. Feed the well 20 bbls of source water. 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. RIH with 2-7/8" CAT Standing Valve on slickline. Set the 2-7/8" CAT Standing Valve in the XN Nipple at 7,263' 3SMD (7,275' SLMDj. Beat down a couple of times to ensure it is set good. 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 psi 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. POOH with slickline and 2-7/8" CAT Standing Valve. Resume 20 bbls/hour fill rate with source water. RD slickline and lubricator extension. Recovered the 2-7/8" CAT Standing Valve. ND the Shooting Flange. NU the Flow Riser and Air Boot. Hang new ESP /Heat trace sheave in Derrick. RU to run ESP completion. Spot the Spooling Unit and load reels. PU / MU ESP pump and motor assembly with Centrilift reps. 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. s • BP EXPLORATION Page 9 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 rPhase ~ Description of Operations 10/16/2008 105:00 - 06:00 ~ 1.00 06:00 - 06:30 0.50 06:30 - 11:00 4.50 11:00 - 14:00 3.00 14:00 - 00:00 10.00 10/17/2008 100:00 - 00:30 00:30 - 01:30 01:30 - 02:30 02:30 - 06:30 06:30 - 07:30 0.501 BUNCO 1.00 BUNCO 1.00 BUNCO 4.00 BUNCO 1.00 BUNCO 07:30 - 08:30 08:30 - 13:00 13:00 - 15:30 15:30 - 17:00 17:00 - 18:00 1.00 WHSUR P 4.50 BOPSU P 2.50 WHSUR P 1.50 WHSUR P 1.001 WHSUR I P 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 no returns. 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" Type "H" TWC with FMC rep. 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 Support 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. ~nmea: turtazous tz:au:az rnn s Tree: 2-9/16" - 5M FMC Orig. DF elev. = 69.10' (Doyon 14) IWe Ihead: 11" x 11" 5M FMC M P I -1 ~ Orig. 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 ~~~, Camco 2-7/8" x1" 139` "NOtI?" KBMM-2 Gas lift mandrel 10 3/4" 45.5 ppf L-80 & K-55 BTC-M ' (Drift ID = 10.050, cap. _ .0981 bpf) ' i Camco 2-7/8" x1" 416' -Yield .Collapse / Internal KBMG Gas lift mandrel K-55 2090 psi. /' 3580' psi. L-80 2480 psi. / 5210 psi. K-55 161' thru 2,879' 10 3/4" Howco Ftoat Shoe 2ggg' Heat Trace to 2742' KOP @ 300' ~ i 50+ de ree from 2500' Camco 2-7/8" x1" 6,416' 9 KBMM-2 Gas lift mandrel Max hole angle = 75 degrees @6450' MD aiwE HES 2-7/8" XN-Nipple (2.250" id) 6,556' 7 5/8" 29.7 ppf, L-80, BTC-M casing Tandem Centrilift Pump 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 6 600' ( drift id = 2.347" cap = .00592 bpf) , GRSFTX AR H6 - Centrilift Tandem Seal section GS63DBUT 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' etm Baker Float Shoe 12,198' outside hook point 7,204' 118 jts. - 4 1/2" Slotted Liner OA Lateral 1 jts, 12.6# L-80 IBT Baker Tie Back Sleeve 7,315` t~ 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. - 41 /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 1111ELL I-19 02/12/05 MDO ESP RWO Nabors -4es 10/17/08 REH ESP RWO/ Install LEM API NO: 50-029-23218-00 sn-029-23218-60 BP EXPLORATION SAKI • • MICROFILMED 03/01 !2008 DD NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc / 3> ð·J4c ^ Ò \ ~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041360 Well NamelNo. MILNE PT UNIT SB 1-19L 1 Operator BP EXPLORATION (ALASKA) INC API~f~2Z~-~ ~ MD 12225'- TVD 4045 - Completion Date 9/13/2004"- Completion Status 1-01L Current Status 1-01L UIC N -~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR / Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number po D Asc I Rpt F D Asc I Rpt I ¿- D Lis I Rpt r C Lis ~- Well Cores/Samples Information: Name Directional Survey Directional Survey Directional Survey Directional Survey Ç<lrp"'í1 Ra.yj"l.~"'\"~',,", /(\.)...,1J,,:1\ LIS Verification Log Log Interval OH/ . Run Scale Media No Start Stop CH Received Comments 7187 12225 Open 10/7/2004 IIFR 7187 12225 Open 10/7/2004 IIFR 7187 12225 Open 10/7/2004 MWD 7187 12225 Open 10/7/2004 MWD 7192 12167 Open 1/27/2005 MWD/GRlEWR4/ABI/ROP 7192 12167 Open 1/27/2005 MWD/GR/EWR4/ABIIROP 112 12225 Open 2/22/2006 ROP DGR EWR plus Graphics 12947 12947 13574 Induction/Resistivity Name Interval Start Stop Sent Received Sample Set Number Comments . ADDITIONAL INFORMATION Well Cored? Y & Chips Received? ~ Formation Tops ~/N 6/N Daily History Received? Analysis Received? ~ .~~~,~,-~~~._--- ----~-~~---~-~ Comments: Compliance Reviewed By: ~ Date: 3 ö~ ~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 dQ4--I~ February 16, 2006 l3f:J7~ RE: MWD Formation Evaluation Logs MPI-19 L1, 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 Ll: LAS Data & Digital Log Images: 50-029-23218-60 1 CD Rom ~ rrl ~~\()(Q ·. L(H'¡;~ 1. Operations Performed: c~en6f~flSÞ"'I'm!!IlI~ o Abandon 181 Repair Well o Plug Perforations o Stimulate 181 Oth e o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 204-136 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23218-60-00 7. KB Elevation (ft): KBE = 69.1' 9. Well Name and Number: MPI-19L1 8. Property Designation: 10. Field / Pool(s): ADL 025517 Milne Point Unit I Schrader Bluff 11. Present well condition summary Total depth: measured 12225' feet true vertical 4045' feet Plugs (measured) None Effective depth: measured 12225' feet Junk (measured) None true vertical 4045' 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 7159' 7-5/8" 7192' 4015' 6890 4790 Liner 5012' 4-1/2" 7187' - 12199' 4013' - 4045' 8430 7500 Perforation Depth MD (ft): Slotted 7253' - 12154' Perforation Depth TVD (ft): Slotted 4030' - 4045' 2-7/8", 6.5# L-80 6634' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None None 12. Stimulation or cement squeeze summary; Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft MAH .1 .4 2005 13. ReDresentative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service aD Wen Schematic Diagram 16. Well Status after proposed work: 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Skip Coyner, 564-4395 Printed Name Sandra Stewman ~ Title Technical Assistant ~cP~~~~hone Q2¡ )S~ Prepared By Name/Number: 564-5803 Date -/10 -0 Sondra Stewman, 564-4750 . . . STATE OF ALASKA RSC.< ALASKA AND GAS CONSERVATION C.,SS,ON . .. EI\/ËD REPORT OF SUNDRY WELL OPERATION$AR 11 2005 AJa,b Oil ¿y G,S (' Form 10-404 RevIsed 04/2004 DUPLICATE Submit Onglnal Only .Iræ;. 2-9/16" - 5M FMC Wellhead' 11" x 11" 5M Fua Gen 5, w 2-7/8" FMC Tbg-.-." EU 8rd on t&b, 2.5" CIW-H BPV Profile 20', 92#/ft, H-40 "Note" 10314' 45.5 ppfL-80 & K-55 BTC-M (Drift ID = 10.050, cap. = .0981 bPi) Collapse I IntemalYield K-55 2090 psi. / 3580 psi. LooSO 24S0psi. / 5210 psi. K-55161' thru 2,879' 103/4" Howco Float Shoe I 2999' I KOP @ 300' 50+ degree from 2500' Max hole angle = 75 degrees @ 6450' MD 75/8" 29.7 ppl, LooSO, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpi) 2-7/S' 6.5 ppf, L-SO Srd eue tbg. ( drift id = 2.347' cap = .00592 bpI) Window in 75/S" Casing @ 7,192' - 7,204' Well Angle @ window = 72° 4-1/2" Hook Hanger inside casing 7,1S7' 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' / 7-5/S" Weatherford Float Collar 7344' 7-5/S" Weatherford Float Shoe 742S' DATE 09/13/04 02/12/05 REV. BY MDO MDO COMMENTS Drilled & Completed Doyon 14 ESP RWO Nabors -4es MPI-19 OA Lateral Orig. DF elev. = 69.10' (Doyon 14) .rig. GL elev. = 24.S0' (Doyon 14) Cameo 2-7/S" x1' KBMG Gas lift mandrel Cameo 2-7/S" x1' KBMG Gas lift mandrel Cameo 2-7/S" x1' KBMG Gas lift mandrel HES 2-7/S" XN-Nipple (2.250" id) Tandem Centrilift Pump 95 stg_GC1700 /19 stg_ GCS200 GPMTAR 1:1 Tandem Centrilift (400 Intemals) Intake GRSFTX AR H6 Centrilift Tandem Seal section 513 GSB3DBUT AB/HSN PFSA I Centrilift Motor 114 hp 1 KMH 2330 volt / 30 amps. PumpMate w/6 fin centralizer I 167' I I 2,030'1 I 6,406'1 I 6,578" I 6,597' I I 6,610'1 16,602' I 6,616'1 16,628'1 16,634' 63/4" Hole td @ 12.225' Btm Baker Float Shoe 12,198' 118 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# LooSO IBT 63/4" Hole td @ 9720' Blm HES Type V Float Shoe 9720' 47 jts. - 4 112" Slotted Liner 8 jts, 12.6# L-80 IBT Mll,J'iE POIl':lJ UN I"L WELL 1-19 API NO: 50-029-23218-00 50-029-23218-60 BP EXPLORATIQN (AK) BP EXPLORATION Operations Summary Report Rig Down and move to MPI·19 Move to MPI-19, Rig on location at 20:45 Spot Rig on to location, Accept Rig at 02:00 Pull BPV, Rig up lines to kill well, fill pits with seawater T/I!O = 1100/1200/130 PJSM. Spot tiger tank & rig up lines. Rig up lines to kill well. PT lines to 1500 psi, OK. PJSM. Bleed gas from tubing & IIA to tiger tank. Line up & circulate heated seawater @ 4 bpm I 300 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 IIA @ 5 bpm /350 psi. Monitor well & blow down lines. Tubing & IIA both on vacuum. PJSM. Set two way check. NID existing wellhead, (tree, adapter, HCR). PJSM. N/U 13 5/8' x 5M BOPE & secondary annulus valve. 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 tool pusher. 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. Pressure test BOP annular low and high pressure· test good. Test accumulator· test good. Drain stack and pull out pipe rams. New set of 2-7/8' x 5' variable pipe rams installed. Start low and high pressure test on pipe rams. Attempt multiple low and high tests on pipe rams. Could not get rams to hold pressure firmly. Would loose -100psi in 5 mins on high pressure test. Change to another set of pipe rams. 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. Pull TWC Pump 100 bbls of seawater down lA, monitor pressure. IA on vac. Pull hanger to the floor and laydown same. POOH wi ESP completion string, double disptacing hole. PJSM. UD ESP assembly. Shaft twisted In seals. PJSM. Pick up new ESP assembly. RIH wi ESP completion, pumping down tubing & checking conductivity of ESP cable every 2000'. M/U Landing Joint Up WT = 44K Down WT = 30K Make field connector splice, pump 15 bbls at 1/2 bpm@130 psi. RD tubing handling equipment and spooling unit. Land hanger and run in lock down screws. Lay down landing joint and install TWC Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI·19 MPI-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From-To Hours Task Code NPT Phase 2/9/2005 21 :00 - 00:00 3.00 RIGD P PRE 2/10/2005 00:00 - 00:00 24.00 MOB P PRE 2/11/2005 00:00 - 02:00 2.00 MOB P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 06:00 3.00 RIGU P PRE 06:00 - 10:30 4.50 KILL P DECOMP 10:30 - 11:00 0.50 KILL DECOMP 11:00 - 13:00 2.00 BOPSU DECOMP 13:00 - 15:00 2.00 BOPSU DECOMP 15:00 - 17:00 2.00 BOPSU DECOMP 17:00·18:00 1.00 BOPSU P 18:00 - 19:00 1.00 BOPSU DECOMP 19:00 - 20:30 1.50 BOPSU DECOMP 20:30 . 21 :30 1.00 BOPSU DECOMP 21 :30 - 00:00 2.50 BOPSU DECOMP 2/12/2005 00:00 - 01 :00 1.00 BOPSU P 01:00 - 02:00 1.00 BOPSU DECOMP 02:00 - 03:00 1.00 KILL DECOMP 03:00 - 04:00 1.00 PULL P DECOMP 04:00 - 10:00 6.00 PULL P DECOMP 10:00 - 12:00 2.00 PULL P DECOMP 12:00 - 14:30 2.50 RUNCO RUNCMP 14:30 - 18:00 3.50 RUNCO RUNCMP 18:00 - 18:30 0.50 RUNCO RUNCMP 18:30 - 20:00 1.50 RUNCO RUNCMP 20:00 - 20:30 RUNCMP Page tot 2 Start: 2/1 0/2005 Rig Release: 2/12/2005 Rig Number: Spud Date: 8/28/2004 End: Description ot Operations Printed: 2/1412005 9:25:24 AM Page 2 of 2 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/12/2005 MPI-19 MPI-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From -To Hours Task Code NPT Phase 20:30 - 21 :30 1.00 RUNCO RUNCMP 21 :30 - 23:00 1.50 RUNCO RUNCMP 23:00 - 00:00 1.00 RIGD P POST Start: 2/10/2005 Rig Release: 2/12/2005 Rig Number: Spud Date: 8/28/2004 End: Description of Operations Nipple down BOP's Nipple up tree and adapter flange, test void and tree to 5000 psi. Pull TWC and set BPV. Secure well and Centrilift perform final check- good. Rig Released at 2400 Printed: 2/1412005 9:25:24 AM -. "'-. .. STATE OF ALASKA . ALASKAIIft.. AND GAS CONSERVATION COM . ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revision: 11-«»2-04, Start Producti911 1a. Well Status: a Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 a Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/13/2004 204-136 ~Q1 303 ß¡CTJ 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/7/2004 50- 029-23218-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/10/2004 MPI-19L 1 2319' NSL, 3521' WEL, SEC. 33, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2033' NSL, 4474' WEL, SEC. 28, T13N, R10E, UM (OA) KBE = 69.1' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 5260' NSL, 1475' WEL, SEC. 29, T13N, R10E, UM (OA) 12225' + 4045' Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 551850 y- 6009437 Zone- ASP4 12225' + 4045' Ft ADL 025517 TPI: x- 550849 y- 6014423 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 548538 y- 6017634 Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost DYes aNo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , IFRlCASANDRA , RES, ABI , PWD 22. CASING, liNER AND CEMENTING RECORD ~$~~~ . SETTING EPlfHMD .SEtTINGDEPTHTVD ·~fi£i. ~ .WT.¡::>gRFT. ii .GRAD~ lOP BOT1"OM TPI? BOT1"OM > 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 2!~99' 35' 2550' 13-1/2" 468 sx AS Lite, 254 sx Class 'G' 7-5/8" 29.7# L-80 33' 7'192' 33' 4015' 9-7/8" 757 sx Class 'G' 4-1/2" 12.6# L-80 7187' 12199' 4013' 4045' 6-3/4" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. T 'BING ). }, Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-12" Slotted Liner 2-7/8",6.5#, L-80 6647' N/A MD TVD MD TVD 25. AC!D,: '...·¡;:Tþ· " 7253' -12154' 4030' - 4045' ·.HI:!II!I;I'oI!. . .......} DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls Dead Crude and 125 Bbls of Diesel. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 20,2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF W A TER-BsL CHOKE SIZE 1 GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; jf none, state "none". None RBDMS BFL NO'V - 3 2004 J\L O. \ ,~ ; .. G,r: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MC NA NB NC NE NF OA 5085' 5650' 5665' 5830' 6183' 6543' 6680' 6810' 6900' 7060' 7188' 3319' 3544' 3550' 3607' 3726' 3828' 3865' 3897' 3920' 3973' 4014' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~e 204-136 304-303 Permit No. I A roval No. Technical Assistant Date \ 1 - (.")2- MPI-19L 1 Well Number Prepared By Name/Number: Drilling Engineer: Sandra 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 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 · STATE OF ALASKA A ALASKA AND GAS CONSERVATION COM""-'ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG R ~iECl=h/r::n 1a. Well Status: IBI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: '.., f'~,f 20AAC 25.105 20AAC 25.110 181 ~~If5P"'EWt ¡gJJtPloratOry oGINJ oWINJ o WDSPL No. of Completions One Other o Stratigraphic' ervice 2. Operator Name: 5. Date Camp., Susp., or Aband. 'n f2. Permitto.DriIlNurT1.b~r " ':':~ fl BP Exploration (Alaska) Inc. 9/13/2004 , 204-1,:3£3 '304-303 3. Address: 6. Date Spudded , 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/7/2004 50- 029-23218-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/10/2004 MPI-19l1 2319' NSL, 3521' WEL, SEC. 33, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2033' NSL, 4474' WEL, SEC. 28, T13N, R10E, UM (OA) KBE = 69.1' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 5260' NSL, 1475' WEL, SEC. 29, T13N, R10E, UM (OA) 12225' + 4045' Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 551850 < y- 6009437/ Zone- ASP4 I 12225' + 4045' / Ft ADL 025517 TPI: x- 550849 y- 6014423 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 548538 · y- 6017634 - Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes oNo N/A MSL 1800' (Approx.) 21. Logs Run: '7'7" ,c.J "-:ttt>f4,J -¡/~2' 'hþ MWD , GR , IFRlCASANDRA , RES, ABI , PWD ¥l>/ S-' 'TV"þ 22. (,ASING, LINER AND CEMENTING RECORD _..-Q..Þ /I.:J<' ",64 ç~~~~ .. GRA[)~ SETTINGDEPl'H MD . ..~E1:TIN@OEPrH1VÖ '~~i{ .·.Plí;J.~t'I Wr. PERFTi TOP 6ÓTTOM TOP ¡BÓTTOM ..,......,. 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 2999' 35' 2550' 13-1/2" 468 sx AS Lite, 254 sx Class 'G' 7-5/8" 29.7# L-80 33' 7192' 33' 4015' 9-7/8" 757 sx Class 'G' 4-1/2" 12.6# L-80 7187' 12199' 4013' 4045' 6-314" Uncemented Slotted Liner 23. Perforations op'en to Production (MD + TVD of Top and 24. , ,",,,..,.., , " ...,...".', T" ',T, Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-12" Slotted Liner 2-7/8", 6.5#, L-80 6647' N/A MD TVD MD TVD .25. ·..A",....'..., .."",. ..... )~'r¢. '........ 7253' -12154' 4030' - 4045' . '7...'....';.. ,-1':"";"'7',:".. . " DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls Dead Crude and ~5 Bbls of Diesel. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL -BBL GAs-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rëo1~~1~~'! or;¡ None ¡ t/j :7if·6{¡ 0 ¡ ('\ i t. I A L 1 Hr''''::'~~;~''~ ~. ! ':JJ:>:~ ¡ bY ¡ lJ Il\l' .' . L~::~n,__,_....~':-:::, f Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ I</J£ì11s 28. GEOLOGIC MARKERS 29. RMATlON TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 NA NB NC NE NF OA 5085' 5650' 5665' 5830' 6183' 6543' 6680' 6810' 6900' 7060' 7188' 3319' 3544' 3550' 3607' 3726' 3828' 3865' 3897' 3920' 3973' 4014' None OCr¡1:"" ~.~ ¿¿~¢ 1ft" "'.s"/¡f} 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 foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date t D -- I J.i -0 ~. MPI-19L1 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Skip Coyner. 564-4395 204-136 304-303 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate 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" x 11" 5M FM. Gen 5, W 2-7/8" FMC Tbg. " EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 lliÐ " Note" 103/4" 45.5 ppf L-80 & K-55 BTC-M (Drift ID = 10.050, cap. = .0981 bpf) Collapse / Intemal Yield K-55 2090 psi. / 3580 psi. L-80 2480 psi. / 5210 psi. K-55 161' thru 2,879' 103/4" Howco Float Shoe 12999' I KOP @ 300' 50+ degree from 2500' Max hole angle = 75 degrees @ 6450' MD 75/8" 29.7 ppf, L-80, BTC-M casing (Drill 10 = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. (drill 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' / 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 Orig. OF elev. = 69.10' (Doyon 14) .rig. GL elev. = 24.80' (Doyon 14) Cameo 2-7/8" x1" KBMG Gas lift mandrel Cameo 2-7/8" x1" KBMG Gas lift mandrel Cameo 2-7/8" x1" KBMG Gas lift mandrel HES 2-7/8" XN-Nipple (2.250" id) Centrilift Pump 122 stg. / GC2200 GPMTAR 1:1 Centri/ift Intake 400 intemals Model - GRSTXAR Centrilift Tandem Seal section 513 GSB3DBUTILH6PFSA GSB3DBL TH6FSA Centrilift Motor 133 hp / KMH 2205 volt / 37 amps. PumpMate w/6 fin centralizer I 178' I I 2,041'1 I 6,416' I 16,568'1 16,589' I 16,610' I 16,615' I 16,629' I 16,641' I I 6,647' I 63/4" Hole Id @ 12,225' Blm Baker Aoal Shoe 12,198' 118 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT 6 3/4" Hole Id @ 9720' 81m HES Type V Floal Shoe 9720' 47 jts. - 4 1/2" Slotted Liner 8 jts, 12.6# L-80 IBT JYlIL~POINT UM-T~ WEL.L..l:1.9.. API NO: 50-029-23218-00 50-029-23218-60 B~ EX~ORATJON (AK) Page 1 of 7 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/27/2004 8/28/2004 8/29/2004 8/30/2004 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 From - To Hours Task Code NPT Phase 07:00 - 08:00 1.00 MOB P 08:00 - 09:00 1.00 MOB P 09:00 - 11 :00 2.00 MOB P 11 :00 - 12:00 1.00 MOB P 12:00 - 13:00 1.00 MOB P 13:00 - 15:00 2.00 RIGU P 15:00 - 22:00 7.00 DRILL P 22:00 - 00:00 2.00 DRILL P 00:00 - 01 :00 1.00 DRILL P 01 :00 - 02:00 1.00 DRILL P 02:00 - 03:30 1.50 DRILL P 03:30 - 04:00 0.50 DRILL P 04:00 - 05:30 1.50 DRILL N 05:30 - 06:00 0.50 DRILL P 06:00 - 23:30 17.50 DRILL P 23:30 - 00:00 0.50 DRILL P 00:00 - 00:30 0.50 DRILL P 00:30 - 01 :30 1.00 DRILL P 01 :30 - 02:00 0.50 DRILL P 02:00 - 10:00 8.00 DRILL P 10:00 - 12:30 2.50 CASE P 12:30 - 13:30 1.00 CASE P 13:30 - 14:00 0.50 CASE P 14:00 - 15:30 1.50 CASE P 15:30 - 17:00 1.50 CASE P 17:00 - 18:30 1.50 CASE P 18:30 - 19:30 1.00 CASE P 19:30 - 20:30 1.00 CASE P 20:30 - 23:30 3.00 CASE P 23:30 - 00:00 00:00 - 01 :30 01 :30 - 04:00 0.50 CASE P 1.50 CASE P 2.50 CEMT P PRE PRE PRE PRE PRE PRE SURF SURF SURF SURF SURF SURF DFAl SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF 04:00 - 05:30 1.50 CASE P SURF 05:30 - 06:30 1.00 CASE P SURF 06:30 - 09:30 3.00 CASE P SURF 09:30 - 10:30 1.00 CASE P SURF 10:30 - 13:30 3.00 CASE P SURF Description of Operations PJSM, Skid rig floor Move off well, center rig on pad Shuffle and double up rig mats, set approach Move rig to MPI-19, spot over well Skid rig floor, rig up Nipple up Diverter, Rig was accept @ 11 :00 hrs 8/27/2004 due to Poor pad conditions Rig up and picking up pipe and standing in derrick, total of 78 stands, mixing spud mud Pickup BHA #1, Orient Bha Diverter Test, the right to witness test was wavier by John Chrisp AOOGC, rig up Sperry- Sun Gyro unit Spud meeting with all hands, fill hole with mud check for leaks Spud well, drill 112' to 254' Pooh to pickup flex dc, Check MWD, install new probe in MWD Picking up flex dc, Rih 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') Circ 2 bottoms up, with 513 gpm, 2000 psi, 80 rpms Finish Circ 2 bottoms up, with 513 gpm, 2000 psi, 80 rpms Pumping out to HWDP at full drilling rate Trip back to bottom, ream last stand to bottom Drill 1,977' to 3,010' with 80 rpm. 513 gpm, 2400 ps Circ 2 bottoms up with 513 gals min., 2280 psi, 80 rpms Pump out with full drilling rate to 1400', hole not taking proper fill Rih to 2950', wash to bottom 3010' Circ. 2 bottoms up, weight up to 9.6, flow check, well static Pump out to HWDP, with full drilling rate Stand back HWDP, lay down BHA Clear floor PJSM, Rig up to pick up 103/4 Csg Picking up 103/445.5# 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 Rig down Franks tool, rig up cement head Circ and Thin mud for cement job. 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 bb/s 600 psi, Bump plug with 1500 psi, floats held, 190 bbls good cement to surface Flush Diverter, lines, clear rig floor Nipple down Diverter Nipple up starting head, test to 1000 psi for 10 min., Nipple up BOP stack Change out bales, install test plug, rig up for Bop test 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: 912012004 11: 12:25 AM BPEXPLORATION Operations Summary Report Page 2 of 7 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 Date From - To Hours Task Code NPT Phase Description of Operations 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 wi 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 WI. 265 psi, TVD 2549 = EMW 11.0 21 :00 - 00:00 3.00 DRILL P INT1 DriJI3030' 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 9 7/8' 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 5/8' 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: 912012004 11: 12:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 3 of7 BP EXPLORATION Operations·· Summary Report 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 From - To Hours Task Code NPT Phase Description of Operations 9/2/2004 13:30 - 16:00 16:00 - 16:30 16:30 - 19:00 19:00-21:30 21 :30 - 22:00 22:00 - 00:00 9/3/2004 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 10:00 10:00 - 10:30 10:30 - 11 :30 11 :30 - 12:30 12:30 - 13:00 13:00 - 14:30 14:30 - 15:30 15:30 - 18:00 18:00 - 20:30 20:30 - 23:00 2.50 CASE P 0.50 CASE P INT1 INT1 2.50 CASE P INT1 2.50 CEMT P INT1 0.50 CASE P INT1 2.00 CASE P INT1 1.00 CASE P INT1 1.50 CASE P INT1 0.50 CASE P INT1 0.50 CASE P 1.50 CASE P INT1 INT1 0.50 CASE P 4.50 CASE P INT1 INT1 0.50 CASE P 1.00 CEMT P INT1 INn 1.00 CASE P 0.50 EVAL P INT1 INT1 1.50 DRILL P PROD1 1.00 DRILL N 2.50 DRILL N 2.50 DRILL N DFAL PROD1 DFAL PROD1 DFAL PROD1 2.50 DRILL N DFAL PROD1 and circ last joint down 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' Circulate two casing volumes - 682 bbls - 6840 strokes - Condition mud for cementing 7 5/8" casing - BPM 6 - PP 500 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 cufVsx 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 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 Rig down casing tools - Lay down casing tools - Cementing head - Install 7 5/8" pack-off - Test to 5000 psi - Hold for 15 mins- Test good 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- Pull test plug - Install wear ring - Rig down testing equipment - Change bails on top drive - Install elevators Rig service Moblize BHA - Make up 6 3/4" bit - Motor - MWD - Orient same - Con't pick up BHA Purge pumps - Surface test MWD 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 Test casing to 2500 psi for 30 mins - Test good Drill float equip from 4742' to 7428' - Drill 20 new hole from 7438' to 7458' CBU - Circulate condition mud for FIT Preform FIT - TVD 4077' - MD 7328' - Mud weight 9 ppg - Surface pressure 635 = EMW 12 ppg 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 CBU - For trip due to DHT failure - Flow check - Well static POOH from 7639' to BHA @ 267' Down load MWD - Change out motor - Orient - Up load MWD - Surface test RIH from 268' to 7375' - Fill pipe every 25 stands on trip in Printed: 912012004 11: 12:25 AM BP . EXPLORATION Operations Summary Report Page40f7 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 Date From - To Hours Task Códe NPT Phase Description ofOperéltÎöns 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 102 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 PAOD2 Pick up Baker Whipstock assy . Orient - Con't PU BHA - Surface test 23:00 - 00:00 1.00 STWHIP P PAOD2 RIH with Baker whipstock assy Printed: 912012004 11: 12:25 AM BP EXPLORATION Operations Summary Report PROD2 RIH with Baker Whipstock to 7207' - Filling every 25 stds - PROD2 Orient whipstock 13 degree to left of high side - RIH tag up 7329' which puts TOW @ 7192' - Set 22K down to set anchor - P II 15K over pick up weight to confirm anchor set - Set 43K 'mes to Milling OA window from 7192' to 7204' '5pl....cL f\'"\ P L i9 L I CBU - Pump sweep - RPM 100 - TO 5K - GPM 347 - PP 2900 Flow check - Well Static· POH from 7170' to 876' @ BHA- lay down milling assy MU stack washer - Flush BOP stack MU Drlg BHA - Orient - Flow test RIH from 268' to 6140' PU 33 joints of 4' HWT Base line ECD 10.3 ppg - Orient for window exit - Slide through window 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 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 Pump swep - CBU 2 X - Circulate clean hole - Reduce ECD to 10.45 ppg 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 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 Pump sweep - CBU 3 X - GPM 300 - PP 3750 - RPM 100 - TO 7.5 Pump to shoe @ drfg rate with 50 RPM rotary Cut drfg line - Service top drive - Check saver sub for wear @ 7100' Orient to high side - RIH 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 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 Pump sweep - CBU clean up hole due to high ECD - RPM 92 - TO 7 - GPM 297 - ICP 3760 Circulate to clean up hole - GPM 297 - PP 3620 - RPM 92- TO 7 - (PU 160 - SO 52 - ROT 106) 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 PROD2 Pump sweep - CBU 3 X - RPM 100 - TO 7 - GPM 300 - PP 3850 psi PROD2 Pump out to shoe - Backreaming @ 35 rpm - Pump @ drfg rate - Pump to 7282' - Pull through whipstock from 7282' to 7186' without rotating or pumping - TOW 7192' - Observe well- Well Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Date From-To Hours Task Code NPT Phase 9/7/2004 00:00 - 02:30 02:30 - 03:00 2.50 STWHIP P 0.50 STWHIP P 03:00 - 08:00 5.00 STWHIP P PROD2 08:00 - 09:00 1.00 STWHIP P PROD2 09:00 - 12:00 3.00 STWHIP P PROD2 12:00 - 13:00 1.00 STWHIP P PROD2 13:00 - 13:30 0.50 STWHIP P PROD2 13:30 - 14:30 1.00 DRILL P PROD2 14:30 - 16:00 1.50 DRILL P PROD2 16:00 - 17:00 1.00 DRILL P PROD2 17:00 - 17:30 0.50 DRILL P PROD2 17:30 - 00:00 6.50 DRILL P PROD2 9/8/2004 00:00 - 16:00 16.00 DRILL P PROD2 16:00 - 18:00 2.00 DRILL P PROD2 18:00 - 00:00 6.00 DRILL P PROD2 9/9/2004 00:00 - 04:00 4.00 DRILL P PROD2 04:00 - 06:30 2.50 DRILL P PROD2 06:30 - 09:30 3.00 DRILL P PROD2 09:30 - 11 :00 1.50 DRILL P PROD2 11 :00 - 13:00 2.00 DRILL P PROD2 13:00 - 23:00 10.00 DRILL P PROD2 23:00 - 00:00 1.00 DRILL P PROD2 9/10/2004 00:00 - 02:00 2.00 DRILL P PROD2 02:00 - 07:30 5.50 DRILL P PROD2 07:30 - 10:30 3.00 CASE P 10:30 - 15:30 5.00 CASE P Page 5 of 7 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 Description of Operations Printed: 9/2012004 11: 12:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/10/2004 9/11/2004 MPI-19 MP/-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Frorn-To Hours Task Code NPT Phase 10:30 - 15:30 5.00 CASE P PROD2 15:30 - 17:30 2.00 CASE P PROD2 17:30 - 20:30 3.00 CASE P PROD2 20:30 - 00:00 3.50 CASE P PROD2 00:00 - 01:00 1.00 CASE P PROD2 01 :00 - 01 :30 0.50 CASE P PROD2 01 :30 - 04:00 2.50 CASE P PROD2 04:00 - 04:30 0.50 CASE P PROD2 04:30 - 05:30 1.00 CASE P PROD2 05:30 - 06:00 0.50 CASE P PROD2 06:00 - 07:00 1.00 CASE P PROD2 07:00 - 09:00 2.00 CASE P PROD2 09:00 - 09:30 0.50 CASE P PROD2 09:30 - 10:00 0.50 CASE P PROD2 10:00 - 13:30 3.50 CASE P PROD2 13:30 - 16:00 2.50 CASE P PROD2 16:00 - 16:30 0.50 CASE P PROD2 16:30 - 17:00 0.50 CASE P PROD2 17:00 - 21 :00 4.00 CASE P PROD2 21 :00 - 00:00 3.00 CASE P PROD2 9/12/2004 00:00 - 02:00 2.00 CASE P PROD2 02:00 - 03:30 1.50 CASE P PROD2 03:30 - 05:00 1.50 CASE P PROD2 05:00 - 08:00 3.00 CASE P PROD2 08:00 - 08:30 0.50 CASE P PROD2 08:30 - 11 :30 3.00 CASE P PROD2 11 :30 - 12:30 1.00 CASE P PROD2 Page 6 of7 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 Description of Operations static Orient to high side - RIH from 7168' to 12140' - Precauctionary wash from 10140' to 12225' - PU 125 - SO 85 CBU 3 X - GPM 255 - PP 3450 - RPM 100 - TO 7 - ECD's 10.8 ppg to 11.0 ppg - Flow check - Well static - PU 155 - SO 80 Pump out from 12225' to 8050' - Pump rate 250 GPM - No Backreaming Con't pump out from 8050' to 7282' - Pull through window from 7282' to 7073' without pumping or rotating - CBU - 80 RPM - TO 4 - GPM 290 - PP 2600 POH from 7050' to BHA @ 268' Stand back BHA / LD BHA Down load MWD Flush motor - Lay down same Make up Baker retrieving assy - Surface test MWD - 71 spm @ 1390 psi RIH from 825' to 7130' - Filling every 25 stands Orient hook - Latch onto whipstock - PU 170 - Release unloader sub - PU 190 set jars off to release whipstock - Flow check well- Well static CBU - GPM 305 @ 2570 psi POH with whipstock Handle BHA - Stand back 3 1/2' HWT - 4 3/4" DC's - Lay down MWD - Break down Baker retrieving tools and whipstock - Tailpipe assy - Service break Baker tools LD Baker equipment - Clean rig floor Rig up 4 1/2' Slotted liner running tools PJSM - Pick up and run 41/2' slotted liner - 120 joints 41/2" 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 RIH from 5018' to 9049' with liner on DP - Exited window after fouth attempt - Liner weight at window PU 11 OK - SO 87K - Block weight 50K Con't RIH with 41/2" slotted liner from 9049' to 12173' - PU 160 - SO 83 - Block weight 50K Hook wall hanger in BOW @ 7204' Float shoe @ 12198' - Pick up tum pipe 1/4 tum - RIH hook wall hanger to 7214' float shoe to 12210' - Pick back up to 12173' tum 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 Cut drlg line - Top Drive service - Rig service POH with Baker hook wall hanger running tools Lay down hook wall liner running tools 1 Clean rig floor MU circ sub and RIH to 7175' Circulate mud @ 275 GPM - PP 1800 - RPM 80 - TO 6K- PJSM on displacement Priore<!: 912012004 11: 12:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report MPI-19 MPI-19 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Date From -To Hours Task Code NPT Phase 9/12/2004 12:30 - 15:00 2.50 CASE P PROD2 15:00 - 23:30 S.50 CASE P PROD2 23:30 - 00:00 0.50 CASE P PROD2 9/13/2004 00:00 - 01 :00 1.00 RUNCO RUNCMP 01 :00 - 02:00 1.00 RUNCO RUNCMP 02:00 - 05:00 3.00 RUNCO RUNCMP 05:00 - 16:00 11.00 RUNCO RUNCMP 16:00 - 16:30 RUNCMP 16:30 - 19:00 2.50 RUNCO RUNCMP 19:00 - 19:30 0.50 RUNCMP 19;30 - 20:00 0.50 RUNCO RUNCMP 20;00 - 21 :00 1.00 RUNCO RUNCMP 21 :00 - 23:00 2.00 RUNCO RUNCMP 23:00 - 00:00 1.00 RUNCO RUNCMP Page 7 of 7 Start: 8/27/2004 Rig Release: 9/13/2004 Rig Number: Spud Date: 8/28/2004 End: 9/13/2004 Description of Operations 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 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' Pull wear ring - Moblize tubing jewelery to rig floor - Moblize tubing equipment PJSM Running ESP completion - RU tubing running equipment PU / MU 2 7/S" ESP pump assy - Test Run 2 7/S" 6.5# tubing and ESP cable - Perform ESP cable integrity test / fill pipe after 1000' and every 2000' on trip in hole Make up tubing hanger - (Ran 207 joints 27/S" 6.5# EUE S 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 S5 - SO 70 Splice ESP cable tubing penetrator - test continuity - Good test - Make up cable to penetrator - test continuity - Good test - Flush mud circ system Land tubing - RILDS - Test TWC from above to 1000 psi - Good test Rig down test equipment - Lay down landing joint Nipple down BOP stack 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 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: 912012004 11: 12:25 AM Legal Name: MPI-19 Common Name: MPI-19 Test Date 8/30/2004 9/3/2004 Test Type Test Depth (TMD) 3,030.0 (ft) 7,428.0 (ft) TesfDepth . (TVD) 2,549.0 (ft) 4,077.0 (ft) Surface Pressure 265 (psi) 636 (psi) AMW 9.00 (ppg) 9.00 (ppg) Leak Off Pressure (BHP) 1 ,457 (psi) 2,542 (psi) FIT FIT Page lof 1 EMW 11.00 (ppg) 12.00 (ppg) Printed: 9/20/2004 11: 12: 18 AM ·WELL SERVICE REPORT. WELL MPI-19 DATE 9/14/2004 AFE MSD337402 JOB SCOPE NEW WELL POST DAILY WORK FREEZE PROT KEY PERSON FESCO - WILSON MINID 0" 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. «<Note: SPM status added to this report to reflect what is in the well bore»»> Final WHP=550, 300, O. Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 13:30 Load fluids 14:34 AOURia UP 14:38 Diesel 3000 PT Lines 14:39 .8 0 Crude 200 Start down IA 14:43 2.5 5 1000 14:51 " 25 1375 15:01 -- 2.5 50 1425 15:12 " 75 Crude 1500 Switch to flush 15:13 1.0 0 Diesel 675 Continue 15:14 " 2 " Stop 15:22 3500 PT Lines 15:24 1.0 0 Diesel 1800 Start down tubinq 15:38 " 15 1975 SD 15:49 -. RDMO . Final-> 550 300 0 FLUID SUMMARY 75 bbls Crude. 15 bbls Diesel. SER~CECOMPANY-SER~CE DAILY COST CUMULTOTAL BP $0 $0 FESCO $780 $1 560 WAREHOUSE $630 $4,830 TOTAL FIELD ESTIMATE: $1,410 $6,390 . AOGCC ~ubh I Dðð36rr" 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well MPI-19 L 1 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: 7,187.91' MD 7,192.00' MD 12,225.00' 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 /Ð /7 !&( signÇ , / ~--..-; Please call me at 273-3545 if you have any q Regards, William T. Allen Survey Manager Attachment(s) ~ 0«1-/3 ~ DEFINITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-19L1 . Job No. AKZZ3258923, Surveyed: 10 September, 2004 Survey Report 30 September, 2004 Your Ref: API 500292321860 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 spa......i'y-suf1 CAtL...L..1NG SEAVICES A Halliburton Company Survey Ref: svy1457 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19L 1 Your Ref: API 500292321860 Job No. AKZZ3258923, Surveyed: 10 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) 7187.91 72.380 14.410 3944.40 4013.50 4993.15 N 967.20 W 6014422.81 N 550847.84 E 5064.28 Tie On Point . 7192.00 72.370 14.460 3945.64 4014.74 4996.93 N 966.22 W 6014426.59 N 550848.79 E 1.190 5067.94 Window Point 7266.34 80.150 15.160 3963.28 4032.38 5066.68 N 947.77 W 6014496.47 N 550866.76 E 10.505 5135.53 7317.86 88.150 15.650 3968.53 4037.63 5116.05 N 934.17W 6014545.94 N 550880.02 E 15.557 5183.32 7362.62 89.940 16.070 3969.27 4038.37 5159.10 N 921.94 W 6014589.07 N 550891.95 E 4.108 5224.95 . 7410.84 87.650 16.530 3970.29 4039.39 5205.37 N 908.41 W 6014635.43 N 550905.16 E 4.844 5269.65 7458.30 87.660 16.000 3972.23 4041.33 5250.89 N 895.13 W 6014681.04 N 550918.12 E 1.116 5313.64 7510.57 85.870 13.730 3975.18 4044.28 5301.33 N 881.74 W 6014731.57 N 550931.16 E 5.525 5362.50 7554.96 86.170 12.410 3978.26 4047.36 5344.46 N 871.72 W 6014774.77 N 550940.87 E 3.042 5404.44 7605.29 86.910 10.900 3981.30 4050.40 5393.66 N 861.58 W 6014824.04 N 550950.68 E 3.336 5452.40 7651.27 88.210 11.590 3983.26 4052.36 5438.72 N 852.62 W 6014869.16 N 550959.32 E 3.200 5496.35 7700.55 89.570 8.240 3984.21 4053.31 5487.24 N 844.14 W 6014917.74 N 550967.47 E 7.335 5543.80 7746.91 93.030 4.990 3983.16 4052.26 5533.27 N 838.80 W 6014963.81 N 550972.48 E 10.237 5589.07 7796.22 91.540 4.430 3981.19 4050.29 5582.37 N 834.75 W 6015012.94 N 550976.19 E 3.228 5637.53 7843.43 92.900 3.970 3979.36 4048.46 5629.42 N 831.30 W 6015060.00 N 550979.32 E 3.041 5684.01 7891.91 94.320 3.200 3976.31 4045.41 5677.71 N 828.27 W 6015108.31 N 550982.01 E 3.330 5731.76 7938.56 94.450 1.330 3972.74 4041.84 5724.18 N 826.43 W 6015154.80 N 550983.52 E 4.007 5777.83 7986.66 92.040 359.510 3970.02 4039.12 5772.20 N 826.08 W 6015202.82 N 550983.54 E 6.275 5825.57 8035.07 91.910 358.600 3968.35 4037.45 5820.57 N 826.88 W 6015251.18 N 550982.40 E 1.898 5873.79 8085.48 92.100 358.330 3966.59 4035.69 5870.93 N 828.23 W 6015301.53 N 550980.70 E 0.655 5924.04 8131.21 92.220 357.380 3964.87 4033.97 5916.60 N 829.94 W 6015347.19 N 550978.68 E 2.092 5969.65 8179.80 92.040 356.750 3963.06 4032.16 5965.09 N 832.43 W 6015395.66 N 550975.85 E 1.348 6018.15 . 8227.24 93.210 359.480 3960.89 4029.99 6012.45 N 833.99 W 6015443.01 N 550973.97 E 6.255 6065.43 8274.58 93.270 2.950 3958.21 4027.31 6059.70 N 832.98 W 6015490.26 N 550974.64 E 7.319 6112.35 8324.51 90.930 3.860 3956.38 4025.48 6109.50 N 830.Q2 W 6015540.08 N 550977.26 E 5.028 6161.62 8372.75 90.930 3.090 3955.60 4024.70 6157.65 N 827.10 W 6015588.25 N 550979.84 E 1.596 6209.24 8418.73 91.170 2.770 3954.76 4023.86 6203.56 N 824.75 W 6015634.17 N 550981.88 E 0.870 6254.69 8467.10 89.070 1.730 3954.65 4023.75 6251.89 N 822.85 W 6015682.52 N 550983.44 E 4.845 6302.60 8514.14 88.210 0.600 3955.77 4024.87 6298.90 N 821.89 W 6015729.54 N 550984.07 E 3.018 6349.29 8561.26 91.730 358.360 3955.80 4024.90 6346.01 N 822.32 W 6015776.64 N 550983.31 E 8.854 6396.21 8610.87 92.350 358.610 3954.03 4023.13 6395.57 N 823.63 W 6015826.19 N 550981.66 E 1.347 6445.65 8660.51 90.740 358.530 3952.69 4021.79 6445.18 N 824.87 W 6015875.79 N 550980.07 E 3.247 6495.14 8706.60 90.560 358.350 3952.17 4021.27 6491.25 N 826.12 W 6015921.85 N 550978.50 E 0.552 6541.11 8758.36 90.490 357.100 3951.69 4020.79 6542.96 N 828.18 W 6015973.55 N 550976.08 E 2.419 6592.77 8803.67 90.680 356.830 3951.23 4020.33 6588.21 N 830.58 W 6016018.77 N 550973.37 E 0.729 6638.03 30 September, 2004 - 10:13 Page 2 of5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19L 1 Your Ref: API 500292321860 Job No. AKZZ3258923, Surveyed: 10 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) 8852.69 91.170 356.670 3950.44 4019.54 6637.14 N 833.35 W 6016067.69 N 550970.25 E 1.052 6687.00 8899.98 91.360 356.010 3949.40 4018.50 6684.32 N 836.37 W 6016114.85N 550966.91 E 1.452 6734.25 8947.72 89.070 357.310 3949.22 4018.32 6731.98 N 839.15 W 6016162.48 N 550963.79 E 5.516 6781.95 8993.82 88.390 359.110 3950.24 4019.34 6778.04 N 840.59 W 6016208.53 N 550962.03 E 4.173 6827.93 9042.60 86.910 0.740 3952.24 4021.34 6826.78 N 840.66 W 6016257.27 N 550961.63 E 4.511 6876.43 . 9086.78 86.850 359.970 3954.64 4023.74 6870.89 N 840.38 W 6016301.38 N 550961.60 E 1.746 6920.30 9141.65 86.480 357.870 3957.84 4026.94 6925.65 N 841.42 W 6016356.14 N 550960.19 E 3.880 6974.90 9186.34 86.730 357.170 3960.48 4029.58 6970.22 N 843.35 W 6016400.69 N 550957.95 E 1.661 7019.44 9238.59 87.280 355.010 3963.21 4032.31 7022.28 N 846.90 W 6016452.72 N 550954.03 E 4.260 7071.59 9282.96 87.650 351.940 3965.18 4034.28 7066.31 N 851.94 W 6016496.72 N 550948.68 E 6.962 7115.91 9333.79 88.150 348.550 3967.04 4036.14 7116.37 N 860.55 W 6016546.71 N 550939.73 E 6.737 7166.57 9380.33 87.040 352.490 3968.99 4038.09 7162.22 N 868.20 W 6016592.51 N 550931.75 E 8.788 7212.96 9431 .27 86.980 353.150 3971.65 4040.75 7212.69 N 874.56 W 6016642.94 N 550925.04 E 1.299 7263.81 9473.53 87.100 350.500 3973.83 4042.93 7254.46 N 880.56 W 6016684.67 N 550918.75 E 6.269 7305.97 9524.40 86.970 346.870 3976.46 4045.56 7304.27 N 890.53 W 6016734.40 N 550908.44 E 7.131 7356.52 9570.36 86.670 343.230 3979.02 4048.12 7348.60 N 902.37 W 6016778.65 N 550896.30 E 7.935 7401.80 9620.87 87.960 340.460 3981.38 4050.48 7396.53 N 918.09 W 6016826.47 N 550880.24 E 6.044 7451.05 9666.50 87.780 337.230 3983.08 4052.18 7439.05 N 934.54 W 6016868.88 N 550863.50 E 7.085 7494.99 9717.02 89.260 334.180 3984.38 4053.48 7485.08 N 955.32 W 6016914.76 N 550842.40 E 6.708 7542.84 9763.08 88.640 331.870 3985.23 4054.33 7526.12 N 976.20 W 6016955.65 N 550821.23 E 5.192 7585.74 9815.24 88.150 327.840 3986.69 4055.79 7571.20 N 1002.38 W 6017000.54 N 550794.74 E 7.780 7633.19 9859.31 87.410 324.840 3988.40 4057.50 7607.84 N 1026.79 W 6017037.02 N 550770.08 E 7.006 7672.07 . 9913.36 88.890 321.140 3990.14 4059.24 7650.97 N 1059.30 W 6017079.92 N 550737.27 E 7.369 7718.20 9955.84 87.780 318.920 3991.38 4060.48 7683.51 N 1086.57 W 6017112.27 N 550709.77 E 5.841 7753.27 10006.05 86.970 315.360 3993.68 4062.78 7720.27 N 1120.68 W 6017148.80 N 550675.40 E 7.264 7793.22 10051.93 87.290 310.710 3995.97 4065.07 7751.54 N 1154.17 W 6017179.82 N 550641.70 E 10.146 7827.64 10098.92 89.630 306.820 3997.24 4066.34 7780.94 N 1190.79W 6017208.97 N 550604.88 E 9.658 7860.52 10144.80 91.230 304.390 3996.89 4065.99 7807.65 N 1228.08 W 6017235.42 N 550567.40 E 6.341 7890.78 10195.58 90.560 299.340 3996.10 4065.20 7834.44 N 1271.19 W 6017261.91 N 550524.10 E 10.031 7921.70 10245.11 89.810 294.790 3995.94 4065.04 7856.97 N 1315.29 W 6017284.14 N 550479.85 E 9.310 7948.48 10294.83 89.810 293.320 3996.10 4065.20 7877.24 N 1360.69 W 6017304.09 N 550434.31 E 2.957 7973.13 10339.49 90.310 291.780 3996.06 4065.16 7894.36 N 1401.93 W 6017320.93 N 550392.95 E 3.625 7994.25 10387.71 89.510 290.860 3996.13 4065.23 7911.90 N 1446.85 W 6017338.15 N 550347.91 E 2.528 8016.13 10434.17 85.490 287.510 3998.16 4067.26 7927.14 N 1490.67 W 6017353.09 N 550303.98 E 11 .258 8035.64 10487.22 87.900 284.800 4001.22 4070.32 7941.88 N 1541.53W 6017367.47 N 550253.02 E 6.830 8055.32 30 September, 2004 - 10:13 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19L 1 Your Ref: API 500292321860 Job No. AKZZ3258923, Surveyed: 10 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) (o/100ft) 10532.30 88.210 283.030 4002.75 4071.85 7952.71 N 1585.26 W 6017378.00 N 550209.22 E 3.984 8070.42 10583.15 90.000 282.560 4003.54 4072.64 7963.97 N 1634.84 W 6017388.91 N 550159.56 E 3.639 8086.53 10628.06 90.190 282.460 4003.47 4072.57 7973.70 N 1678.69 W 6017398.34 N 550115.65 E 0.478 8100.54 10680.91 90.120 282.020 4003.33 4072.43 7984.90 N 1730.33 W 6017409.18 N 550063.92 E 0.843 8116.79 10722.76 91.610 282.400 4002.69 4071.79 7993.75 N 1771.23W 6017417.75 N 550022.97 E 3.674 8129.64 . 10777.33 93.330 281.240 4000.34 4069.44 8004.92 N 1824.59 W 6017428.54 N 549969.53 E 3.801 8146.02 10819.25 92.960 278.690 3998.04 4067.14 8012.16N 1865.81 W 6017435.50 N 549928.26 E 6.138 8157.30 10869.32 92.530 276.720 3995.64 4064.74 8018.87 N 1915.37 W 6017441.86 N 549878.65 E 4.023 8168.87 10915.72 90.740 277.310 3994.32 4063.42 8024.53 N 1961.40 W 6017447.20 N 549832.58 E 4.062 8179.06 10966.62 90.490 277.610 3993.77 4062.87 8031.14 N 2011.87 W 6017453.46 N 549782.07 E 0.767 8190.62 11010.44 90.190 277.750 3993.51 4062.61 8037.00 N 2055.30 W 6017459.01 N 549738.61 E 0.755 8200.73 11061.32 90.190 275.820 3993.35 4062.45 8043.01 N 2105.82 W 6017464.67 N 549688.05 E 3.793 8211.71 11107.70 89.440 277.740 3993.50 4062.60 8048.48 N 2151.87 W 6017469.83 N 549641.96 E 4.444 8221.71 11158.93 89.380 277.660 3994.02 4063.12 8055.35 N 2202.64 W 6017476.34 N 549591.14 E 0.195 8233.55 11203.42 90.930 277.780 3993.90 4063.00 8061.32 N 2246.72 W 6017482.01 N 549547.02 E 3.494 8243.85 11254.44 90.860 277.840 3993.11 4062.21 8068.25 N 2297.26 W 6017488.59 N 549496.43 E 0.181 8255.75 11300.72 90.800 276.830 3992.44 4061.54 8074.16 N 2343.16 W 6017494.18 N 549450.50 E 2.186 8266.16 11350.51 90.490 276.890 3991.87 4060.97 8080.11 N 2392.59 W 6017499.78 N 549401.03 E 0.634 8276.96 11394.61 90.060 274.930 3991.66 4060.76 8084.65 N 2436.45 W 6017504.01 N 549357.13 E 4.550 8285.81 11446.55 90.310 277.650 3991.50 4060.60 8090.34 N 2488.07 W 6017509.35 N 549305.47 E 5.259 8296.58 11492.20 92.470 278.630 3990.39 4059.49 8096.80 N 2533.25 W 6017515.49 N 549260.25 E 5.196 8307.47 11543.39 92.040 277.980 3988.37 4057.47 8104.19 N 2583.86 W 6017522.53 N 549209.59 E 1.522 8319.82 . 11587.16 91.850 276.620 3986.89 4055.99 8109.75 N 2627.25 W 6017527.79 N 549166.16 E 3.136 8329.64 11635.97 91.420 278.730 3985.50 4054.60 8116.26N 2675.60 W 6017533.97 N 549117.77 E 4.410 8340.90 11683.03 92.530 280.060 3983.87 4052.97 8123.94 N 2722.00 W 6017541.32 N 549071.32 E 3.680 8353.12 11729.96 93.090 279.730 3981.57 4050.67 8131.99 N 2768.17 W 6017549.05 N 549025.09 E 1.385 8365.70 11778.98 91.790 281.750 3979.49 4048.59 8141.12 N 2816.29 W 6017557.84 N 548976.91 E 4.897 8379.54 11826.87 91.480 280.990 3978.12 4047.22 8150.56 N 2863.22 W 6017566.96 N 548929.92 E 1.713 8393.56 11875.26 91.110 280.930 3977.03 4046.13 8159.76 N 2910.71 W 6017575.82 N 548882.36 E 0.775 8407.41 11924.34 90.680 280.140 3976.26 4045.36 8168.73 N 2958.96 W 6017584.46 N 548834.05 E 1.832 8421.10 11972.11 90.490 280.640 3975.77 4044.87 8177.34 N 3005.95 W 6017592.75 N 548787.01 E 1.120 8434.32 12019.93 90.120 280.030 3975.52 4044.62 8185.92 N 3052.99 W 6017601.00 N 548739.91 E 1 .492 8447.50 12067.21 89.750 279.400 3975.57 4044.67 8193.90 N 3099.59 W 6017608.65 N 548693.25 E 1.545 8460.05 12116.56 89.380 279.530 3975.94 4045.04 8202.02 N 3148.27 W 6017616.43 N 548644.52 E 0.795 8472.93 12152.50 90.060 279.850 3976.12 4045.22 8208.06 N 3183.69 W 6017622.23 N 548609.05 E 2.091 8482.45 30 September, 2004 - 10:13 Page 4 of5 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19L 1 Your Ref: API 500292321860 Job No. AKZZ3258923, Surveyed: 10 September, 2004 Milne Point Unit Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) .- 12225.00 90.060 279.850 3976.04 4045.14 Local Coordinates Northin9s Eastin9s (ft) (ft) Global Coordinates Northin9s Eastings (ft) (ft) 8220.47 N 3255.12 W 6017634.14 N 548537.53 E 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 12225.00ft., The Bottom Hole Displacement is 8841.49ft., in the Direction of 338.398° (True). Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastin9s (ft) (ft) (ft) Comment 7187.91 7192.00 12225.00 Tie On Point Window Point Projected Survey 4013.50 4014.74 4045.14 4993.15 N 4996.93 N 8220.47 N 967.20 W 966.22 W 3255.12 W Survey tool program for MPI-19L 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 447.00 0.00 446.83 447.00 12225.00 446.83 CB-SS-GYRO (MPI-19PB1) 4045.14 MWD+IIFR+MS (MPI-19PB1) BPXA Dogleg Vertical Rate Section Comment (o/100ft) 0.000 8501.85 Projected Survey . . 30 September, 2004 - 10:13 Page 5 of 5 DrillQuest 3.03.06.006 . . AOGCC ~ Deason - 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-19 L 1 MWD /O/léJ 7 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: 7,187.91' MD 7,192.00' MD 12,225.00' 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 /t!J~~¡:: ..- / Please call me at 273-3545 if you have any qu stions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ÂD v/-/3G Halliburton Sperry-Sun Milne Point Unit BPXA . Milne Point MPI MPI-19L 1 (rowd) 2004 Job No. AKMW3258923, Surveyed: 5 September, Survey Report 2004 30 September, . Your Ref: API 500292321860 Surface Coordinates: 6009436.50 N, 551849.73 E (70· 26'11.4861" N, 149· 34' 38.1394" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy1479 11\1 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!I'""I'"""Y-SUf1 IL.L.tN_G SE:FHIICeS A Halliburton Company Halliburton Sperry-Sun Survey Report for Milne Point MPI - MPI-19L 1 (mwd) Your Ref: API 500292321860 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) (o/100ft) 7187.91 72.380 14.560 3944.40 4013.50 5007.01 N 906.00 W 6014437.09 N 550908.95 E 5072.03 Tie On Point 7192.00 72.370 14.460 3945.64 4014.74 5010.78 N 905.02 W 6014440.87 N 550909.90 E 2.343 5075.68 Window Point 7266.34 80.150 15.160 3963.28 4032.38 5080.54 N 886.57 W 6014510.76 N 550927.86 E 10.505 5143.28 7317.86 88.150 15.650 3968.53 4037.63 5129.91 N 872.96 W 6014560.22 N 550941.12 E 15.557 5191.06 7362.62 89.940 18.220 3969.28 4038.38 5172.72 N 859.93 W 6014603.12 N 550953.86 E 6.996 5232.37 . 7410.84 87.650 17.000 3970.29 4039.39 5218.67 N 845.34 W 6014649.16 N 550968.13 E 5.381 5276.65 7458.30 87.660 16.580 3972.23 4041.33 5264.06 N 831.65 W 6014694.66 N 550981.51 E 0.884 5320.48 7510.57 85.870 14.310 3975.18 4044.28 5314.36 N 817.75 W 6014745.05 N 550995.05 E 5.525 5369.15 7554.96 86.170 13.000 3978.26 4047.36 5357.39 N 807.29 W 6014788.15 N 551005.21 E 3.021 5410.94 7605.29 86.910 11.770 3981.30 4050.40 5406.46 N 796.52 W 6014837.29 N 551015.64 E 2.848 5458.70 7651.27 88.210 12.520 3983.26 4052.36 5451.37 N 786.86 W 6014882.27 N 551024.99 E 3.263 5502.44 7700.55 89.570 8.800 3984.21 4053.31 5499.78 N 777.74 W 6014930.74 N 551033.77 E 8.036 5549.71 7746.91 93.030 6.240 3983.16 4052.26 5545.72 N 771.68 W 6014976.72 N 551039.52 E 9.283 5594.83 7796.22 91.540 5.450 3981.20 4050.30 5594.73 N 766.66 W 6015025.77 N 551044.19 E 3.420 5643.10 7843.43 92.900 4.500 3979.37 4048.47 5641.73 N 762.57 W 6015072.79 N 551047.96 E 3.513 5689.46 7891.91 94.320 4.900 3976.31 4045.41 5689.95 N 758.61 W 6015121.03 N 551051.58 E 3.043 5737.06 7938.56 94.450 1.960 3972.75 4041.85 5736.37 N 755.82 W 6015167.48 N 551054.04 E 6.290 5782.98 7986.66 92.040 0.310 3970.02 4039.12 5784.38 N 754.87 W 6015215.49 N 551054.66 E 6.069 5830.66 8035.07 91.910 359.360 3968.36 4037.46 5832.76 N 755.01 W 6015263.87 N 551054.19 E 1.980 5878.82 8085.48 92.100 359.100 3966.59 4035.69 5883.13 N 755.69 W 6015314.24 N 551053.16 E 0.639 5929.01 8131.21 92.220 358.180 3964.87 4033.97 5928.82 N 756.77 W 6015359.91 N 551051.76 E 2.027 5974.58 8179.80 92.040 357.490 3963.06 4032.16 5977.34 N 758.61 W 6015408.42 N 551049.58 E 1 .467 6023.04 . 8227.24 93.210 0.120 3960.89 4029.99 6024.71 N 759.60 W 6015455.79 N 551048.27 E 6.062 6070.29 8274.58 93.270 3.500 3958.21 4027.31 6071.95 N 758.10 W 6015503.03 N 551049.43 E 7.130 6117.14 8324.51 90.930 3.940 3956.38 4025.48 6121.74N 754.87 W 6015552.84 N 551052.32 E 4.769 6166.36 8372.75 90.930 3.540 3955.60 4024.70 6169.87 N 751.72 W 6015600.99 N 551055.13 E 0.829 6213.95 8418.73 91.170 3.460 3954.76 4023.86 6215.75 N 748.91 W 6015646.90 N 551057.62 E 0.550 6259.33 8467.10 89.070 2.360 3954.66 4023.76 6264.06 N 746.46 W 6015695.22 N 551059.74 E 4.901 6307.16 8514.14 88.210 1.200 3955.77 4024.87 6311.06 N 745.00 W 6015742.23 N 551060.87 E 3.069 6353.79 8561.26 91.730 358.900 3955.80 4024.90 6358.17 N 744.96 W 6015789.34 N 551060.59 E 8.923 6400.66 8610.87 92.350 359.070 3954.03 4023.13 6407.74 N 745.84 W 6015838.90 N 551059.36 E 1.296 6450.08 8660.51 90.740 358.960 3952.69 4021.79 6457.35 N 746.69 W 6015888.51 N 551058.17 E 3.251 6499.53 8706.60 90.560 358.990 3952.17 4021.27 6503.43 N 747.51 W 6015934.58 N 551057.02 E 0.396 6545.47 8758.36 90.490 357.740 3951.70 4020.80 6555.17 N 748.99 W 6015986.30 N 551055.19 E 2.419 6597.10 8803.67 90.680 357.430 3951.23 4020.33 6600.44 N 750.90 W 6016031.56 N 551052.96 E 0.802 6642.33 30 September, 2004 - 10:12 Page 2 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI - MPI-19L 1 (mwd) Your Ref: API 500292321860 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) 8852.69 91.170 357.180 3950.44 4019.54 6649.39 N 753.20 W 6016080.50 N 551050.32 E 1.122 6691.28 8899.98 91.360 356.590 3949.40 4018.50 6696.60 N 755.77 W 6016127.69 N 551047.42 E 1.310 6738.51 8947.72 89.070 357.860 3949.22 4018.32 6744.28 N 758.08 W 6016175.35 N 551044.78 E 5.485 6786.18 8993.82 88.390 359.620 3950.24 4019.34 6790.36 N 759.10 W 6016221.42 N 551043.44 E 4.092 6832.13 9042.60 86.910 1.290 3952.24 4021.34 6839.09 N 758.71 W 6016270.15 N 551043.49 E 4.572 6880.59 . 9086.78 86.850 0.480 3954.65 4023.75 6883.20 N 758.03 W 6016314.27 N 551043.87 E 1.836 6924.42 9141.65 86.480 358.440 3957.84 4026.94 6937.97 N 758.54 W 6016369.03 N 551042.97 E 3.772 6978.97 9186.34 86.730 357.820 3960.49 4029.59 6982.56 N 760.00 W 6016413.61 N 551041.20 E 1 .494 7023.49 9238.59 87.280 355.620 3963.22 4032.32 7034.65 N 762.99 W 6016465.68 N 551037.86 E 4.335 7075.61 9282.96 87.650 352.770 3965.18 4034.28 7078.74 N 767.47 W 6016509.74 N 551033.07 E 6.471 7119.94 9333.79 88.150 349.410 3967.04 4036.14 7128.92 N 775.34 W 6016559.86 N 551024.85 E 6.679 7170.64 9380.33 87.040 353.340 3969.00 4038.10 7174.88 N 782.31 W 6016605.77 N 551017.56 E 8.767 7217.07 9431 .27 86.980 353.950 3971.65 4040.75 7225.44 N 787.94 W 6016656.29 N 551011.58 E 1.202 7267.94 9473.53 87.100 351.350 3973.83 4042.93 7267.29 N 793.34 W 6016698.10 N 551005.89 E 6.151 7310.12 9524.40 86.970 347.960 3976.47 4045.57 7317.26 N 802.46 W 6016748.01 N 550996.42 E 6.660 7360.75 9570.36 86.670 344.460 3979.02 4048.12 7361.82 N 813.40 W 6016792.49 N 550985.17 E 7.632 7406.17 9620.87 87.960 341.760 3981.38 4050.48 7410.10 N 828.05 W 6016840.66 N 550970.18 E 5.919 7455.65 9666.50 87.780 338.600 3983.08 4052.18 7452.99 N 843.51 W 6016883.44 N 550954.42 E 6.932 7499.86 9717.02 89.260 335.710 3984.39 4053.49 7499.52 N 863.12 W 6016929.84 N 550934.50 E 6.425 7548.11 9763.08 88.640 333.270 3985.23 4054.33 7541.08 N 882.95 W 6016971.26 N 550914.38 E 5.465 7591.42 9815.24 88.150 329.270 3986.69 4055.79 7586.79 N 908.01 W 6017016.80 N 550889.00 E 7.723 7639.38 9859.31 87.410 326.310 3988.40 4057.50 7624.05 N 931.48 W 6017053.89 N 550865.27 E 6.918 7678.78 . 9913.36 88.890 322.640 3990.14 4059.24 7668.01 N 962.86 W 6017097.63 N 550833.58 E 7.318 7725.62 9955.84 87.780 320.450 3991.38 4060.48 7701.26 N 989.26 W 6017130.69 N 550806.95 E 5.778 7761.31 10006.05 86.970 317.000 3993.68 4062.78 7738.95 N 1022.35 W 6017168.15 N 550773.61 E 7.051 7802.09 10051.93 87.290 312.490 3995.98 4065.08 7771.19 N 1054.88 W 6017200.17 N 550740.85 E 9.842 7837.39 10098.92 89.630 308.560 3997.24 4066.34 7801.71 N 1090.58 W 6017230.44 N 550704.94 E 9.731 7871.28 10144.80 91.230 306.370 3996.90 4066.00 7829.61 N 1126.99W 6017258.09 N 550668.33 E 5.911 7902.65 10195.58 90.560 301.570 3996.10 4065.20 7857.97 N 1169.09 W 6017286.16 N 550626.04 E 9.543 7935.03 1 0245.11 89.810 297.330 3995.94 4065.04 7882.32 N 1212.21 W 6017310.20 N 550582.75 E 8.693 7963.52 10294.83 89.810 296.150 3996.11 4065.21 7904.69 N 1256.61 W 6017332.26 N 550538.20 E 2.373 7990.17 10339.49 90.310 295.230 3996.06 4065.16 7924.05 N 1296.85 W 6017351.34 N 550497.82 E 2.345 8013.41 10387.71 89.510 293.830 3996.14 4065.24 7944.07 N 1340.72 W 6017371.06 N 550453.81 E 3.344 8037.66 10434.17 85.490 290.880 3998.16 4067.26 7961.72 N 1383.63 W 6017388.41 N 550410.78 E 10.728 8059.47 10487.22 87.900 287.620 4001.22 4070.32 7979.17 N 1433.62 W 6017405.51 N 550360.67 E 7.633 8081.78 30 September, 2004 - 10:12 Page 3 of5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19L 1 (mwd) Your Ref: API 500292321860 Job No. AKMW3258923, Surveyed: 5 September, 2004 BPXA Milne Point Unit Measured True Sub-5ea 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) 10532.30 88.210 285.670 4002.75 4071.85 7992.08 N 1476.79 W 6017418.12 N 550317.42 E 4.377 8098.88 10583.15 90.000 285.370 4003.55 4072.65 8005.68 N 1525.78 W 6017431.38 N 550268.33 E 3.569 8117.26 10628.06 90.190 284.970 4003.47 4072.57 8017.44 N 1569.12W 6017442.83 N 550224.91 E 0.986 8133.24 10680.91 90.120 284.380 4003.33 4072.43 8030.82 N 1620.25 W 6017455.87 N 550173.69 E 1.124 8151.61 10722.76 91.610 283.990 4002.70 4071.80 8041.08 N 1660.81 W 6017465.84 N 550133.05 E 3.680 8165.82 . 10777.33 93.330 283.100 4000.35 4069.45 8053.85 N 1713.81 W 6017478.24 N 550079.96 E 3.548 8183.77 10819.25 92.960 280.220 3998.04 4067.14 8062.30 N 1754.80 W 6017486.41 N 550038.92 E 6.916 8196.23 10869.32 92.530 278.650 3995.65 4064.75 8070.50 N 1804.14 W 6017494.27 N 549989.53 E 3.248 8209.26 10915.72 90.740 279.220 3994.32 4063.42 8077.71 N 1849.95 W 6017501.15 N 549943.66 E 4.048 8220.96 10966.62 90.490 279.190 3993.78 4062.88 8085.85 N 1900.20 W 6017508.94 N 549893.37 E 0.495 8234.02 11010.44 90.190 277.990 3993.52 4062.62 8092.39 N 1943.52 W 6017515.19 N 549849.99 E 2.823 8244.82 11061.32 90.190 277.340 3993.35 4062.45 8099.18 N 1993.95 W 6017521.62 N 549799.52 E 1.278 8256.55 11107.70 89.440 279.200 3993.50 4062.60 8105.85 N 2039.84 W 6017527.97 N 549753.58 E 4.324 8267.73 11158.93 89.380 278.730 3994.03 4063.13 8113.83N 2090.44 W 6017535.60 N 549702.93 E 0.925 8280.67 11203.42 90.930 278.890 3993.90 4063.00 8120.65 N 2134.41 W 6017542.11 N 549658.92 E 3.502 8291.79 11254.44 90.860 278.830 3993.11 4062.21 8128.50 N 2184.81 W 6017549.62 N 549608.46 E 0.181 8304.59 11300.72 90.800 277.770 3992.44 4061.54 8135.18 N 2230.60 W 6017555.98 N 549562.62 E 2.294 8315.76 11350.51 90.490 277. 790 3991.88 4060.98 8141.92 N 2279.93 W 6017562.38 N 549513.25 E 0.624 8327.34 11394.61 90.060 276.010 3991.67 4060.77 8147.22 N 2323.71 W 6017567.37 N 549469.44 E 4.152 8336.94 11446.55 90.310 278.920 3991.50 4060.60 8153.97 N 2375.20 W 6017573.76 N 549417.90 E 5.623 8348.74 11492.20 92.470 280.100 3990.39 4059.49 8161.51 N 2420.21 W 6017580.98 N 549372.84 E 5.391 8360.69 11543.39 92.040 279.390 3988.38 4057.48 8170.17 N 2470.62 W 6017589.29 N 549322.37 E 1.621 8374.29 . 11587.16 91.850 278.390 3986.89 4055.99 8176.93 N 2513.84 W 6017595.75 N 549279.10 E 2.324 8385.28 11635.97 91.420 280.970 3985.50 4054.60 8185.13 N 2561.93 W 6017603.62 N 549230.96 E 5.357 8398.20 11683.03 92.530 282.320 3983.88 4052.98 8194.62 N 2607.99 W 6017612.79 N 549184.83 E 3.713 8412.20 11729.96 93.090 281.910 3981.57 4050.67 8204.46 N 2653.82 W 6017622.31 N 549138.93 E 1.478 8426.51 11778.98 91.790 283.870 3979.49 4048.59 8215.38 N 2701.56 W 6017632.90 N 549091.12 E 4.795 8442.10 11826.87 91.480 282.890 3978.12 4047.22 8226.46 N 2748.13 W 6017643.66 N 549044.47 E 2.146 8457.73 11875.26 91.110 282.880 3977.03 4046.13 8237.25 N 2795.29 W 6017654.12 N 548997.24 E 0.765 8473.12 11924.34 90.680 282.390 3976.26 4045.36 8247.98 N 2843.18 W 6017664.52 N 548949.28 E 1.328 8488.53 11972.11 90.490 282.310 3975.77 4044.87 8258.20 N 2889.84 W 6017674.41 N 548902.55 E 0.432 8503.31 12019.93 90.120 281.330 3975.52 4044.62 8268.00 N 2936.64 W 6017683.88 N 548855.68 E 2.191 8517.68 12067.21 89.750 280.700 3975.57 4044.67 8277.03 N 2983.05 W 6017692.59 N 548809.21 E 1.545 8531.26 12116.56 89.380 280.600 3975.95 4045.05 8286.15 N 3031.55 W 6017701.37 N 548760.65 E 0.777 8545.12 12152.50 90.060 280.790 3976.12 4045.22 8292.82 N 3066.86 W 6017707.80 N 548725.29 E 1.965 8555.25 30 September, 2004 - 10:12 Page 4 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-19L 1 (mwd) Your Ref: API 500292321860 Job No. AKMW3258923, Surveyed: 5 September, 2004 Milne Point Unit Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12225.00 90.060 280.790 3976.05 4045.15 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 8306.39 N 3138.08 W 6017720.87 N 548653.98 E 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 12225.00ft., The Bottom Hole Displacement is 8879.40ft., in the Direction of 339.304° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7187.91 7192.00 12225.00 4013.50 4014.74 4045.15 5007.01 N 5010.78 N 8306.39 N 906.00 W 905.02 W 3138.08 W Tie On Point Window Point Projected Survey Survey tool prOf/ram for MPI-19L 1 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 447.00 446.83 CB-SS-GYRO (MPI-19PB1 (mwd)) 4045.15 MWD Magnetic (MPI-19PB1 (mwd)) 0.00 447.00 446.83 12225.00 BPXA Dogleg Vertical Rate Section Comment (0/100ft) 0.000 8575.79 Projected Survey . . 30 September, 2004 - 10:12 Page 50f5 DríllQuest 3.03.06.006 e ',< ~ ~æ· AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 477.02 Mr. Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 96612 Anchorage, AK 99519-6612 Re: Spacing Exception for Milne Point Unit I-19Ll Well (Permit No. 204-136) Dear Mr. Archey: On July 28, 2004, the Alaska Oil and Gas Conservation Commission ("Commission") received correspondence from BP Exploration (Alaska) Inc. ("BPXA"), dated July 27, 2004, requesting an exception to statewide spacing requirements for drilling and operation of Milne Point Unit ("MPU") I-19Ll. On August 18, 2004, the Commission received additional supporting information from BPXA conceming MPU I-19Ll. This horizontal, multilateral well bore will originate from the MPU 1-19 production well. In MPU 1-19L1, the top of the productive interval will lie 2,023 feet from the south line and 4,497 feet from the east line of Section 28, T13N, RlOE, Umiat Meridian ("UM"). The bottom hole location will be 5,260 feet from the south line and 1,487 feet from the east line of Section 29, T13N, RIOE, UM. The top of the productive interval in this well bore will lie within state lease ADL 025906, and the total depth of the well bore will lie in state lease ADL 025517. MPU I-19L1 will open the Schrader Bluff Oil Pool ("pool") to production, and will approach within approximately 200 feet of existing well MPU J-09A, which is open to the same reservoir sand within the pool. The operator reports MPU J-09A no longer communicates with the reservoir due to sand plugging, and it is not feasible to return the well to regular production. MPU J-19L1 is designed to access the same reserves as MPU J-09A. MPU 1-19L1 will also approach within 500 feet of state leases ADL 025515 and ADL 025516. Well spacing in the pool within Sections 28 and 29 ofT13N, RIOE, UM is regulated by Rule 2 of Conservation Order 477 ("CO 477"), which supersedes the statewide spacing requirements of 20 AAC 25.055. An exception to the spacing requirements of CO 477, Rule 2 is required as MPU I-19L1 will open the pool within two of the same governmental quarter-quarter-quarter sections as existing well MPU J -09 A. e e . . CO 477.02 September 8, 2004 Page 2 of2 Rule 11 of CO 477 states: "Unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater." Administrative approval is appropriate for an exception to the well spacing requirements specified in CO 477. Notice and public hearing are not required for this spacing exception as MPU I-19Ll will not jeopardize correlative rights. The affected state leases, ADL 025906 and ADL 025517, and adjacent state leases ADL 025515 and ADL 025516 have the same owners and landowners, and they are committed to the MPU and to the Schrader Bluff Participating Area ("SBPA"). MPU 1-19Ll will lie more than 500 feet from the exterior boundaries of the MPU and the SBP A. The Commission has determined drilling and operation of MPU 1-19Ll production well bore will not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. The Commission hereby approves the drilling and operation of the Milne Point Unit 1-19Ll well bore as proposed. DONE at Anchorage, Alaska and dated September 8, 2004. Daniel T. Seamount, Jr. Commissioner .-;;;:: ,. ~. . . FRANK H. MURKOWSKI, GOVERNOR AI..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-19Ll BP Exploration (Alaska) Inc. Pennit No: 204-136 Surface Location: 2319' NSL, 3521' WEL, SEC. 33, T13N, RIOE, UM Bottomhole Location: 5260' NSL, 1487' WEL, SEC. 29, T13N, RlOE, UM (OA) Dear Mr. Archey: Enclosed is the approved application for pennit to redrill the above development well. The pennit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska) Inc. assumes the liability of any protest to the spacing exception that may occur. This pennit to redrill does not exempt you trom obtaining additional pennits 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 pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission witness any required test. Contact the Commission's petroleum field inspector at 65 -3 (pager). BY ORDER OF THE COMMISSION DATED thi~ day of July, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. 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)(1) 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 fir;t 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, !úf;r RECE JUL 2 0 2004 Drilling Engineer BP Exploration (Alaska) Inc. Aiaska OJI · STATE OF ALASKA . ALASKA AND GAS CONSERVATION COMIVJISSION PERMIT TO DRILL 20 MC 25.005 ~~ D Drill III Redrill 1 a. Type of work D 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 / Top of Productive Horizon: 2023' NSL, 4497' WEL, SEC. 28, T13N, R10E, UM (OA) Total Depth: 5260' NSL, 1487' WEL, SEC. 29, T13N, R10E, UM (OA) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551850 / y- 6009437 /' Zone- ASP4 16. Deviated Wells: Kickoff Depth: 7187 / feet Maximum Hole Angle: 92 dearees 1b. Current Well Class D Exploratory III Development Oil D Multiple Zone D Stratigraphic Test D Service D Development Gas D Single Zone 5. Bond: a Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPI-19L 1 6. Proposed DeptÞ: 12. Field I Pool(s): MD 122531( /' TVD 4054" Milne Point Unit I Schrader Bluff 7. Property Designation: )f> 1};í:~'JlYnlJ.... ADL 025517 '7.2.(.0'1 8. Land Use Permit: 13. Approximate Spud Date: 08/10104 9. Acres in Property: 2560 14. Distance to Nearest Property: 7000' 18. Casing Program: Size Casino 4-1/2" Hole 6-3/4" Weiaht 12.6# 10. KB Elevation KBE = 15. Distance to Nearest Well Within Pool (Height above GL): 69.3' feet 200' away from MPJ-09A 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1875/ Surface: 1467 / ~..tt;nnh¡¡"nl-h'i,ii I.' TeDiBot om Couolina Lenath MD TVD MD TVD BTC 5166' 7087' 3996' 12253' 4054' ,'" lincludina staQe data) Uncemented Slotted Liner Grade L-80 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): 9722' 4119' None 9722' 4119' None Casing Length Size .. ~. 'VIJ Conductor 80' 20" 260 sx Arctic Set lADorox.) 114' . 2515' 10-3/4" 397 sx AS Lite, 257 sx Class 'G' 2545' IntArmAdi::ltA Production 7440' 7-5/8" 755 sx Class 'G' 7470' I ¡nAr 2385' 4-1/2" Uncemented Slotted Liner 7337' - 9722' 114' 2319' 4079' 4054' - 4119' 20. Attachments 0 Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): None a Dlrilling Program 0 Time vs Depth Plot o Seabed Report a Drilling Fluid Program a Shallow Hazard Analysis a 20 AAC 25.050 Requirements Perforation Depth MD (ft): None 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Skip Coyner, 564-4395 Printed Name Pat Archey Title Senior Drilling Engineer D // /. ¡ Prepared By Name/Number: SiQnature r · š (L_OrA L/ Phone 564-5803 Date 7/ / .., /D 'i Sondra Stewman, 564-4750 '·'i',/~ ii". .>.'". . ,... .iii,."··i.i·····g.Ù>.~i>..'5i'.?/,iiij.i ;..".i'i Permit To Drill J I "2../ IAPI Number: Ö / Permit Approval I See cover letter for Number: .2Ð'í,J ...Ib 50-D2-'1- 2.,32/ D ~ ~O Date:7/.3%)? I other requirements Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required 0 Yes @'No Other: ~ \~. \ ~~~k:~\::j~y;;:~\..~::~a::~~:~~:~~~:'f c.~¡O'bð . (( 11 I A APPROVED BY '2. r,?" / " / ...../ Aooroved BvT V I THE COMMISSION Date T).;;µ)/ O'-r' Form 10-401 R~ed 06~ U K I GIN A L -Bubnrft In Dl6plicate . . - bp I Well Name: I MPI-19 L-1 (Dual-Lateral) I Primary Wellbore & OB Lateral Drill and Complete Plan Summary I Type of Well: Surface Location: (As Built) I Schrader Bluff Dual-Lateral Producer 2319' FSL, 2961' FNL, 3521' FEL, 1759' FWL SEC. 33, T13N, R10E ;' E = 551850'/N = 6009437' Elevation OF = 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' TVO 2720' FSL, 752' FNL, 1610' FEL, 1035' FNL SEC. 32, T13N, R10E E = 551055' N = 6016918' Z = 4119' TVO 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 7-5/8" Casina Point: T/OB sand (Heel) 7470' MD OB Lateral: T lOB sand (Heel) 7470' MD OB Lateral. BHL: DB 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 Pro ert Distance to nearest AFE Number: Estimated Start Date: August 10, 2004 1 . CasingfTubing Program . Hole Csg I Tbg Wt/Ft Grade Conn Length Top Bottom Size O.D. MD I TVD MD ITVD 42" 20-in* 92# H-40 Welded 80' 34' 114' /114' 13-1/2" 1 O. 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 L-80 BTC 2,385' 7,337' /4,054' 9,722' /4,119' OB Slotted 12.6# 6-3/4" 4.5-in L-80 BTC 5,166' 7,087' / 3,996' 12,253' / 4,054' Slotted 12.6# OA Mud Program: YP 25 - 30 LSND API Filtrate LG Solids < 6 < 15 LSND API Filtrate LG Solids < 6 < 15 MOBM API Filtrate LG Solids < 6 < 15 6-3/4" OA Production Hole ( 7187' -12253'): MOBM Densitv (OuL'" PV VP HTHP pH API Filtrate LG Solids 9.0 - 9.4 i 15 - 25 18 - 25 10-11 9.0- 9.5 <6 <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 - 600 306 6-3/4" 7,470' - 9,722' 2,252' PDC .30 - .50 275 - 325 3ÜA 6-3/4" 7,187' - 12,253' 5,066' PDC .30 - .50 275 - 325 2 . Cement Program: . Casin Size Basis 10-3/4",45.5#, L-80, BTC Casin 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 S acer Lead Tail Tern 20 bbl water Casing Size 7-5/8",29.7#, L-80, BTC-M Intermediate Casing at 7,470' MD Basis Top of cement to be 500' MO above Ugnu sands [TOC = 4,625' MO] + 40% excess. Shoe Joint = 85 ft [7,385' to 7,470' MO] Total Cement Wash 5-bbl water Volume: 156 bbl 25 bbl CW 100 Spacer 35 bbl of MudPush Tail 156 bbl, 755 sx "G" mixed at 15.8 Ib/Qal& 1.16 fe/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 j OA owe 4,159 on owe 4,214 3 . . E I r p va ua Ion rogram: 13-1/2" Section Open Hole: MWD/GR IFR/CASANDRA Sperry InSite Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES IFRlCASANDRA Sperry InSite 6-3/4" Sections Open Hole: MWD/GRlRESI ABI/PWD IFRlCASANDRA Sperry InSite Well Control: Intermediate/Production hole: · Maximum anticipated BHP: · Maximum surface pressure: · BOP test pressure: · BOP Test Interval: 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) / 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/gal 20' below the 7-5/8" shoe [OB sand] 75 bbl: 9.3 ppg mud below the 10-3/4" shoe wi 1 0 ppg LOT. MOBM in Laterals with 9.6 ppg Brine and Diesel above. · Integrity tests: Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: · Hydrates have been encountered on I-Pad wells between 1,700' and 2,300' TVD. / · Tight hole and packing off due to clays and poor hole cleaning has occurred on I Pad wells. · Sloughing I caving coal beds have been encountered on I Pad. · 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 andlor 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. I 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. ./ Anti-collision Issues · MPI-19 passes the Major Risk Criteria in the Mother Bore and the L-1 lateral. Gyro surveys will be required for close approach issues and magnetic interference to at least 900 ft MD. Distance to Nearest Property · MPI-19 is 2,030 ft from. the nearest Milne Point property lint Distance to Nearest Well Within Pool · MPI-19 is 200 ft from the nearest Schrader Bluff 08 sand penetration in MPJ-09A. / Drillina ~~ é~"."3(Rf~-$et·cof1duètohiåf1d:þé'(!af; 2?!::~:::'~::fY11RY; à:!1a:N(:f:(jlvett~r 3;:~:c::¡:;:fUhctiori':.:r ~stJ)ivérteo:RU 4" DP'and BHA. · ';':Orill1;3S.iI2";suftåð'e;h(jte. 5.'·' . ".. "Bµrfárídcemenf1 0~314~:surfac~:'é'ãsing~ 6.· ··;¡ND dIÝéi1er; in~Xa.Uweflheåg~ân(ff\Jl.JrrestBOP. 7; . ,¡j:t'ti!I'9~7/8~!"interroediate:hole: 8. .. . Hun andcement7:;SI8" intermédiatecasing. 9. . Djsplacetol\.;1~BM. . Ptill6:;3Z4"QB.:t)orizontal production hol.e. 10: ':Hun' 4": 1/2~' 'slotte ·;Iiner. and fiâng·öffi"· 7 :'S/8"· casing. 11. un whipstock and mill window for OA lateral. 12. Drill 6-3/4" OA horizontal production hole. 13. Retrieve whipstock. 14. Run 4-1/2" slotted liner and hang off in 7-S/8" casing 1S. Displace MOBM with Brine 16. RU and Run 2-7/8" tubing and ESP Completion. 17. NO BOP/NU Tree 18. Freeze Protect. 19. RDMO Doyon 14. DRILL & COMPLETION PROCEDURE 5 k\X-\\ ~ ~ Th'L) 0f~ffi)\JQ-{ I ASP GRID -z I I-PAD PLANT . 2"34'4'" .14 .13 .12 .11 · 8 · 7 · 4 · 6 · 3 · 5 · 2 · 9 .1 .10 .15 +'-16 +1-17 +1-18 +1-19 MPU I-PAD LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR NOTES 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). SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY 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 ARE CORRECT AS OF JUNE 04, 2<J04. 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.DD) BOX ELEV. OFFSETS MPI-16 y= 6,009,440.89 N 1,120.01 70"26'11.535" 70.4365375' 34.5' 2,324' FSL X= 551,759.44 E 1,464.86 149'34'40.788" 149.5779967" 3,611' FEl 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 MPI-18 Y= 6,009,438.23 N 1,120.05 70'26'11.505" 70.4365292" 34.6' 2,321' FSl x= 551,819.32 E 1,524.80 149"34'39.032" 149.5775089' 3,551' FEL MPj-19 Y= 6,009,436.50 N 1,119.69 70'26'11.486" 70.4365239' 34.8' 2,319' FSL / X= 551,849.73 E 1,555.26 149'34'38.139" 149.5772608' 3,521' FEL / I ,/ ~, DRA'M\I: ObP JACOBS CHECKED: AlliSON DATE: 6/5/04 DRA'lMNG: MILNE POINT UNIT I-PAD SHEET; FRB04 MPI 02-00 ~ ffi~fßrnœo JOB NO: SCALE: AS-BUll T CONDUCTORS 1 OF 1 o 6 5 04 ISSUED FOR INFORMATION JJ RFA OiGMEI!SNÐlANOSlJRIIE~ WELLS MPI-16, 1-17, 1-18 & 1-19 eo1'11£ST FIROI€EtI L...AHE 1'=150' NO. DAlE REVISION BY CHK """"""" """'" """ . . MPI-19 Schrader Bluff Dual Lateral B - 1-19 "OA" MPI... 19 10-3/4",40.5#, BTC <It 2545' MD MD (3158' 'TVD) . MD B s .- PI-19 "OA" With Slotted I, MPI .. 19 10-3/4",40.5#, 9' TVD) BTC at 2545' MD <: 4625' MD (3158' s - 1-19 MPI .. 19 STC at 2545' MD 10-3/4", STC at 2545' MD TOC <: 4625' MD s - 1- Lateral Completion 10-3/4", BTC at 2545' MD TOC <: 4625' MD ...................................................................................................................................................................................................... ~~ COMPANY DETAILS BP Amoco Calculation Method: Minimum Curvarure Error System: ISCWSA Scan Method: Trav Cylinder North Error Surl'ace: Elliptical + Cumg Warning Method: Rules Based TARGET DETAILS Name TVD +N/-S +E/-W MPI-19 LI Fault I 3754.30 4207.81 -1744.80 MPI-19 LI T2 4024.30 6204.77 -809.99 MPI-19 LI TI 4039.30 5576.34 -840.00 MPI-19 Ll Geo Poly 4039.30 5576.00 -840.00 MPI-19 LI T3 4049.30 7061.25 -819.99 MPI-19 LI T7 4054.30 8150.00 -2794.85 MPI-19 LI T8 4054.30 8220.88 -3267.08 MPI-19Ll T4 4059.30 7715.00 -1124.99 MPI-19 Ll TS 4059.30 7876.89 -1404.25 MPI-19 LI Fault 5 4059.30 8606.58 -2497.31 MP[-19 Ll Fault 4 4059.30 8926.82 -2526.08 MPI-19 Ll T6 4064.30 8090.00 -24 I 6.49 MP[-19 Ll Fault 3 4089.30 6663.24 -469.57 MP[-19 Ll Fault 2 4095.30 6145.16 -1617.31 REFERENCE fNFORMA nON SURVEY PROORAM Plan: MPI-19 LI wp02 (Plan MPI-19IMPI-19 LI) Co-otdinate (NlE) Rtfemx:e: Well Centre: Plan MPI-19, True North Depth Fm Depth To SurveylPlatI Tool Created By: Troy Jakabosky Date: 512012004 Venical (NO) Reference: 69.3 RKB(34J + 35) 6930 Sa:tion (VS) Reference: Slot - (O.OON.O.OOE) 7187.00 1225:2.81 Planned: MPI·19 L1 wp02 V30 MWD+IFR+MS Checked: Date Measured Depth Refere1lCe: 69,3 RKB{34J + 35) 69JO Calculation Method: Minimum Curvature Reviewed: Dale:_ WELL DETAILS ""'" +N!-S +FJ·W -"" ....ring Lai_ Longitude Slol Northing Easting Shape Plan MPI·[9 1038.09 1611,20 6009436.83 551849.84 70"26'll.489N 149"34'38,I36W NiA 6013632.00 550076.00 Polygon SECTION DETAILS 6015635.22 550996.81 Point Sec MD Inc Azi +N/-S +E/-W 6015006.66 550971.18 Point TVD DLeg TFace VSec Target 6015006.32 550971.18 Polygon I 7187.00 76.20 6.94 4020.70 4982.37 -989.67 6016491.53 550980.86 Point 0.00 0.00 4995.64 6017566.42 548998.67 Point 2 7207.00 78.19 8.31 4025.14 5001.70 -987.08 12.00 34.00 5012.64 6017634.00 548526.01 Point 3 7430.28 91.02 17.30 4046.14 5217.75 -937.80 7.00 35.44 5195.22 6017143.08 550671.35 Point 4 7607.48 91.02 17.30 4042.99 5386.91 -885.12 0.00 0.00 5332.96 6017303.00 550391.01 Point 5 7802.40 91.15 9.50 4039.30 5576.34 -840.00 4.00 -88.95 5492.34 MPI-19 L1 TI 6018025.00 549293.01 Polygon 6 8001.47 91.48 1.54 4034.73 5774.28 -820.86 4.00 -87.55 5669.22 6018345.00 549262.01 Polygon 7 8378.84 91.48 1.54 4024.99 6151.39 -810.71 0.00 0.00 6015.92 6017509.06 549377.41 Point 8 8432.24 90.00 0.00 4024.30 6204.77 -809.99 4.00 -133.79 6065.26 MPI-19Ll T2 60 I 6096.00 551334.01 Polygon 9 8475.59 88.27 359.89 4024.95 6248.12 -810.Q4 4.00 -176.23 6105.56 6015570.00 550/90.01 Polygon 10 9172.57 88.27 359.89 4046.00 6944.77 -811 .43 0.00 0.00 6753.48 11 9289.51 88.50 351.70 4049.30 7061.25 -819.99 7.00 -88.51 6864.89 MPI-19 L1 T3 12 9293.09 88.75 351.71 4049.39 7064.79 -820.51 7.00 2.77 6868.37 . CASING DETAILS 13 9435.66 88.75 351.71 4052.50 7205.84 -841.06 0.00 0.00 7007.03 14 10031.76 90.00 3[0.00 4059.30 7715.00 -1124.99 7.00 -88.60 7585.06 MPI-19 Ll T4 MD Name Size 15 10239.99 90.00 295.42 4059.30 7827.23 -1299.72 7.00 -90.00 7753.88 16 10349.65 90.00 295.42 4059.30 7874.31 -1398.76 0.00 0.00 7834.21 12252.00 4 1\2" 4.500 17 10355.71 90.00 295.00 4059.30 7876.89 -1404.25 7.00 -90.00 7838.63 MPI-19 L1 T5 18 10563.85 89.69 280.43 4059.86 7940.06 -1601.98 7.00 -91.23 7970.36 19 11383.19 89.69 280.43 4064.28 8088.43 -2407.76 0.00 0.00 8405.83 20 11392.06 90.00 280.00 4064.30 8090.00 -24 I 6.49 6.00 -54.55 8410.52 MPI-19 L1 T6 21 11423.94 91.62 278.99 4063.85 8095.26 -2447.93 6.00 -31.98 8427.02 22 11747.06 91.62 278.99 4054.70 8145.71 -2766.95 0.00 0.00 8591. 72 23 " 775.29 90.00 278.50 4054.30 8150.00 -2794.85 6.00 -163.31 8606.01 MP[-19L1 T7 24 11775.89 90.00 278.54 4054.30 8 I 50.09 -2795.45 6.00 90.00 8606.32 25 /2252.81 90.00 278.54 4054.30 8220.88 -3267.08 0.00 0.00 8846.28 MPI-19 L1 T8 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation No. TVD 1 0.00 0.00 TUZC 4054.30 2 0.00 0.00 Ugnu-MA 3 0.00 0.00 Ugnu-MBI 4 0.00 0.00 Ugnu-MB2 5 0.00 0.00 SBF2-NA 6 0.00 0.00 SBFI-NB 7 0.00 0.00 SBE2-NE 8 4044.30 7349.66 TSBC-Base OA c ~ 36 Ov 0 0 :::. '" õ. ¿¡ " " e " > 2 f- 42 vv : ,/ .;""00 "".... . ......- I,' '- ~ I i I I I H'. ,- !H ., in , 300 - : 'n , -JtáÂ~r /1~~:l8tJ~.14~~4 : ¡lill+ \ : ! stÎiribr 1¡!m1:12ö!t'MD[4Ô:ì5h8!r Dr ¡ I djDiI74~01"M5¡~6[5 TyiJ¡ ! t I I I, + I I '1 j j l I,n l!slsJn-blr~l br.~id 8 ~~D;140j\3 8'tvh-î' 1 j I t [I 1 1-, /I I 1 j: I jEzì[d t:F:Ît~4~'f·40rf r l; ¡ II t '. '-- n, , , I I I! " ': Stárt 0ir 1'1 ' i 8378 6'iMþ.402# 'W9'- f ' 1 j ,I l: : 1 ¡ lEn~ 9ir ¡ 8475,61 MP'4[024 ~r' tV? I,'; i ~ 1 1 \ ¡ , i I i I J¡ I tl I t - ¡- t 1 ¡ ¡..~-- - I I r i J i 1 j I I r 1,' I 1 1--- I ! L , i ,fl' , I j I i 1/- e .- I f-- -I J,Jri¡,:tltõ;1;~1- ~9tMt KM ¡~Y1L I :: : ·f+D~'i92k )' ~£.T04 .3' 't~-- I ¡- ~. ' fa · ~:::,~tlt~:-, 3J5 :~:,~:'~;'~ . ~! ¡ 1'1 i 11tl I---f -if- -- T ;;. tQ [ IlO'~138.2 '+OL4~j2Ì8bO }I -I--1~:- -- f-- J/nd-DI ,I o.ff.85'f - - n - -- -- - n t,-lîau t5~~;; - - -t~:l þ,-!- ;:3;;;;- ¡. -- . - - - --h - --\Î taI,jJI '1 '- i~7ì·08' tv ' LI-1. -I-::Jttl~ 1 5.~I~~1:.tsLtJD.~·· . .. j 1~/ J ¡t.l¡rjlii~ --. -- }; -.- -1.t ...(_jl. I - ~~['Ydl'tl2rJ _j_L+-. .llt+ -- --- -- 'I". ° --- ... __ I ¡ ·1·_._ _ '-i:__' +'u --j-" -- -- --- + lj -+-'" -- :2o-,JÐ.. -'1'- . - _n --- -- .. -- "~ - .! ~,~k ~ · .¡J, ),¡;¡--¡ r - -- --+ ... --- - rt ~ L - -1 .. ~.: ;~ ~.. =' ~ ~ =: ~t- -~ --. :.- :: n.tlL .dl .__ _ n --L, . II .. ·lulJ .J . , ,. _u_ ---- L... ., t T T 1'--/ ~1 -.- -- I -- -- u__ --- - .. --- '-0 .--- - --~ -- -.;..: --_.- ·-f--'· --- .. - - ItxOO, PI 19(1\1 ... "- -.--- ..-.-..- -_.- -- 48 0 I , L I I ,... "--0 ---- 1 , , , 4200 4800 5400 6000 6600 n __ .__ ~ .----->- .. ~n on _ 7200 7800 9600 8400 9000 Vertical Section at 338.33° [600ft/in] SURVE.Y PROOR.AM 1 Plan: MPI·19 LI wp02 (Plan MPI·!9/MPI·19 LI Depth Fm Depth To Su~1P1an tool Created By' Troy Jokabooky Dale: 5/20/2004 7187.00 121j2.SI Planned: MPI-19 LI wp02 V30 MWD+IFR+MS Cheàed: Date: - WELL DETAILS ........ .",oS +E,I·W Northing -. latirude Longitude SIoI PlanMPI· 9 1038JJ9 161110 6009436.83 551849.84 70"26'tl.489N 149Q)4'31!..IJ6W N/A TARGET DETAILS REFERENCE INFORMA TJON Well Centre: Plan MPI·19. True North 69.3 RKB(343 + 35) 6930 SkJl - (O.OON.O.OOE} 69.3 RK.B(343 ... 35) 693' MinimumCUrvarure Co-ordinate (NIE) Reference: Vertical (TVD) Reference: Section (VS) Reference; Measu~aI~~~~~~ TVD +N/-S +E/-W Northing Easting Shape 3754.30 4207.81 -1744.80 6013632.00 550076.00 Polygon 4024.30 6204.77 -809.99 6015635.22 550996.81 Point 4039.30 5576.34 -840.00 60 I 5006.66 550971.18 Point 4039.30 5576.00 -840.00 6015006.32 550971.\8 Polygon 4049.30 7061.25 -819.99 6016491.53 550980.86 Point 4054.30 8150.00 ·2794.85 6017566.42 548998.67 Point 4054.30 8220.88 -3267.08 6017634.00 548526.01 Point 4059.30 7715.00 -1124.99 6017143.08 550671.35 Point 4059.30 7876.89 ·1404.25 6017303.00 550391.01 Point 4059.30 8606.58 ·2497.31 6018025.00 549293.01 Polygon 4059.30 8926.82 ·2526.08 6018345.00 549262.01 Polygon 4064.30 8090.00 ·2416.49 6017509.06 549377.41 Point 4089.30 6663.24 -469.57 6016096.00 551334.01 Polygon 4095.30 6145.16 ·1617.31 6015570.00 550190.01 Polygon FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 0.00 0.00 ruzc 2 0.00 0.00 Ugnu-MA 3 0.00 0.00 Ugnu-MBI 4 0.00 0.00 Ugnu-MB2 5 0.00 0.00 SBF2-NA 6 0.00 0.00 SBFI-NB 7 0.00 0.00 SBE2-NE 8 4044.30 7349.66 TSBC-Base OA CASING DETAILS Name MPI·19 LI Fault 1 MPI-19 LI T2 MPI·19 LI T1 MPI-19 L1 Geo Poly MPI-19LI T3 MPI·19 LI T7 MPI·\9 LI T8 MPI·19 LI T4 MPI-19 Ll T5 MPI·19 Ll Fault 5 MPI-19 LI Fault 4 MPI-19 Ll T6 MPI-19 LI Fault 3 MPI·19Ll Fault 2 h Mb ~tk4:3'~VDj uj i¡"'JUJ1 ui+ \1 Iml" 'Iu'.~'+,n¡+ 'W'I'~'u, tlnll [Etjd ir):PT7 .9I'MIJ:."f15,J.lnlin ·f :/! I "I" St:jrt it6l1(¡þ'11Î7 7.¿8'1MÞ, ,054 7'Jvb,' i I . i : Iii I : : I:. . I ¡,"i" "I, I' I!'" ',1\ -1,..:+I--1..'t--"" ;pJUI..t, i- f I ,Iu ,..y '_u.~" -.. End 't"'jWI2' .96-Ji¡,JIO~3. I! I I t \ I; . i i ~ I . 'u . '~9-itlF'T'4' ",,-- u n,__ --", _1__ ,- "_1 :,. L'f't: rL! ,~! rtJii6I:LOQ'_\JI3&3,. I I ' I I ; COMPANY DETAILS BP Amoco ~ Calculation Method: Minimum Curvature Error SYf>tem: ISCWSA Scan Method: Trav Cylinder North Error Surl'¡w;e: EUipt\cal + Casing WarnjngMethod: RulcsBased f¡ IT6t.1 '":,, 'I """ I I I I ! I ,. , ) ! f I -¡ I , : I ~ j j I I , 880' -....: I . ·-f-..I 4 ì\j 9) jn1Ju_",[ + ++",-, '-¡" -"-I L~p .i~ I 4lm(u "+Iu,,(' t1u!¡+11 11IartMPh(MI1I:j .t~'.ì.tl·1]'· . L_J._ _~__¡,. _-!-__.L.' I\- \ :Q 'µ-¡--,'" ~I+ri Jinlztl¡,.. ,-j, , -,:1, 'Iu fa .dtS I I ' : i : ",rli"nJ', In.,' ,uf' iTY¡I'19rliT6u i' u '-'+[-1'''+ )"¡P.I·19 11 ' I I ~ \ I tbt~J~;t,¡;¡;~:i6t +-+LLI..i-l l- i in 1'~9<i~it':'-~Ot4( I ;. , ! ; i : ! II )-r-II)I- -i I 1QO'¡:9I43S.68· MD. ~0$2. , I': '¡"I ir¡:92t3./1 '¡MID.4<j49i3S lii:7!1 0Ø':j91i7:;ÚS<I'MD! 41 ¡r¡',·-rlliT¡· 475,61 !MD.14024i.95'~V1 I En~1I Sfaj-t 1 800 720 c ;¡§ o ~ +' :E! 1:: ~ :E! :; o on e Size 4.500 - VSec Target 4995.64 5012.64 5195.22 5332.96 5492.34 MPI·19 LI TI 5669.22 6015.92 6065.26 MPI-19 LI T2 6105.56 6753.48 6864.89 MPI-19 LI 13 6868.37 7007.03 7585.06 MPI-19 LI T4 7753.88 7834.21 7838.63 MPI-19 Ll T5 7970.36 8405.83 8410.52 MPI-19 LI T6 8427.02 8591.72 8606.01 MPI-19L1 T7 8606.32 8846.28 MPI-19 LI T8 MD 2252.00 TVD No. E~d Di~ : 640 Name 41\2' TF ace 0.00 34.00 35.44 0.00 ·88.95 -87.55 0.00 133.79 176.23 0.00 -88.51 2.77 0.00 -88.60 -90.00 0.00 -90.00 ·91.23 0.00 -54.55 -31.98 0.00 63.31 90.00 0.00 , , 'j 1- :. '. ,,' i JJJ-.Hti l '-, ì '-. :nll r-ï'iml L1uJf! .. 1--+--t-·-t --+_.~.- ,uTn¡ )~~9h,tVÞ: +/1 .. f' ,. " ;JID"4Þ5~.3riÿÖ 11 : i i i I ill i i -, . i .I---+--r-' ;1]v¡D Ll-L- ~th ; if·" "~ 46'TYn I: --._~._.. _j___ L·...._,_ ..., ¡ --. 1- ~ .,...,..,.,. L1 DLeg 0.00 12.00 7.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 7.00 7.00 0.00 7.00 7.00 0.00 7.00 7.00 0.00 6.00 6.00 0.00 6.00 6.00 0.00 4054.30 SECTION DETAILS +EI-W -989.67 -987.08 -937.80 -885.12 -840.00 -820.86 -810.71 -809.99 -810.04 ·811.43 -819.99 -820.51 -841.06 -1124.99 -1299.72 -1398.76 -1404.25 -1601.98 -2407.76 -2416.49 -2447.93 -2766.95 -2794.85 -2795.45 -3267.08 1 +N/-S 4982.37 5001.70 5217.75 5386.91 5576.34 5774.28 6151.39 6204.77 6248.12 6944.77 7061.25 7064.79 7205.84 7715.00 7827.23 7874.31 7876.89 7940.06 8088.43 8090.00 8095.26 8145.71 8150.00 8150.09 8220.88 TVD 4020.70 4025.14 4046.14 4042.99 4039.30 4034.73 4024.99 4024.30 4024.95 4046.00 4049.30 4049.39 4052.50 4059.30 4059.30 4059.30 4059.30 4059.86 4064.28 4064.30 4063.85 4054.70 4054.30 4054.30 4054.30 Azi 6.94 8.31 17.30 17.30 9.50 1.54 1.54 0.00 359.89 359.89 351.70 351.71 351.71 310.00 295.42 295.42 295.00 280.43 280.43 280.00 278.99 278.99 278.50 278.54 278.54 Inc 76.20 78.19 91.02 91.02 91.I5 91.48 91.48 90.00 88.27 88.27 88.50 88.75 88.75 90.00 90.00 90.00 90.00 89.69 89.69 90.00 91.62 91.62 90.00 90.00 90.00 MD 7187.00 7207.00 7430.28 7607.48 7802.40 8001.47 8378.84 8432.24 8475.59 9172.57 9289.51 9293.09 9435.66 10031.76 10239.99 10349.65 10355.71 10563.85 11383.19 11392.06 11423.94 11747.06 1 1775.29 11775.89 12252.81 Sec 1 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 21 22 23 24 25 '1 o I JLl1 I I t -800 -::: f I i d I ' v¿ ; I VlD i i I I 'tD! ! I : i , I ) J i i -2400 600 West(-)/East(+) [800ft/in] FalJlt.2 . i 8bo\ .4b·f' ¡} 40i4·t3"T , t r ,'L:· I ! i I I ¡I! i 'II II : , i I h II i ¡ : 16 ~0.~5' 1Mb. 41' 043.p81¡T I' I I I . I : Y4~0-r4'IMID.A<146 5~'1 , i \ f I \ '100':: rO?'~p 4025·18' 2~1O~' : 7 181 J~, 4b2~. 7 I ! , I, I . I ¡ ! i, I I I I : I I , , i ! I I, ¡ ! I ¡Ii ! i ·3200 ilL i i I: I i I ~ndDir I I I I I 'I' : ¡ i I L i I : Ii' I I ' . ¡ i Star1 DIr 4/IÖO Iii L \ i i I i ¡t:.l\d IDi: ¡ ¡ ¡ i ! : ( Iii S",~Dir 111[i slart, ~r I : I r ., I I I I I I IIIII 560 480 . . BP Planning Report - BP Company: BPAmoco Date: 5/20/2004 Time: 15:05:42 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-19, True North Site: M Pt I Pad Vertical (fVD) Reference: 69.3 RKB(34.3 + 35) 69.3 Well: Plan MPI-19 Section (VS) Reference: Well (0.OON,O.00E,338.33Azi) Wellpath: MPI-19 L1 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: MPI-19 L1 wp02 Date Composed: 5/6/2004 Version: 30 Principal: Yes Tied-to: From: Definitive Path Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2003 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6008388.01 ft Latitude: 70 26 1.282 N From: Map Easting: 550245.83 ft Longitude: 149 35 25.422 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 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 Wellpath: MPI-19 L 1 Drilled From: MPI-19 Tie-on Depth: 7187.00 ft Current Datum: 69.3 RKB(34.3 + 35) Height 69.30 ft Above System Datum: Mean Sea Level Magnetic Data: 5/6/2004 Declination: 24.87 deg Field Strength: 57557 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.30 0.00 0.00 338.33 Casing Points MD TVD Diameter Hole Size Name ft ft in in 12252.00 4054.30 4.500 6.125 4112" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft - deg deg 0.00 BPRF 0.00 0.00 0.00 TUZC 0.00 0.00 0.00 Ugnu-MA 0.00 0.00 0.00 Ugnu-MB1 0.00 0.00 0.00 Ugnu-MB2 0.00 0.00 0.00 Ugnu-MC 0.00 0.00 0.00 SBF2-NA 0.00 0.00 0.00 SBF1-NB 0.00 0.00 0.00 SBE4-NC 0.00 0.00 0.00 SBE2-NE 0.00 0.00 0.00 SBE1-NF 0.00 0.00 0.00 TSBD-Top OA 0.00 0.00 7349.66 4044.30 TSBC-Base OA 0.00 0.00 0.00 TSBB- T op OB 0.00 0.00 0.00 SBA5-Base OB 0.00 0.00 Targets Map Map <- Latitude ---> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPI-19L1 Fault 1 3754.30 4207.81 -1744.80 6013632.00 550076.00 70 26 52.870 N 149 35 29.372 W -Polygon ,1 3754.30 4207.81 -1744.80 6013632.00 550076.00 70 26 52.870 N 149 35 29.372 W Company: Field: Site: Well: Wellpath: Targets BP Amoco Milne Point M pt I Pad Plan MPI-19 MPI-19 L1 Name . Description TVD Dip. Dir. ft 3754.30 -Polygon 2 MPI-19 L1 T2 MPI-19 L 1 T1 MPI-19 L 1 Geo Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 -Polygon 11 -Polygon 12 MPI-19 L 1 T3 MPI-19 L1 T7 MPI-19l1 T8 MPI-19 l1 T4 MPI-19 L 1 T5 MPI-19 L 1 Fault 5 -Polygon 1 -Polygon 2 MPI-19 L 1 Fault 4 -Polygon 1 -Polygon 2 MPI-19 L 1 T6 MPI-19 L 1 Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 MPI-19 L 1 Fault 2 -Polygon 1 -Polygon 2 Plan Section Information MO ft 7187.00 7207.00 7430.28 7607.48 7802.40 8001.47 8378.84 8432.24 8475.59 Incl deg 76.20 78.19 91.02 91.02 91.15 91.48 91.48 90.00 88.27 .----,-..--------.------....--...----.-----.-.-,---- - Azim deg 6.94 8.31 17.30 17.30 9.50 1.54 1.54 0.00 359.89 4024.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4039.30 4049.30 4054.30 4054.30 4059.30 4059.30 4059.30 4059.30 4059.30 4059.30 4059.30 4059.30 4064.30 4089.30 4089.30 4089.30 4089.30 4095.30 4095.30 4095.30 TVO ft 4020.70 4025.14 4046.14 4042.99 4039.30 4034.73 4024.99 4024.30 4024.95 ---- -,-- - - ---'-----,- BP Planning Report - BP +N/-S ft 4210.07 6204.77 5576.34 5576.00 4754.06 4734.54 5798.79 7226.88 7965.74 8050.44 8355.49 8151.63 7827.64 7505.59 7151.47 5801.58 7061.25 . Date: 5/20/2004 Time: 15:05:42 Page: 2 Co-ordinate(NE) Reference: Well: Plan MPI-19, True North Vertical (TVO) Reference: 69.3 RKB(34.3 + 35) 69.3 Section (VS) Reference: Well (0.00N,0.00E,338.33Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +E/-W ft -630.65 -809.99 -840.00 -840.00 -1195.93 -834.02 -707.61 -694.68 -949.57 -1481.05 -3352.16 -3375.58 -1513.60 -1080.79 -925.23 -964.62 -819.99 8150.00 -2794.85 8220.88 -3267.08 7715.00 -1124.99 7876.89 -1404.25 8606.58 -2497.31 8606.58 -2497.31 7998.04 -2574.54 8926.82 -2526.08 8926.82 -2526.08 7909.72 -1667.05 8090.00 -2416.49 6663.24 6663.24 5684.24 4675.18 -469.57 -469.57 -486.38 -782.43 6145.16 -1617.31 6145.16 -1617.31 5869.61 -536.10 +N/-S ft 4982.37 5001.70 5217.75 5386.91 5576.34 5774.28 6151.39 6204 .77 6248.12 +E/-W ft -989.67 -987.08 -937.80 -885.12 -840.00 -820.86 -810.71 -809.99 -810.04 Map Map Northing Easting ft f! 6013642.00 551190.00 6015635.22 550996.81 6015006.66 550971.18 6015006.32 550971.18 6014182.00 550621.00 6014165.00 550983.00 6015230.00 551102.00 6016658.00 551105.00 6017395.00 550845.00 6017476.00 550313.00 6017768.00 548440.00 6017564.00 548418.00 6017253.00 550282.00 6016934.00 550717.00 6016581.00 550875.00 6015231.00 550845.00 6016491.53 550980.86 6017566.42 548998.67 6017634.00 548526.01 6017143.08 550671.35 6017303.00 550391.01 6018025.00 549293.01 6018025.00 549293.01 6017416.00 549220.01 6018345.00 549262.01 6018345.00 549262.01 6017334.00 550128.01 6017509.06 549377.41 6016096.00 551334.01 6016096.00 551334.01 6015117.00 551324.01 6014106.00 551035.01 6015570.00 550190.01 6015570.00 550190.01 6015302.00 551273.01 DLS Build Turn deg/1000 deg/100f! deg/100f! 0.00 0.00 0.00 12.00 9.97 6.85 7.00 5.74 4.03 0.00 0.00 0.00 4.00 0.07 -4.00 4.00 0.17 -4.00 0.00 0.00 0.00 4.00 -2.77 -2.89 4.00 -3.99 -0.26 - -_._-,--....,---,----- --..-.-..- -_.._-,-- - "---. ----.----...---- ---"-..-" ----- <-- Latitude -> <- Longitude -> Deg Min Sec Deg Mio See 70 27 12.511 N 70 26 52.894 N 149 34 56.655 W 70 27 6.331 N 70 27 6.328 N 70 26 58.244 N 70 26 58.052 N 70 27 8.519 N 70 27 22.564 N 70 27 29.830 N 70 27 30.662 N 70 27 33.656 N 70 27 31.651 N 70 27 28.471 N 70 27 25.304 N 70 27 21.822 N 70 27 8.546 N 70 27 20.935 N 70 27 31.638 N 70 27 32.333 N 70 27 27.364 N 70 27 28.955 N 70 27 36.129 N 70 27 36.129 N 70 27 30.144 N 70 27 39.278 N 70 27 39.278 N 70 27 29.278 N 70 27 31.049 N 70 27 17.021 N 70 27 17.021 N 70 27 7.392 N 70 26 57.468 N 70 27 11.924 N 70 27 11.924 N 70 27 9.215 N TFO deg 0.00 34.00 35.44 0.00 -88.95 -87.55 0.00 -133.79 -176.23 Target MPI-19 L 1 T1 MPI-19 L 1 T2 ----,'--.._----._------,'------- -'._-,---.-- 149 35 1.928 W 149 35 2.807 W 149 35 2.807 W 149 35 13.257 W 149 35 2.629 W 149 34 58.919 W 149 34 58.543 W 149 35 6.034 W 149 3521.649 W 149 36 16.626 W 149 36 17.312 W 149 3522.604 W 149 35 9.887 W 149 35 5.316 W 149 35 6.468 W 149 35 2.224 W 149 36 0.250W 149 36 14.125 W 149 3511.187 W 149 35 19.392 W 149 35 51.512 W 149 35 51.512 W 149 35 53.775 W 149 35 52.361 W 149 35 52.361 W 1493527.113W 149 3549.133 W 149 34 51.929 W 149 34 51.929 W 149 34 52.421 W 149 35 1.113 W 149 35 25.640 W 149 35 25.640 W 149 34 53.882 W . . BP Planning Report - BP Company: BP Amoco Date: 5/20/2004 Time: 15:05:42 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-19, True North Site: MPtlPad Vertical (TVD) Reference: 69.3 RKB(34.3 + 35) 69.3 Well: Plan MPI-19 Section (VS) Reference: Well (0.00N,O.00E,338.33Azi) Wellpath: MPI-19 L1 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1000 deg/100ft deg/1000 deg 9172.57 88.27 359.89 4046.00 6944.77 -811.43 0.00 0.00 0.00 0.00 9289.51 88.50 351.70 4049.30 7061.25 -819.99 7.00 0.20 -7.00 -88.51 MPI-19 L1 T3 9293.09 88.75 351.71 4049.39 7064.79 -820.51 7.00 6.99 0.34 2.77 9435.66 88.75 351.71 4052.50 7205.84 -841.06 0.00 0.00 0.00 0.00 10031.76 90.00 310.00 4059.30 7715.00 -1124.99 7.00 0.21 -7.00 -88.60 MPI-19 L1 T4 10239.99 90.00 295.42 4059.30 7827.23 -1299.72 7.00 0.00 -7.00 -90.00 10349.65 90.00 295.42 4059.30 7874.31 -1398.76 0.00 0.00 0.00 0.00 10355.71 90.00 295.00 4059.30 7876.89 -1404.25 7.00 0.00 -7.00 -90.00 MPI-19 L1 T5 10563.85 89.69 280.43 4059.86 7940.06 -1601.98 7.00 -0.15 -7.00 -91.23 11383.19 89.69 280.43 4064.28 8088.43 -2407.76 0.00 0.00 0.00 0.00 11392.06 90.00 280.00 4064.30 8090.00 -2416.49 6.00 3.48 -4.89 -54.55 MPI-19 L1 T6 11423.94 91.62 278.99 4063.85 8095.26 -2447.93 6.00 5.09 -3.18 -31.98 11747.06 91.62 278.99 4054.70 8145.71 -2766.95 0.00 0.00 0.00 0.00 11775.29 90.00 278.50 4054.30 8150.00 -2794.85 6.00 -5.75 -1.72 -163.31 MPI-19 L1 T7 11775.89 90.00 278.54 4054.30 8150.09 -2795.45 6.00 0.00 6.00 90.00 12252.81 90.00 278.54 4054.30 8220.88 -3267.08 0.00 0.00 0.00 0.00 MPI-19 L1 T8 Survey MD lncl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1000 7187.00 76.20 6.94 4020.70 3951.40 6014411.72 550825.66 4995.64 0.00 Start Dir 12/100' : 7187' MD, 7200.00 77.49 7.83 4023.66 3954.36 6014424.28 550827.20 5006.70 12.00 MWD+IFR+MS 7207.00 78.19 8.31 4025.14 3955.84 6014431.06 550828.11 5012.64 12.00 Start Dir 71100' : 7207' MD, 4 7250.00 80.65 10.08 4033.03 3963.73 6014472.83 550834.57 5048.92 7.00 MWD+IFR+MS 7300.00 83.52 12.10 4039.92 3970.62 6014521.48 550843.76 5090.56 7.00 MWD+IFR+MS 7349.66 86.37 14.09 4044.30 3975.00 6014569.72 550854.63 5131.19 7.00 TSBC-Base OA 7350.00 86.39 14.10 4044.32 3975.02 6014570.05 550854.71 5131.46 7.00 MWD+IFR+MS 7400.00 89.27 16.09 4046.21 3976.91 6014618.37 550867.39 5171.48 7.00 MWD+IFR+MS 7430.28 91.02 17.30 4046.14 3976.84 6014647.43 550875.89 5195.22 7.00 MWD+IFR+MS 7430.74 91.02 17.30 4046.13 3976.83 6014647.87 550876.02 5195.57 0.00 End Dir : 7430.74' MD, 4046.5 7500.00 91.02 17.30 4044.90 3975.60 6014714.12 550896.15 5249.41 0.00 MWD+JFR+MS 7607.48 91.02 17.30 4042.99 3973.69 6014816.93 550927.38 5332.96 0.00 MWD+IFR+MS 7610.85 91.02 17.16 4042.93 3973.63 6014820.16 550928.36 5335.58 4.00 Start Dir 4/100': 7610.85' MD 7700.00 91.08 13.60 4041.30 3972.00 6014906.24 550951.39 5406.71 4.00 MWD+IFR+MS 7802.40 91.15 9.50 4039.30 3970.00 6015006.66 550971.18 5492.34 4.00 MPI-19 L 1 T1 7900.00 91.31 5.60 4037.20 3967.90 6015103.45 550983.33 5517.48 4.00 MWD+IFR+MS 8001.47 91.48 1.54 4034.73 3965.43 6015204.70 550988.94 5669.22 4.00 MWD+IFR+MS 8001.49 91.48 1.54 4034.73 3965.43 6015204.72 550988.94 5669.23 0.00 End Dir : 8001.49' MD, 4034.7 8100.00 91.48 1.54 4032.18 3962.88 6015303.17 550990.90 5759.74 0.00 MWD+IFR+MS 8170.00 91.48 1.54 4030.38 3961.08 6015373.12 550992.30 5824.05 0.00 Fault 2 8200.00 91.48 1.54 4029.60 3960.30 6015403.11 550992.90 5851.61 0.00 MWD+IFR+MS 8300.00 91.48 1.54 4027.02 3957.72 6015503.04 550994.89 5943.48 0.00 MWD+IFR+MS 8378.84 91.48 1.54 4024.99 3955.69 6015581.84 550996.46 6015.92 0.00 MWD+IFR+MS 8378.86 91.48 1.54 4024.99 3955.69 6015581.85 550996.46 6015.93 0.00 Start Dir 4/100' : 8378.86' MD 8400.00 90.89 0.93 4024.55 3955.25 6015602.98 550996.77 6035.40 4.00 MWD+/FR+MS 8432.24 90.00 0.00 4024.30 3955.00 6015635.22 550996.81 6065.26 4.00 MPI-19 L 1 T2 8475.59 88.27 359.89 4024.95 3955.65 6015678.56 550996.47 6105.56 4.00 MWD+IFR+MS 8475.61 88.27 359.89 4024.96 3955.66 6015678.58 550996.47 6105.57 0.00 End Dir : 8475.61' MD, 4024.9 8500.00 88.27 359.89 4025.69 3956.39 6015702.95 550996.25 6128.25 0.00 MWD+IFR+MS 8600.00 88.27 359.89 4028.71 3959.41 6015802.89 550995.35 6221.21 0.00 MWD+IFR+MS 8700.00 88.27 359.89 4031.73 3962.43 6015902.83 550994.46 6314.17 0.00 MWD+IFR+MS 8800.00 88.27 359.89 4034.75 3965.45 6016002.77 550993.57 6407.13 0.00 MWD+/FR+MS 8900.00 88.27 359.89 4037.77 3968.47 6016102.72 550992.67 6500.09 0.00 MWD+IFR+MS 9000.00 88.27 359.89 4040.79 3971.49 6016202.66 550991.78 6593.05 0.00 MWD+IFR+MS 9100.00 88.27 359.89 4043.81 3974.51 6016302.60 550990.88 6686.02 0.00 MWD+IFR+MS I . . BP Planning Report - BP Company: BP Amoco Date: 5/20/2004 Time: 15:05:42 Page: 4 Field: Mílne Point Co-ordinate(NE) Reference: Well: Plan MPI-19, True North Site: MPtlPad Vertical (fVD) Reference: 69.3 RKB(34.3 + 35) 69.3 Well: Plan MPI-19 Section (VS) Reference: Well (0.00N,O.00E,338.33Azi) Wellpath: MPI-19 L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/100t! 9172.57 88.27 359.89 4046.00 3976.70 6016375.12 550990.24 6753.48 0.00 MWD+IFR+MS 9172.59 88.27 359.89 4046.00 3976.70 6016375.14 550990.24 6753.50 0.00 Start Dir 71100' : 9172.59' MD 9200.00 88.32 357.97 4046.81 3977.51 6016402.53 550989.53 6779.14 7.01 MWD+IFR+MS 9250.00 88.42 354.47 4048.24 3978.94 6016452.36 550985.89 6826.70 7.00 MWD+IFR+MS 9289.51 88.50 351.70 4049.30 3980.00 6016491.53 550980.86 6864.89 7.00 MPI-19 L1 T3 9293.09 88.75 351.71 4049.39 3980.09 6016495.06 550980.32 6868.37 7.00 MWD+IFR+MS 9293.11 88.75 351.71 4049.39 3980.09 6016495.09 550980.31 6868.39 0.00 End Dir : 9293.11' MD, 4049.3 9300.00 88.75 351.71 4049.54 3980.24 6016501.90 550979.27 6875.09 0.00 MWD+IFR+MS 9400.00 88.75 351.71 4051.72 3982.42 6016600.72 550964.18 6972.35 0.00 MWD+IFR+MS 9435.66 88.75 351.71 4052.50 3983.20 6016635.95 550958.79 7007.03 0.00 MWD+IFR+MS 9435.68 88.75 351.71 4052.50 3983.20 6016635.97 550958.79 7007.05 0.00 Start Dir 7/100' : 9435.68' MD 9450.00 88.77 350.71 4052.81 3983.51 6016650.11 550956.50 7021.01 7.01 MWD+IFR+MS 9500.00 88.86 347.21 4053.84 3984.54 6016699.09 550946.59 7070.13 7.00 MWD+IFR+MS 9550.00 88.96 343.71 4054.79 3985.49 6016747.38 550933.71 7119.73 7.00 MWD+IFR+MS 9600.00 89.05 340.21 4055.65 3986.35 6016794.79 550917.90 7169.61 7.00 MWD+IFR+MS 9650.00 89.16 336.71 4056.43 3987.13 6016841.15 550899.23 7219.60 7.00 MWD+IFR+MS 9700.00 89.26 333.21 4057.13 3987.83 6016886.29 550877.76 7269.50 7.00 MWD+IFR+MS 9750.00 89.37 329.71 4057.73 3988.43 6016930.04 550853.57 7319.13 7.00 MWD+IFR+MS 9800.00 89.48 326.22 4058.23 3988.93 6016972.22 550826.77 7368.30 7.00 MWD+IFR+MS 9850.00 89.59 322.72 4058.64 3989.34 6017012.70 550797.43 7416.84 7.00 MWD+IFR+MS 9900.00 89.70 319.22 4058.95 3989.65 6017051.31 550765.68 7464.55 7.00 MWD+IFR+MS 9950.00 89.81 315.72 4059.17 3989.87 6017087.91 550731.64 7511.27 7.00 MWD+IFR+MS 10000.00 89.93 312.22 4059.28 3989.98 6017122.36 550695.42 7556.81 7.00 MWD+IFR+MS 10031.76 90.00 310.00 4059.30 3990.00 6017143.08 550671.35 7585.06 7.00 MPI-19 L1 T4 10050.00 90.00 308.72 4059.30 3990.00 6017154.54 550657.17 7601.01 7.00 MWD+IFR+MS 10100.00 90.00 305.22 4059.30 3990.00 6017184.33 550617.03 7643.71 7.00 MWD+IFR+MS 10150.00 90.00 301.72 4059.30 3990.00 6017211.61 550575.14 7684.73 7.00 MWD+IFR+MS 10200.00 90.00 298.22 4059.30 3990.00 6017236.28 550531.67 7723.93 7.00 MWD+IFR+MS 10239.99 90.00 295.42 4059.30 3990.00 6017254.07 550495.87 7753.88 7.00 MWD+IFR+MS 10240.00 90.00 295.42 4059.30 3990.00 6017254.08 550495.85 7753.89 0.00 End Dir : 10240' MD, 4059.3' 10300.00 90.00 295.42 4059.30 3990.00 6017279.46 550441.49 7797.84 0.00 MWD+IFR+MS 10349.65 90.00 295.42 4059.30 3990.00 6017300.46 550396.51 7834.21 0.00 MWD+IFR+MS 10349.66 90.00 295.42 4059.30 3990.00 6017300.46 550396.50 7834.22 0.00 Start Dir 7/100' : 10349.66' M 10355.71 90.00 295.00 4059.30 3990.00 6017303.00 550391.01 7838.63 7.01 MPI-19 L1 T5 10400.00 89.93 291.90 4059.33 3990.03 6017320.34 550350.26 7870.01 7.00 MWD+IFR+MS 10450.00 89.86 288.40 4059.42 3990.12 6017337.23 550303.22 7903.35 7.00 MWD+IFR+MS 10500.00 89.78 284.90 4059.57 3990.27 6017351.23 550255.23 7934.35 7.00 MWD+IFR+MS 10550.00 89.71 281.40 4059.79 3990.49 6017362.26 550206.47 7962.90 7.00 MWD+IFR+MS 10563.85 89.69 280.43 4059.86 3990.56 6017364.79 550192.86 7970.36 7.00 MWD+IFR+MS 10563.87 89.69 280.43 4059.86 3990.56 6017364.79 550192.84 7970.37 0.00 End Dir : 10563.87' MD, 4059. 10600.00 89.69 280.43 4060.06 3990.76 6017371.09 550157.27 7989.57 0.00 MWD+IFR+MS 10690.00 89.69 280.43 4060.54 3991.24 6017386.77 550068.65 8037.41 0.00 Fault 4 10700.00 89.69 280.43 4060.60 3991.30 6017388.51 550058.81 8042.72 0.00 MWD+IFR+MS 10800.00 89.69 280.43 4061.14 3991.84 6017405.93 549960.35 8095.87 0.00 MWD+IFR+MS 10900.00 89.69 280.43 4061.67 3992.37 6017423.36 549861.89 8149.02 0.00 MWD+IFR+MS 11000.00 89.69 280.43 4062.21 3992.91 6017440.78 549763.43 8202.17 0.00 MWD+IFR+MS 11100.00 89.69 280.43 4062.75 3993.45 6017458.20 549664.97 8255.32 0.00 MWD+IFR+MS 11200.00 89.69 280.43 4063.29 3993.99 6017475.63 549566.51 8308.47 0.00 MWD+IFR+MS 11300.00 89.69 280.43 4063.83 3994.53 6017493.05 549468.05 8361.62 0.00 MWD+IFR+MS 11383.19 89.69 280.43 4064.28 3994.98 6017507.54 549386.15 8405.83 0.00 MWD+IFR+MS 11383.21 89.69 280.43 4064.28 3994.98 6017507.55 549386.12 8405.84 0.00 Start Dir6/100': 11383.21' M 11392.06 90.00 280.00 4064.30 3995.00 6017509.06 549377.41 8410.52 6.01 MPI-19 L 1 T6 11400.00 90.40 279.75 4064.27 3994.97 6017510.36 549369.57 8414.67 6.00 MWD+IFR+MS . . BP Planning Report - BP Company: BP Amoco Date: 5/20/2004 Time: 15:05:42 Page: 5 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-19, True North Site: M Pt I Pad Vertical (TVD) Reference: 69.3 RK8(34.3 + 35) 69.3 Well: Plan MPI-19 Section (VS) Reference: Well (0.00N.0.00E.338.33Azi) Wellpath: MPI-19 L 1 Survey Calculation Method: Minimum Curvature Dh: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/100ft 11423.94 91.62 278.99 4063.85 3994.55 6017514.09 549345.93 8427.02 6.00 MWD+IFR+MS 11423.96 91.62 278.99 4063.85 3994.55 6017514.10 549345.91 8427.03 0.00 End Dir : 11423.96' MD, 4063. 11500.00 91.62 278.99 4061.69 3992.39 6017525.45 549270.76 8465.79 0.00 MWD+IFR+MS 11550.00 91.62 278.99 4060.28 3990.98 6017532.91 549221.35 8491.27 0.00 Fault 5 11600.00 91.62 278.99 4058.86 3989.56 6017540.37 549171.93 8516.76 0.00 MWD+IFR+MS 11700.00 91.62 278.99 4056.03 3986.73 6017555.30 549073.10 8567.73 0.00 MWD+IFR+MS 11747.06 91.62 278.99 4054.70 3985.40 6017562.32 549026.60 8591.72 0.00 MWD+IFR+MS 11747.08 91.62 278.99 4054.70 3985.40 6017562.32 549026.57 8591.73 0.00 Start Dir 6/100' : 11747.08' M 11750.00 91.45 278.94 4054.62 3985.32 6017562.76 549023.69 8593.22 6.04 MWD+IFR+MS 11775.29 90.00 278.50 4054.30 3985.00 6017566.42 548998.67 8606.01 6.00 MPI-19 L1 T7 11775.89 90.00 278.54 4054.30 3985.00 6017566.50 548998.08 8606.32 6.00 MWD+IFR+MS 11775.91 90.00 278.54 4054.30 3985.00 6017566.51 548998.06 8606.33 0.00 End Dir : 11775.91' MD. 4054. 11800.00 90.00 278.54 4054.30 3985.00 6017569.92 548974.21 8618.45 0.00 MWD+IFR+MS 11900.00 90.00 278.54 4054.30 3985.00 6017584.07 548875.23 8668.76 0.00 MWD+IFR+MS 12000.00 90.00 278.54 4054.30 3985.00 6017598.22 548776.24 8719.08 0.00 MWD+IFR+MS 12100.00 90.00 278.54 4054.30 3985.00 6017612.38 548677.26 8769.40 0.00 MWD+IFR+MS 12200.00 90.00 278.54 4054.30 3985.00 6017626.53 548578.28 8819.71 0.00 MWD+IFR+MS ./ 12252.00 90.00 278.54 4054.30 3985.00 6017633.89 548526.81 8845.88 0.00 4 1\2" 12252.81 90.00 278.54 4054.30 / 3985.00 6017634.00 548526.01 8846.28 0.00 MPI-19 L1 T8 , WELL DETAILS Nmœ +N/-S ---FJ-W Northing """'" Latitude Longitude Slot pJanMPI·J9 !038.09 1611.10 60Ü9436.83 55!849J!4 7if26'!!.489N !49''34'38.J36W NlA 50 150 o o 27 ANTI-COLLISION SETTINGS COMPANY DETAILS BP Amoco Interval: 25.00 To: 12252.83 Reference: Plan: MPI-19 LI wpOl From Colour o 7000 7500 8000 8500 9000 9500 10000 10500 11 000 11500 12000 12500 oi~~g 14000 4500 "" MD "" ToMD 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 ki SURVEY PROGRAM fÂ'¢h Fro Depth To SurveyJPInn 7187.00 !2252.83 Plam1ed: MP!-J9 L! wp02 V27 Tool MWD'dFR"-MS ParentWdJp¡¡:lh: TieonMD' WELL PATH DETAILS MPI-J9Ll MP1-19 7J87.QO Rig: Ref Datum: œ.3 RKB(J43 +33) 69.30Jt Origin Origin :..'tarting +N!-S -i-Ei_W FromTVD 338.33" 0.00 OJJO 3430 SECTION DETAILS TVD +N!~S +EJ~W DlÆg TFace VSa': Tar<>"pt MP¡·¡9L! T! MPI-19 Ll T2 MPI-ì9 LI 1'3 MPJ-19 L1 1'4 MPI-19 L1 T5 MPl-19 L1 T6 MPJ-1911 17 MPI·19 L1 1'8 . . BP Anticollision Report Company: BP Amoco Date: 5/20/2004 Time: 15:20:38 Page: 1 Field: Milne Point Reference Site: M Pt I Pad Co-ordinate(NE) Reference: Well: Plan MPI-19. True North Reference Well: Plan MPI-19 Vertical (fVD) Reference: 69.3 RKB(34.3 + 35) 69.3 Reference Wellpath: MPI-19 L 1 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.30 to 12252.81 ft Scan Method: Trav Cylinder North Maximum Radius: 1421.85 ft Error Surface: Ellipse + Casing Survey Program for Definitive Well path Date: 5/6/2004 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 34.30 7187.00 Planned: MPI-19 wp06 V93 (0) MWD+IFR+MS MWD + IFR + Multi Station 7187.00 12252.81 Planned: MPI-19 L 1 wp02 V30 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 12252.00 4054.30 4.500 6.125 4 1\2" Summary < Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt I Pad Plan MPI-19 MPI-19 V3 Plan: MPI-19 7100.00 7100.00 0.00 0.00 0.00 FAIL: NOERRORS M Pt J Pad MPJ-01 MPJ-01 V3 8751.34 4200.00 916.81 159.30 757.51 Pass: Major Risk M PtJ Pad MPJ-01 MPJ-01A V2 9560.88 5100.00 568.79 209.06 359.73 Pass: Major Risk M PtJ Pad MPJ-01 MPJ-01AL1 V6 9500.00 5000.00 568.70 202.52 366.18 Pass: Major Risk M PtJ Pad MPJ-06 MPJ-06 V1 8898.27 4500.00 581.16 196.51 384.66 Pass: Major Risk M PtJ Pad MPJ-08A MPJ-08A V7 10993.53 6200.00 148.35 42.97 105.38 Pass: Minor 1/200 M Pt J Pad MPJ-08 MPJ-08 V1 10028.62 5400.00 82.18 27.08 55.10 Pass: Minor 1/200 M PtJ Pad MPJ-09 MPJ-09 V1 11032.47 5900.00 267.99 204.85 63.14 Pass: Major Risk M Pt J Pad MPJ-09 MPJ-09A V2 11524.00 6200.00 277.46 238.48 38.98 Pass: Major Risk M PtJ Pad MPJ-09 MPJ-09A with IIFR temp 11524.00 6200.00 277.46 No Reference Casings M PtJ Pad MPJ-11 MPJ-11 V1 9700.00 4600.00 1155.33 222.35 932.99 Pass: Major Risk M PtJ Pad MPJ-15 MPJ-15 V5 10393.04 5200.00 1052.01 183.03 868.98 Pass: Major Risk M PtJ Pad MPJ-16 MPJ-16 V1 9900.00 4900.00 875.02 205.98 669.04 Pass: Major Risk M Pt J Pad MPJ-18 MPJ-18 V2 11673.28 6300.00 669.88 220.14 449.73 Pass: Major Risk M Pt J Pad MPJ-19A MPJ-19A V1 8381.73 4200.00 1310.13 130.28 1179.84 Pass: Major Risk M pt J Pad MPJ-19 MPJ-19 V1 12225.95 6300.00 980.32 187.56 792.76 Pass: Major Risk M pt J Pad MPJ-22 MPJ-22 V4 7383.64 4100.00 896.89 111.76 785.14 Pass: Major Risk M PtJ Pad MPJ-24 MPJ-24 V11 Out of range M PtJ Pad MPJ-24 MPJ-24L 1 V4 Out of range M pt J Pad MPJ-24 MPJ24L 1PB2 V3 Out of range M PtJ Pad Plan MPJ-14 Plan MPJ-14 V15 Plan: 10512.75 5900.00 ;07.35 99.98 607.37 Pass: Major Risk M pt J Pad Plan MPJ-14 Plan MPJ-14L 1 V5 Plan: 10512.75 5900.00 707.35 99.98 607.37 Pass: Major Risk M Pt J Pad Plan MPJ-25 old Plan MPJ-25 KlO Plug 0 8494.44 4400.00 228.33 0.00 228.32 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25 option VO 8649.19 4500.00 262.62 0.00 262.62 Pass: NOERRORS M PtJ Pad Plan MPJ-25 old Plan MPJ-25 VO Plan: M 8636.15 4500.00 204.18 0.00 204.18 Pass: NOERRORS M pt J Pad Plan MPJ-25 old Plan MPJ-25PB1 VO Plan 8615.76 4500.00 157.16 0.00 157.16 Pass: NOERRORS M PtJ Pad Plan MPJ-25 Plan MPJ-25 PB1 VO Pia 8729.02 4300.00 182.07 127.89 54.18 Pass: Major Risk M pt J Pad Plan MPJ-25 Plan MPJ-25 VO Plan: M 8740.14 4300.00 243.12 119.87 123.25 Pass: Major Risk M pt J Pad Plan MPJ-26 Plan MPJ-26 V3 Plan: M 6983.67 4100.00 1015.98 121.95 894.03 Pass: Major Risk M pt J Pad Plan MPJ-26 Plan MPJ-26L 1 VO Plan: 6983.67 4100.00 1015.98 121.81 894.17 Pass: Major Risk M PtJ Pad Plan MPJ-26 Plan MPJ-26L2 V1 Plan: 6983.67 4100.00 1015.98 121.81 894.17 Pass: Major Risk M PtJ Pad Plan MPJ-26 RIG MPJ-26 V2 6966.33 4000.00 1015.02 111.61 903.41 Pass: Major Risk M Pt J Pad Plan MPJ-Cipher Plan MPJ-Cipher VO Pia 11683.03 6100.00 626.05 140.22 485.82 Pass: Major Risk M PtJ Pad Plan MPJ-Dozer Plan MPJ-Dozer VO Plan 5955.77 4800.00 28.96 0.00 28.96 Pass: NOERRORS M Pt J Pad Plan MPJ-Jax Plan MPJ-Jax VO Plan: 12246.17 6600.00 664.43 124.10 540.34 Pass: Major Risk M Pt J Pad Plan MPJ-Kali Plan MPJ-Kali VO Plan: 12220.53 5700.00 1252.71 129.74 1122.97 Pass: Major Risk M Pt J Pad Plan MPJ-L Plan MPJ-L V11 Plan: M Out of range M pt J Pad Plan MPJ-L Plan MPJ-LL 1 V6 Plan: Out of range MPtJPad Plan MPJ-N6 Plan MPJ-N6 V10 Plan: 12176.14 5600.00 1209.77 120.48 1089.29 Pass: Major Risk M PtJ Pad Plan MPJ-N6 Plan MPJ-N6L1 V1 Plan: 12176.14 5600.00 1209.77 121.40 1088.37 Pass: Major Risk M pt J Pad Plan MPJ-Y Plan MPJ-Y V5 Plan: MP 10190.32 4600.00 1390.78 112.31 1278.47 Pass: Major Risk M pt J Pad Plan MPJ-Y Plan MPJ-YL1 V5 Plan: 10190.32 4600.00 1390.78 126.71 1264.07 Pass: Major Risk M Pt J Pad Plan MPJ-Zee Plan MPJ-Zee VO Plan: Out of range 1 N Intervals open to OA , - , , MPU 1..19L 1 Proposè' OA Produ PTD # 2041360 . . PERMIT TO DRILL 20 MC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME m¡;?¿,{ :I-(1 L ( PTD# 2ðLf - 13~ V/ Development Service CHECK WßA T APPLŒS ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 6.0-69) Exploration Stratigraphic "CLUE". The permit is for a Dew weJlbore segment of existing well , Permit No, API No. . ProductioDshould continue to be reported as a fUDction 'of the original API number. stated above. HOLE In accordance with 2.0 AAC 25..0.05(1), an records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) .. and API number (5.0 - 7.0/80) from records, data and logs acquired for well (name on permit). Pn.,OT (PH) SPACING EXCEPTION ,. I 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 or.!J.er appro~g Ji/ ~ spacing' e:sception. ~~~~./¡, 1,ø5-. (Company Name) assumes tbe liability of any" protest to,,~ spacing .exctjPtion ¿bJ!!I}Y .f: occur·.tA~ M.W -r¿~"" l ~17~~þ.. .A. - All dry ditch sample sets submitted to tbe Commission must be in no greater ·tbaD 3.0' sample intervab from below tbe permafrost or from where samples are first caugbt and ] 0' sample intervals tbrough target zones. I' . . This pennit does not authorize opening the wellbore to test or regular production, which \J~ ~. requires issuance of a conservation order granting a spacing exception. By commencing . ~ J> X' drilling operations before receiving a spacing exception, Company name assumes the risk ~ )J4J that a spacing exception may not be granted and that Company name may be required to ^ plug and abandon the well without enjoying any benefit from the well. /~ x>(f V \ NOT, : If a s ng ex eption í ) dril ma~ t be issued unt' ~ o Well bore seg Annular Disposal On DEV On/Off Shore Name: MILNE PT UNIT S GeoArea 890 Unit Ml.lltil<ltecal well~ fee W<livedper 20_AAG 25,QO'5(;) iniervaJ iJl ADL 9259_06;TD in ADL 025_517'. Program 11~28 -1£1L1 Wel PEND DEV Surface Ipcaiion <lndJop productjve governed by_ CO 4 Z7 roposed well is 20Q' awayfcornMF>U J-09A in OAs_and. fles GpY!. Qtr-Qtr-Qtr_sect¡on. 1-19L1 alJ<i ex¡stilJ~ Ç.¡) ~~~? - i~_ 4~~ la~------- ~ S"/\G.-O~ .. NA Yes _Ye$ Ye$ Ye$ Ye$ No_ Ye$ Y_e$ Y_e$ Ye$ No_ Yes NA NA NA NA nitial Class/Type MILNE POINT, SCHRADER BLFF OIL - 525140 NC Permit fee attache~ _LeasenIJmber _appropriate Field & Pool _UJliq!.le weltn_arne _and oumb_er JQcated Sc;hradec ell.lft Oil F>ool (5251040) oe$ noLspecity minimum offset NGEXCEPTIONREQUJREQ: _ Q J-01A wellJie in_sJ'lme Qtr~Qtr-Qtr $ectio. S_ufficient Jfdevi<lted OJ)ecator onl~ aff_ected party _OJ)ecator bas.apprppriate_ Þ-ond inJorce _acreage_a_....i,...",.:. 2 3 4 5 6 7 8 9 Administration ina d_efine~ J)po from driJling l.lnitb_olJnd_al)'_ from Qtber wells distance ,"~ '~""'., in_driUiog unit js weJlbc ncJu_ded JQcated proper distance_ JQcated pr_oper Well Wel Wel can be iS$ued wjtbout co_n$ervaiion order can be iS$ued witbout ad_mini$trative apprpvaJ Permit Permit C9mments)_ (For in 10# 15-day wait Wel AJI wei]s_ within J l4JIJile _area_of reyieW id_entified (Fpr $ervjc_e well onl~) Pre-produJ:ed injector; ~l.lrJ'ltio_n_of pre-J)rodl.lc;tipo te$s th<ln:3 months (For service well QnJy) 10 11 12 13 14 15 16 17 Date Appr SFD be approved before JQcated within area and_str<ltaal.lthorized by_ njectiplJ Order # (Put Can permi 7/22/2004 Ml.lltil<ltecal well_bpre Cond!.lc;tor 1\11 ~,." ':<~": 47_. SUI siJlg to be_cemeote<i tp _sl.lrfa_œ tntE te_ c;asing to _be _œmented_ abpve aJ 510 ~r setio rnptherbore. ...,W'-''''''' exernpted 40 CFR 102(b)(3) in_mo_therÞ-ore. _hydrocarbpns in motherbp(ec çOmpletion plJ'loned._ _wells_. J No re$eJ"'le_pjtJ)lanoe_dc AU waste to_CJass Rig iSßquippe_dwith steel_pjt$. prp~imitiy anaJysis performed_. _Nearest weJlboJe is motherbpreJocJ'lled below. BOP stack_ will be iO place_. PlalJn_ed mud weigbts 9.D e 9._6ppg. Expected BHF> 8.5. pre$sure_3_00Q psj Plaoned BOP lest 1467 p$i Calc;uJaiedMASP MPtp_ad is not de_signate<i fp(l-t2S, _Mud_shouJd_ precJu_de J'lO~ H2S_ QnJbe ri~ Rig ha_s senspcs and <llarmsc Ye$ NA Ye$ No No_ Yes Ye$ NA Ye$ NA _Yes Ye$ Yes Yes Ye$ No_ NA ACMP_F"indjngof CQnsistenc;yh_a$ beeMs_sIJed_ fortbis pcojeçt C_ondu_ctor _Surfacec<I$ingpJQtects all known USQW$ oJl_cond_uçtor_ $t(ÎnQpJQvided 8< $UJt csg _CMT v_oj adeQu_ate_ to çirculJ'lle _CMT vol adeQuate_ to tie-in JQngstring lo_sIJrf ~g _CMTwill cover_aU klJown_produc;tiye bQrizons _C_asiog design$ ad_eQuaie fpr c,r, B&_perroafrost been apPJQved re_serve pit JtaJe-drilt bas a_ 10~403 for J'lbandonment Adequate _well bore $eparatio_n -PfopO$ed t meet reguJations_ list Jfdjveder required, does adequate _Drilling fJuid program schem<ltic& equip B_OPEs._dp Jhey meet reguJatipo in_commeot$) Jest lo(puJ C_hokemanifold çompJies_ w/APtRF>-5:3 (May 64) Work will pcc_ur withput p$ig raiiog appropriate; ßOPEpres$ operatJoJlshutdown H2S gas_ probable Meçha_nicaLcpodition pf wel\$ withil) j\QR yerified (Fpr_ service Wf!1J only) -'$ pre&ence_ Qf J-Pads, jn_ SChrader_BluffJe&ewoir$ QU-_or be drilled wjth 9.0 - 9.4 ppg mud. F>a~ wells_ between j 1'00&_ 2300' TYD, Per _S_kip _Coyner, _BPo_n7122l04:_ No H2S [<I)own Expecte<i re$ervoir J)res$uJe is _8c5ppg EMW; wj Ye$ Ye$ NA NA NA Permit c_an Þe iS$ued wlo_ hydcogen_ sulfide meas_ures l:Iydratesh_ave be_en f!Oc;oUlJtered 01) _D_ala_preselJted Qn_ pote_ntial pveJpre&SIJrf! _zOl)es .Seismicanalysjs_ Qf shaJlow gas_zPlJes 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 Engineering AdequJ'lle tan_kage OJ Date 7/26/2004 Appr TEM ~~bV Geology Date 7/22/2004 Appr SFD SPACING EXCEPTION REQUIRED because proposed well violates Rule 2 of CO 477 which requires each drilling unit conform to a quarter-quarter-quarter governmental section. Proposed well and existing well MPU J-09A are open to the OA sand in two of the same governmental quarter-quarter-quarter sections. Notify Skip Coyner of BP via phone. He will submit pplication for Admin. Approval per CO 477, Rule 11. SFD 7/22/2004 (if off-$h_ore) CQntacl narnelphoneJor_wef!l<ly prpgre$sreport$ [e¡cploratpl)'only] Date Engineering Commissioner: Seabed _conditiplJ survey 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 information. . Sperry-Sun Drilling Services LIS Scan Utility . 201-(3(0 $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 15 10:25:34 2004 Ree~e~~~~:r name. . . . . . . . . . . . . LISTPE f ) l OJ (17 Date. . . . . . . . . . . . . . . . . . . . .04/11/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... .... . UNKNOWN Continuation Number......Ol 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 Ll 500292321860 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 8 MW0003258913 R. FRENCH D. GREEN MWD RUN 9 MW0003258923 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 T13 RIO 2319 3521 MSL 0) .00 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 7192.0 . # 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. THIS WELLBORE EXITS MPI-19 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 7192 'MD/4015 'TVD. THE WHIPSTOCK WAS POSITIONED DURING MWD RUN 8. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 3 & 9 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 9 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND PRESSURE WHILE DRILLING (PWD). 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 - 3, 8, 9 REPRESENT WELL MPI-19 L1 WITH API#: 50-029-23218-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12225'MD/4045'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 12167.5 12224.5 12174.5 12174.5 12174.5 12174.5 12174.5 . # 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 8 9 MERGED MAIN PASS. $ MERGE TOP 67.0 254.0 3010.0 7192.5 7218.0 MERGE BASE 254.0 3010.0 7192.0 7218.0 12225.0 # 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 0.26 0.32 0.0853 Max 12224.5 1189.28 127.83 2000 2000 2000 2000 148.31 Mean 6145.75 209.113 71.7094 12.8809 13.7102 14.7852 20.3101 0.772658 Nsam 24316 24225 24202 18416 18416 18416 18416 18416 First Reading For Entire File......... .67 Last Reading For Entire File.......... .12224.5 First Reading 67 112.5 67 2967 2967 2967 2967 2967 Last Reading 12224.5 12224.5 12167.5 12174.5 12174.5 12174.5 12174.5 12174.5 . . File Trailer Service name... ....... ...STSLIB.001 Service Sub Level Name... Version Number. ..........l.O.O 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: 28 -AUG-04 Insite 66.37 Memory 254.0 112.0 254.0 .0 .7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120557 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13 .500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): SPUD MUD 9.15 125.0 8.5 300 10.0 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . .000 .000 .000 .000 .0 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 ReadiI).g 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.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units...........Feet Data Reference Point........... ...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 . Frame Spacing.................. ...60 .1IN Max frames per record. ......... ...Undefined 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 FET RPD RPM RPS RPX Rap $ 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 7192.0 7192.0 7192.0 7192.0 7192.0 7192.0 7192.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 01-SEP-04 . 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 $ 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..................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 Insite 66.37 Memory 7192.0 3010.0 7192.0 . 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 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2965.5 7192 5078.75 8454 2965.5 7192 ROP MWD030 FT/H 0.43 850.17 250.927 8364 3010.5 7192 GR MWD030 API 20 127.83 67.9382 8454 2965.5 7192 RPX MWD030 OHMM 0.22 215.42 10.282 8451 2967 7192 RPS MWD030 OHMM 0.07 2000 11.7685 8451 2967 7192 RPM MWD030 OHMM 0.26 2000 13 .1023 8451 2967 7192 RPD MWD030 OHMM 0.32 2000 21. 9346 8451 2967 7192 FET MWD030 HOUR 0.0853 34.6967 0.79037 8451 2967 7192 First Reading For Entire File....... ...2965.5 Last Reading For Entire File........ ...7192 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 ROP $ 5 header data for each bit run in separate files. 8 .5000 START DEPTH 7192.5 STOP DEPTH 7218.0 # 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: 07-SEP-04 Insite 66.37 Memory 7218.0 7192.0 7218.0 72.4 72 .4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER . $ # 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.750 7192.0 Oil Based 9.20 80.0 .0 38000 .0 .000 .000 .000 .000 Name Service Order DEPT ROP MWD080 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD080 FT/H Min 7192.5 0.58 Max 7218 15.19 First Reading For Entire File......... .7192.5 Last Reading For Entire File........ ...7218 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 Mean 7205.25 6.89846 Nsam 52 52 . .0 82.4 .0 .0 First Reading 7192 . 5 7192.5 Last Reading 7218 7218 . 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 RPM RPS RPX GR FET ROP $ 6 . header data for each bit run in separate files. 9 .5000 START DEPTH 7192.5 7192.5 7192.5 7192.5 7192.5 7192.5 7218.5 STOP DEPTH 12174.5 12174.5 12174.5 12174.5 12167.5 12174.5 12225.0 # 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 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: # 10-SEP-04 Insite 66.37 Memory 12225.0 7218.0 12225.0 72.4 93.3 TOOL NUMBER 160788 90518 6.750 7192.0 Oil Based 9.10 83.0 .0 120 .0 .000 .000 .000 .000 .0 114.8 .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 . lIN Max frames per record............ . Undefined Absent value......... . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7192.5 12225 9708.75 10066 7192.5 12225 ROP MWD090 FT/H 0.85 1189.28 193.597 10014 7218.5 12225 GR MWD090 API 42.1 120.27 78.6806 9951 7192.5 12167.5 RPX MWD090 OHMM 4.83 2000 15.085 9965 7192.5 12174.5 RPS MWD090 OHMM 5.11 1731. 46 15.3569 9965 7192.5 12174.5 RPM MWD090 OHMM 5.23 1718.89 16.2123 9965 7192.5 12174.5 RPD MWD090 OHMM 4.03 2000 18.9324 9965 7192.5 12174.5 FET MWD090 HOUR 0.22 148.31 0.757637 9965 7192.5 12174.5 First Reading For Entire File....... ...7192.5 Last Reading For Entire File.......... .12225 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................~OWN 4IÞ 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
