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Home My WebLink About190-010David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type MPU C-04 500292080100 182-126 2/27/2021 Wipestock MPU I-07A 500292260201 221-010 5/8/2021 Perf Record MPU L-06 500292200300 190-010 5/18/2021 Wipestock MPU S-21 500292306500 202-009 6/3/2021 Perf Record MPU F-116 500292365000 219-133 1/25/2020 Perf Record MPU I-19 500292321800 204-135 4/10/2020 CCL Please include current contact information if different from above. eceived By: 07/22/2021 37' (6HW By Abby Bell at 3:14 pm, Jul 22, 2021 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type MPU L-06 50029220030000 190010 5/26/21 Caliper Survey MPU J-23A 50029229700100 215154 7/3/21 Injection Profile MPU E-12 50029232620000 205067 6/26/2021 Coil Flag MPU J-24A 50029229760100 216120 7/4/21 Injection Profile Please include current contact information if different from above. eived By: 07/13/2021 37' (6HW By Abby Bell at 3:30 pm, Jul 13, 2021 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: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 21.0' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 13-3/8" H-40 115' 9-5/8" J-55 4,590' 7" L-80 7,299' 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 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 10,472'4-1/2" 12.6# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 328 sx Class 'G' 30" Surface 6,314'1469 sx PF 'E', 410 sx Class 'G' 485 sx PF 'C' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 5/23/2021 2119' FNL, 318' FWL, Sec. 08, T13N, R10E, UM, AK 2369' FSL, 1270' FWL, Sec. 04, T13N, R10E, UM, AK 190-010 / 321-042 Milne Point Field / Kuparuk Oil Pool 56.0' 10,561' / 6,998' HOLE SIZE AMOUNT PULLED 50-029-22003-00-00 MPU L-06 544920 6031351 2129' FSL, 922' FWL, Sec. 04, T13N, R10E, UM, AK CEMENTING RECORD 6035636 SETTING DEPTH TVD 6035879 BOTTOM TOP 8-1/2" Surface 12-1/4"Surface CASING WT. PER FT.GRADE 550763 551109 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 26# Surface DEPTH SET (MD) 10,356' / 6,881' PACKER SET (MD/TVD) 48# 36# 115' Surface 11,068' Gas-Oil Ratio:Choke Size: Set Whipstock (Fell) 10,561' Set Whipstock Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing Oil-Bbl: 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 10,582' N/A DITE / CNL / LDT / NGT / Cyberlook / Gyro / GR / CCL Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 3/19/1990 3/7/1990 ADL 025509, 047434 88-002 1800' (Approx.) N/AN/A None 11,091' / 7,313' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 1:13 pm, Jun 17, 2021 RBDMS HEW 6/21/2021 Abandonment Date 5/23/2021 HEW xG DSR-6/21/21DLB 06/21/2021 SFD 6/24/2021 MGR28JUN2021 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 10566' 7001' 10426' 6921' 10566' 7001' 10584' 7011' 10800' 7137' Kup A 10800' 7137' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 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: FORMATION TESTS Permafrost - Top 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. Summary of Pre-Rig Work, Drilling Report, Wellbore Schematic Signature w/Date: 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. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: Kuparuk B 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 Kuparuk A Kuparuk D Kuparuk C The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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. INSTRUCTIONS 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, 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. 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. 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 6.17.2021 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.06.17 11:13:46 -08'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 6/3/2021 SCHEMATIC Milne Point Unit Well: MPU L-06 Last Completed: 2/18/2021 PTD: 190-010 TD =11,091’ (MD) /TD = 7,313’(TVD) Halliburton HOS Cementer at 1,881’ Baker 4-1/2”x7”WS fell to 10,582’ Orig. KB Elev. = 56’ Ground Elev. = 21’ RKB-THF: 23.95’ (Doyon 16) 7” 3 5 7 Est. TOC at 8,820’ 9-5/8” TOC @10,600’ Est. TOC at 2,000’ 6 PBTD =10,561’(MD) / PBTD =6,998’(TVD) KUP C/B Sands KUP A Sands Arctic Pack RA Tag at 10,304’ Top of window @ 10564’ 4 Baker 4-1/2x7” WS set @ 10561’ 2 1 ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48# / H-40 / Weld 12.715 Surface 115' 0.157 9-5/8" Surface 36# / J-55 / BTC 8.921 Surface 6,314’ 0.0773 7" Production 26# / L-80 / BTC 6.276 Surface 11,068’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6# / L-80 / TXP BTC 3.92 Surface 10,472’ 0.0152 JEWELRY DETAIL No Depth Item 1 31’ 4-1/2” Tubing Hanger 2 10,280’ Gauge Carrier 3 10,288’ HES X-line Sliding Sleeve, 3.813” Seal Bore ID 4 10,296’ Ported Pressure Sub 5 10,356’ 7” X 4-1/2” Premier Production Packer 6 10,425’ X Nipple, 3.813” 7 10,434’ WLEG, bottom at 10,472’ PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C1/B6 10,566’ 10,593’ 7,001’ 7,016’ 27 11/21/1990 Closed KUP B6 10,632’ 10,662’ 7,039’ 7,056 30 11/20/1990 Closed KUP B6 10,678’ 10,693’ 7,065’ 7,074’ 15 11/20/1990 Closed KUP B6 10,714’ 10,724’ 7,086’ 7,092’ 10 11/20/1990 Closed KUP A3 10,800’ 10,821’ 7,137’ 7,150’ 21 11/20/1990 Closed KUP A2 10,834’ 10,878’ 7,158’ 7,184’ 44 11/20/1990 Closed KUP A1 10,900’ 10,904’ 7,197’ 7,200’ 4 11/20/1990 Closed OPEN HOLE / CEMENT DETAIL 30” 485 sks Permafrost ‘C’ 12-1/4" 1469 sx Permafrost E, 410 sx Class ‘G’ 8-1/2” 328 sx Class ‘G’ WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 57° @ 4,600’ Max Hole Angle through perforations = 55° TREE & WELLHEAD Tree 4-1/16” 5K CIW (dry hole) Wellhead FMC 11"x 4-1/2" Hanger, 4.5" TCII top/btm w/ 2- 3/8'' ports GENERAL WELL INFO API: 50-029-22003-00-00 Drilled and Completed by Pool Rig 102 - 11/27/1990 ESP RWO by Rig 4 – 9/25/1993 ESP RWO by Nabors 4ES – 11/21/1998 ESP RWO by Nabors 4ES – 4/9/2001 ESP RWO by Nabors 4ES – 6/17/2005 ESP RWO by Nabors 4ES- 7/9/2007 ESP RWO by Nabors 3S- 11/28/2008 Pull ESP, set CIBP, Run Killstring by Doyon 16 - 5/21/2012 RWO by Doyon 14 – 2/19/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 2/12/2021 Continue BOP testing. Tests performed to 250 PSI low / 4,000 PSI high, held for 5 min ea. charted. 10) 2-7/8 "x 5" upper VBR w/ 4.5" test joint & Upper IBOP. 11) 2-7/8 "x 5" lower VBR w/ 4.5" test joint & Lower IBOP. 12) Choke valves 3 & blind rams. 13) Super choke A. 14) Manual choke B. Perform accumulator test: 3,100 PSI system pressure, 1700 PSI after closure, 200 PSI attained 34 sec, 3,100 psi attained 169 sec, 6 N2 bottle avg, 2,100 psi. Test gas, PVT and flow alarms. Lower 2-7/8'' x 5'' VBR failed hi pressure test on 4-1/2" test jt, seeing, very slight flow above ram. BD lines, drain stack, PJSM, remove lower 2-7/8'' x 5'' VBRs, C/O packer element and top seals, re-install same. Flood stack and lines, attempt to re-test lower VBR rams on 4-1/2" test joint, pressure to 4,000 psi, troubleshoot pressure bleed off, WHR check LDS and test hanger seals to 4k, good, Re-test lower VBR on 4-1/2" and 2-7/8'' test joints to 250/4,000 psi 5 min ea, charted, good test. BD lines, R/D TEST Equipment. Move Co. Man Office/Camp from J-Pad to L-Pad. BD lines, R/D test equipment, Drain stack, M/U T-Bar. Troubleshoot Hydraulic leak on top drive rotating link adaptor, grease RLA to energize seals stopping hydraulic leak. WHR pull BPV dart then BPV. C/O elevators too 4" and make up 4" DP landing joint, 4" pup jt & cross over to 4-1/2" IBT. Make up landing jt to tubing hanger. WHR BOLDS. Pull tubing hanger to Rig floor. Hanger unseat smooth with 85k PUW. Mobilize 2-7/8" handling equipment to Rig floor and rig up to lay down tubing. Lay down tubing hanger, landing joint, pup joint and crossover. Change elevators to 2-7/8". POOH laying down 2-7/8", 6.5#, L-80 EUE kill string f/ 10,030' t/ 880'. Hole taking proper fill. Hilcorp Alaska, LLC Weekly Operations Summary 2/11/2021 N/U BOP stack & torque all BOP flange bolts w/ Sweeny wrench. Install kill line, accumulator hoses, turnbuckles & riser. Install 30' mousehole. Mobilize test joint to the rig floor. Fill BOP stack w/ water. Perform 250 PSI / 2,500 PSI shell test on 2- 7/8” test joint w/ annular -good test. Perform initial BOP test, AOGCC inspector Austin McLeod waived witness on 2/11/21 @ 14:59. All tests performed with fresh water against a tbg hanger, with BPV and test dart installed. Annular tested to 250 psi low / 2500 psi high and held for 5 min. & charted. All remaining test performed to 250 PSI low / 4000 PSI and held for 5 min. & charted. 1) Annular w/ 2.875" test joint. 2) 2-7/8 "x 5" upper VBR w/ 2.875" test joint, choke valves 1, 12, 13, 14, kill line valve #20 & 3.5" FOSV. 3) Choke valves 9, 11, kill HCR, 3.5" dart valve. 4) Choke valves 5, 8, 10, kill Manual, 4" FOSV valve. 5) Choke valves 4, 6, 7, 4” dart valve. 6) Choke valve 2. 7) Choke HCR. 8) Choke Manual. 9) 2-7/8 "x 5" lower VBR w/ 2.875" test joint & 5" FOSV #2. Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 Hilcorp Alaska, LLC Weekly Operations Summary Continue TOOH L/D 2-7/8'' kill string from 880' to surface, break out and L/D mule shoe. Correct displacement on TOOH. Clear and clean rig floor, R/D 2-7/8'' handling equipment and power tongs, R/U 4'' handling equipment. PJSM. M/U cleanout BHA, 6-1/8'' MT bit, no jets, bit sub w/ flt, 4-3/4'' DCs, Jar, XO to 142', drift, P/U and single in the hole w/ 30 jts 4'' XT39 DP to 1,089', fill DP, BD TD. P/U 7'' Baker retrievable storm packer and XOs, RIH with 3 joints 4'' DP, set storm packer with top @ 93', center of elements @ 100.71', release and rack stand back. Flood lines, close blind ram, pressure up and test packer to 3,500 psi, good, BD choke and kill lines, open blind ram, vac out stack. PJSM, Load new FMC wellhead into cellar. ND BOP stack, kill line, bell nipple, BOP anchors, set on pedestal, install new 11'' FMC wellhead @ per WHR onto existing WKM wellhead. N/U BOP, set stack, torque 2 sets flange bolts, re-install riser, anchors and kill line. Record new RKBs, install 9'' ID wear bushing, RI2LDS, R/U chart recorder and test pump. Close blind ram. Pressure test 2 flanges on new wellhead to 250 psi low and 4,000 psi hi 5 min ea, charted, good test. PT kill line to 250 psi low, 4,000 psi hi 5 min ea, charted, good. R/D test equipment, BD lines, open blind rams. RIH with stand DP, M/U FOSV. Make up stand to storm packer and check for pressure - no trapped pressure. Shut annular and release packer. Read 0 pressure at choke. Lay down storm packer and blow down lines. RIH picking up 4" drill pipe singles from shed f/ 1,183' t/ 4,909'. Fill pipe every 2,000'. Proper displacement recorded. 96k PU / 90k SO. Continue RIH picking up 4" drill pipe singles from shed f/ 4,909' t/ 10,375'. POOH f/ 10,375' t/ 10,090' racking 3 stands in Derrick to drill cement with. Continue RIH picking up 4" drill pipe singles. Tag TOC @ 10,408'. Proper displacement recorded. 2/13/2021 2/14/2021 PJSM, Pump 30 bbl hi vis spacer, displace the well to 11.3 ppg LSND mud from 10,406', pumping 6 bpm, 970 psi, 30 rpm, 5- 6 k torque working the pipe 90', take 8.3 source water returns to rock washer until clean mud @ returns, 393 bbls pumped, 14 bbls over calculated displacement. PU 145K, SO 110K. PJSM, slip and cut 79' drilling line, re-calibrate block height, service TD and drwks. Obtain new parameters, SPRs, Drill cement from 10,408' to 10,410', drill cement retainer to 10,413', pumping 250-300 gpm, 1,350 psi, 40-50 rpm, 6-9k torque, 5-19k wob. S/O rotating tagging up at 10,421', continue to drill on retainer junk to 10,430'. Note: seeing some cement and plug rubber at returns. PU 145K, SO 110K, ROT 130K. Drill hard cement f/ 10,430' to 10,600', 350 gpm, 2,200 psi, 60 rpm, 6-12k torque, 12-18k WOB, PU 155K, SO 90K, ROT 115K. Pump 30 bbl hi vis sweep. Back on time with 25% increase in cuttings. Shakers blinding with cement cuttings and barite. Cement contamination cause high pH in mud which reduced the viscosity and causing barite sag. Mud wt. drop to 10.5 ppg. Circulate and condition mud, drop pH from 12 to 9.5-10, increase vis from 35 sec/qt to 55 sec/qt and build md wt back to 11.3 ppg. Obtain SPR's. B/D TopDrive & Monitor Well, Static. Observe very thick column of mud around drillpipe at flowline while monitoring Well. Sample shows to be thick barite sag. Attempt to drain stack to flush clean and packed off at annulus valve. Free blockage, drain stack and wash clean from top. Lay down 3 joints drillpipe and RIH with stand from Derrick. Tag TOC on depth @ 10,600'. Pump weighted hi vis sweep around. 380 GPM, 115RPM. Back on time with slight increase in cuttings being mostly cement wall cake. SimOps: Bring 4-1/2" handling equipment to rig floor. Blow down, Monitor Well - Static. POOH f/ 10,600' t/ 10,369', laying down 4" drill pipe to shed. Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 Hilcorp Alaska, LLC Weekly Operations Summary LD jt 67, held PJSM, POOH to inspect HES AHR 7'' x 4-1/2" packer L/D 4.5" 12.6# L-80 TXP completion string f/ 2,741' to 185' at the gauge carrier, L/D joint # 8 due to damaged pin threads. Found several small pieces retainer junk on joint collars 5-4 and 3, correct displacement on TOOH. Replace tubing seal rings. Centrilift remove tech wire, L/D gauge carrier. L/D jt, inspect packer, shear pins on slip cage have sheared, note: found several 1/4'' pieces of brass on slips and packer element, some scarring on slip cage carrier. Notify town Engineer, decision made to run completion with new packer assy. Monitor the well while waiting on new packer assembly to arrive, finish replacing seal rings on 4-1/2" tubing L/D. Cleanup up the rig floor, service rig equipment, inspect top drive. Mobilize packer to the pipe shed,warm up and verify dimensions. M/U Halliburton 4-1/2" x 7" AHR packer assembly, joint #3 and BakerHughes gauge carrier assembly with sliding sleeve to 196'. Test TEC wire - good. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 196' t/ 3274'. Tripped past 2,845' without taking weight. Took 6K weight at 3,021'. P/U break string over & set 5K again at 3,021'. P/U 33' (70K PU / 67K SO) then work past 3,021' with 3 to 4K bobble. Torque connections to 6,170 ft/lbs with Doyon double stack tongs. Install Cannon clamps every other connection. Test TEC wire at 1,000' & 3,000'. Mud running over pipe last 10' of each joint. Kick drill - well secure in 1 min 35 sec and all hands responded in 2 min. Pump 10 bbls 13.3 ppg slug to cap tubing and prevent mud from running over. 2 BPM, 300 PSI ICP / 150 PSI FCP. R/D circulating head and blow down lines. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/3,274' t/ 4,326'. Completion assembly took 8K weight at 4326'. Torque connections to 6,170 ft/lbs with Doyon double stack tongs. Install Cannon clamps every other connection on TEC wire. P/U 5', S/O & stack out again at 4,326'. P/U 30' to 4,296', S/O & took 6K at 4,302'. P/U, S/O & took 5K at 4,306'. Work down slowly to 4,326' & repeatedly tagged 3 times with 8K. L/D joint to 4,323'. P/U 40' to 4,282', then S/O to 4,290' where took 5K. 81K PU / 72K SO. Consult w/ engineer, decision made to POOH and inspect packer. POOH with 6-1/8'' cleanout BHA f/ 10,369' t/ 4,309', laying down 4" drill pipe to shed. Continue POOH with 6-1/8'' cleanout BHA f/ 4309' t/ 142', laying down 4" drill pipe to shed, L/D Cleanout BHA, 6-1/8'' bit grade = 1-2-JD-G-E-I-NO-DP. Remove float from bit sub. Correct displacement for TOOH. Clear rig floor. M/U running tool, BO2LDS, pull 9'' ID wear bushing. M/U jet tool, jet BOP stack and clean flowline. Make tubing hanger dummy run as per WHR. Lay down landing jt. R/U 4.5” handling equipment. M/U FOSV t/ XO & verify make up on jt. Rig up Centrilift TEC wire spool and sheave. PJSM. P/U WLEG shoe jt, XN nipple, jt 4.5” tubing, HES AHR Packer and jt 4.5” tubing to 157’. M/U Baker Zenith gauge carrier, HES X-Line Sliding sleeve, XO’s & ported pressure sub assembly to 193'. RIH w/ 4.5" 12.6# L-80 TXP BTC completion string f/ 193' to 2,845'. String take 20k wt set down @ 2,845’ pick up 24’ free and set back down at same depth with 10k two times. 1 cannon clamp installed @ gauge carrier, ½ cannon clamp between sliding sleeve and gauge carrier, one every jt 4- 8, then on every other joint. Test tec wire at 1,000' & 2,845’. Torque to opt @ 6,170 ft/lbs. PU 68K, SO 65K . No loss / No Gain on trip in. Pull out and lay down two joints t/ 2,780'. Pull up to 2,741' free, slack off and take 10k wt @ 2,762'. Pick u p 10' slowly , slack off and take 10k wt at 2,757'. Pick up and slack off taking wt at 2,763'. Discuss situation with Town Engineer. Decision made to POOH and inspect Packer. 2/16/2021 2/15/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 Hilcorp Alaska, LLC Weekly Operations Summary 2/17/2021 Ready the pipe shed and rig floor. PJSM, POOH to inspect HES AHR 7'' x 4 1/2'' packer L/D 4.5" 12.6# L-80 TXP completion string f/ 4,282' to 196' at the gauge assembly L/D and separate jt #67- damaged pin threads. Correct displacement on trip out. Centrilift remove TEC wire, L/D gauge carrier. L/D jt, inspect and L/D packer assy, Shear pins on slip cage have sheared, Pull the X-nipple assembly and mule shoe to inspect same, good, set back in the hole. Found 2-1/4" x 3/4'' and 2 smaller pieces wedged under bottom element, fairly deep gouge on lower portion of packer body. Load out HES packer, Monitor the well, while waiting on Baker premier packer assembly to arrive, clear and cleanup the rig floor, C/O seal rings on 4 1/2'' tubing in the shed. Baker packer arrived @ 14:00, Load packer into shed, strap and warmup same, PJSM, M/U Baker 7'' x 4 1/2'' premier packer assembly as per Baker rep, verify set shear @ 1,650' and 2100 psi, M/U joint #3 and Baker Hughes gauge carrier assembly with sliding sleeve to 201'. Test TEC wire - good. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 201' to 5,345'. Torque connections to 6170 ft/lbs with Doyon double stack tongs. Install Cannon clamps every other connection. Test TEC wire at 1,000' then every 2,000'. 87K PU / 76K SO. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 5,345' to 6,519'. Began seeing 4-6K drag f/ 6386' & 3K overpull at 6510'. Torque connections to 6170 ft/lbs with Doyon double stack tongs. Install Cannon clamps every other connection. Test TEC wire every 2,000'. 103K PU / 78K SO. Rig up XO, FOSV and circulating head. Close annular & reverse circulate 1.5x tubing volume. Stage up from 1 BPM, 460 PSI to 4.3 BPM, 660 PSI. No debris observed across the shakers or found on possum belly magnet. No barite sag observed on returned mud. Test TEC wire after closing annular - good. Run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 6,519' to 6,802'. Torque connections to 6,170 ft/lbs with Doyon double stack tongs. Install Cannon clamps every other connection. Test TEC wire every 2,000'. Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 Hilcorp Alaska, LLC Weekly Operations Summary 2/18/2021 Continue to run 4-1/2" 12.6# L-80 TXP-BTC tubing f/ 6,802' seeing 3k drag and several 4-5k bobbles, at 7,435' seeing 8k set down, 10k overpull work past to 7453'. Torque connections to 6,170 ft/lbs with Doyon double stack tongs. Install Cannon clamps every other connection. Test TEC wire every 2,000'. PU 115K, SO 80K. R/U XO, FOSV and circulating head , close annular, reverse circulate, stage pump f/ 1 bpm, 500 psi slowly to 7 bpm, 1,190 psi then circulate 2 tubing volumes. At BU seeing trace settled out bar and fine scale at shakers, circulate until clean. BD and R/D reverse line, open annular. Continue to run 4-1/2" tubing f/ 7,453', 8k set down @ 7,536' w/ 5k overpull, work past easily, continue RIH to 8,464' with no other issues. Test TEC wire every 2,000', Torque connections to 6,170 ft/lb, Install Cannon clamps every other connection. PU 125K, SO 83K. Continue to run 4-1/2" tubing f/ 8,464', 10k set down @ 8,775', P/U and work thru easily, continue to see numerous 3-5k bobbles, RIH to 10,593', at joint 260. Test TEC wire every 2,000', Torque connections to 6,170 ft/lb, Install Cannon clamps every other connection. PU 152K, SO 85K. R/U XO, FOSV and circulating head, close annular, reverse circulate, stage pump slowly f/ 1 bpm, 730 psi to 4 bpm, 1,450 psi. Reverse circulated a surface to surface volume. Got 13.1+ ppg at BU. Shut down, mud out of balance and running over the tubing. Circulate a tubing volume to achieve balance, 11.2 ppg in / out. L/D 4 joints from 10,593' to 10,437'. TEC wire began hanging up, P/U 40' to next cannon clamp to check wire - good. Slack off to 10,437'. Change elevator to 4", M/U tubing hanger, XO subs and 4" landing joint. Perform hanger penetration with TEC wire. Final readings: Pt 4,143.95, Pa 4,139.33, Tt 134.5°, Ta 134.0°, Vx 0.119, Vz 0.144, voltage 19.6. 256 joints of tubing, 133 cross coupler and 1 mid-joint Cannon clamps ran. Land tubing string on hanger,152K PU / 85K SO (45K on hanger). Run in lock down screws. Laydown landing joint. Dry rod BPV. Clean and flush flow line before N/D. PJSM. Pull riser, remove kill line. N/D BOP and rack back on stump. Install test dart in BPV. Clean tubing hanger. Install adapter flange and perform TEC wire penetration. N/U dry hole tree. Test tubing hanger void to 500 PSI for 5 min and 5,000 PSI for 10 min. - good test. Test tree to 250 PSI for 5 min and 5,000 PSI for 5 min. - good test. Remove BPV/test dart from hanger. PJSM. R/U lines and squeeze manifold to reverse circulate. Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 Hilcorp Alaska, LLC Weekly Operations Summary 2/19/2021 Finish R/U to reverse in corrosion inhibited sea water and diesel freeze protect, PJSM, Flood and test lines to 2,000 psi. Line up to pump down I/A, pump 30 bbl spacer, 121 bbls seawater, 146 bbls CI sea water, followed with 84 bbls diesel. Stage f/ 2.5 to 4 bpm, 1,730 psi, then line up and pump diesel off vac truck 3bpm, 880 psi. Take mud returns and spacer out tubing to rock washer. With SW returns, shut down. Shut in tubing and I/A, R/U and let tubing x IA U-tube for 1 hr freeze protecting the IA and tubing to 2,500'. Simops: off load and clean in pits. Bleed off tbg and IA from 200 to 0 psi, shut in same, vac out lines with vac truck, remove circ line from top of tree at otis connection, set ball and rod in tree. Open master valve, drop 1 7/8'' ball and rod, close MV, M/U circ line at otis connection, R/U chart recorder and test pump. Flood lines with diesel, test lines to 3500 psi, good. Using test pump, pump diesel down tubing setting the 7'' x 4 1/2'' premier packer as per Baker rep, pressure up seeing 1st shear @ 1,720 psi, 2nd shear @ 2,375 psi, hold 2800 psi 5 min. Pressure to 3,500 psi testing 4 1/2'' tubing for 30 charted min. IA holding at 250 psi- good, bleed off tubing to 2,000 psi. Pressure test IA to 3500 psi for 30 charted min, tubing holding 2,600 psi- good, bleed IA & tbg to 0 psi. Secure tree. Blow down, R/D lines and squeeze manifold, continue to clean in pits. R/D & M/O to L-25. 4/14/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 200L/2500H. MAKE SEVERAL RUNS USING 10' x 3" PUMP BAILER, AND 5' x 3-1/2" DRIVE DOWN BAILER, FROM 10,478'SLM (10,496' MD)TO 10,498' SLM (10,514, MD). TAG TUBING TAIL @ 10445' SLM +16FT CORRECTION=10461' MD. WELL S/I ON DEPARTURE, WELL SECURED, PAD OP NOTIFIED. 4/18/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 200L/2500H. MADE TWO RUNS USING 10'x3" PUMP BAILER, FROM 10,462'SLM TO 10500'SLM (38 FEET). WELL SI ON DEPARTURE, WELL SECURED PAD OP NOTIFIED. 4/20/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 200L/2500H. MADE FIVE RUNS USING 10'x3.5" PUMP BAILER, FROM 10,481'SLM TO 10,493'SLM (first bailer run sat down at 10420 and broke through a bridge). WELL SI ON DEPARTURE, WELL SECURED PAD OP NOTIFIED. 4/21/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 200L/2500H. MADE 1 RUN USING 10'x3.5" PUMP BAILER AND 4 RUNS USING 10'x3.5" DRIVE DOWN BAILER, FROM 10,494'SLM TO 10,504'SLM (10 FEET). WELL SI ON DEPARTURE, WELL SECURED PAD OP NOTIFIED. 4/22/2021 CONTINUE WSR FROM 4/21/21. P/T PCE 250L / 2500H. MADE 2 RUNS W/ 10' x 3.50" DRIVE DOWN BAILER FROM 10,499' SLM TO 10,507' SLM. RECOVERED 6 gallons OF BAR (slurry type consistency). 4/23/2021 P/T PCE 250L/2500H. MADE 3 RUNS W, 10' x 3.50" DRIVE DOWN BAILER FROM 10,504' SLM TO 10,510' SLM. RECOVERED 9 gallons OF BAR (slurry type consistency). WELL SHUT-IN ON DEPARTURE, NOTIFIED PAD OP. Well Name Rig API Number Well Permit Number Start Date End Date MP L-06 Doyon 14 50-029-22003-00-00 190-010 2/11/2021 5/15/2021 Hilcorp Alaska, LLC Weekly Operations Summary 5/15/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. DRIFT TBG WITH 20'x3.70" DUMMY WHIPSTOCK, 4- 1/2 TEL, 1.75" SAMPLE BAILER (bailer empty). LOCATE TT @ 10467' SLM/10472' MD (5' SLM correction), TAG TD @ 10610' SLM/10615' MD (hard bottom). RDMO, CLOSE PERMIT W/PAD-OP. 5/10/2021 MIRU Coiled Tubing Unit with 1.75" coil. Pump 1.188" ball around coil. Test BOPE to 250 psi low/4000 psi high. MU and RIH with 1.80" Down Jet Nozzle. Have soft tag at 10,560' ctmd. PUH to Tubing Tail and start jetting with slick KCl water and PowerVis pills. Pump gel pills and tag TOC at 10,599' ctmd. Pump final gel pill and chase out of hole. Freeze protect from 2100' MD to surface with 60/40 MeOH. RDMO. Activity Date Ops Summary 5/21/2021 Move rig to MPL-06A. Finish location prep in well cellar. Stage rig for backing over well Back rig over well and set down. Install cribbing and herculite in cellar area Accept rig at 21:30. Prep and lower 2" reel from rig. Install scaffolding in cellar area to access tree. Close in cellar and begin warming up Load and secure 2-3/8" reel onto rig. Install saddle clamps. Install Managed Pressure line in cellar. ND tree cap and prep to NU BOPE. 5/22/2021 Nipple up BOPE. PJSM with crane operator. Swap goosenecks from 2.0" to 2-3/8". RU pressure bulkhead and inner reel iron. Swap out gripper blocks. Swap risers on injector. On highline power at 09:15. RU Flowback tank. Dress stripper with correct brass and packoff. Pull coil across and stab. Test LEL and H2S alarms. MU CTC. Pull test to 50K. MU BHI, Grease and service all valves. Complete valve alignment checklist. Repair leak on Koomey (NPT fitting). Fluid pack all surface lines, coil reel and BOPE stack with 85 bbls fresh water Begin required BOPE test. BOP test witness was waived by AOGCC rep Lou Laubenstein on 5-22-2021. Test #1: IRV, Pack-off, C7, C9, C10, C16. 250/3500 psi Pass. Test #2: Blind/Shear, R2, BL2 and C15 Bleed off and tighten 7" R46 flange at bottom of BOP. Re- test. Pass. Test #3: Ann, TIW #1, B4, B3 Test #4: Upper 2-3/8" Pipe/Slips, TIW #2, B2, B3. Test #5: Lower 2-3/8" Pipe/Slips, C5, C6, C8, Test Valve 2. Test #6: Choke A, Choke C Drawdown Test on Accumulator. Test #7 Annular (3.0") C1, C4, TV1. Test #8 3" Pipe /Slips C2, C3 Clean and clear rig floor. RD BOPE test equipment and prep to PU window milling BHA. 5/23/2021 Clean and clear rig floor. Pressure test PDL's. Install floats in UQC. PT to 3500#. Good test. Load reel with 14 bbls 60/40 Methanol followed by 1% Slick KCL. Open well to closed choke. Well had 650# trapped pressure. Bled off. Perform 30 min no-flow check. Well static Make up window milling BHA. with 3.80" NoGo / 3.81 Go on both string reamer and window mill. Rih circulating 1% Slick KCL (120 deg). Rate in: 0.25 bpm, Rate out: 0.53 bpm. MW in: 8.33 ppg, MW out: 7.50 ppg Taking returns to tiger tank. Log tie in from 10300' to 10441.78' MD with a -22' Inadvertently opened sliding sleeve running in hole. Swap to 9.0 ppg Black mud. Free Spin: 2.68 bpm @ 3610 psi. Rate in: 2.68 bpm, Rate out: 2.72 bpm Circulating pressure: 3610 psi to 3702#. MW in : 9.04 ppg, MW out: 8.86 ppg Window ECD: 11.86 ppg. Mill Window f/10582' t/10583.6' Continue Milling Window f/10583.6 t/10589.6'. Rate in 2.7 bpm, Rate out 2.7 bpm. Circulating pressure 3810 psi to 3840 psi. MW in: 9.00 ppg, MW out: 8.78 ppg. Window ECD: 11.81 ppg. WOB - 1.5k to 3k Continue Milling Window f/10589.6' t/10600'. Decrease in WOB and Differential pressure noted. Light formation sand noted in bottoms up sample. -Rate in 2.7 bpm, Rate out 2.7 bpm. Circulating pressure 3750 psi to 3760 psi. MW in: 9.00 ppg, MW out: 8.78 ppg. Window ECD: 11.82 ppg. WOB - 1.6k to 2k Finish milling 10' rat hole to 10600'. Backream with as-milled TF(25° ROHS) at 1fpm. Rate in 2.7 bpm, Rate out 2.83 bpm. Circulating pressure 3615 psi to 3700 psi. MW in: 9.00 ppg, MW out: 8.78 ppg. Window ECD: 11.80 ppg. WOB - 1.6k to 2k Backream 15° left of as-milled. Backream 15° right of as milled. Rate in 2.69 bpm, Rate out 2.83 bpm. Circulating pressure 3583 psi to 3647 psi. MW in: 9.00 ppg, MW out: 8.79 ppg. Window ECD: 11.83 ppg. WOB - .3k Over pull on last 15° right backream pass at 10582'. Pull over 4k. Attempt to RIH and tag with 10k down. PU to neutral weight and establish milling parameters. Mill back through window with as milled TF and .4k WOB. Backream with as milled TF Continue reaming passes through window as milled TF. .2k to .3k WOB as we pass 10589'. Little to no motor noted as we pass bottom of window at 10589'. Rate in 2.67 bpm, Rate out 2.78 bpm. Circulating pressure 3561 psi to 3580 psi. MW in: 8.99 ppg, MW out: 8.83 ppg. Window ECD: 11.82 ppg Continue milling/reaming top of window from 10585'. Dry drift down and get hung up at 10582' with 8k set down and 5k overpull. Position coil at neutral weight and bring pumps back on. RIH to continue reaming passes. Call Drilling Foreman to inform. Pump 9 bbl HiVis sweep and chase to tubing tail Continue reaming and back reaming window f/10582' t/10590'. Rate in 2.67 bpm, Rate out 2.78 bpm. Circulating pressure 3561 psi to 3580 psi. MW in: 8.93 ppg, MW out: 8.83 ppg. Window ECD: 11.95 ppg. Minor motor work and WOB at ~ 10589'. Work coil at 10582' Unable to move. 5/24/2021 Detained at top of window. Work coil at 10582' Unable to move. Multiple weights from 12K down to -17K Multiple renditions at neutral. All cycling pumps. Observe HOT torque up every time. Good indication we are bit stuck. Pressure up and dump pressure on well multiple times. Pressure up annular to equalize pressure across EDC. Open EDC. Circulate 10 bbl lube pill down to EDC. Close EDC. Squeeze lube pill by rotor and stator. Cycle pipe while circulating by stator. Discuss plan forward with drilling engineer Circulate KWF around. Pump 10 bbl HiVis Spacer followed by 11.8 ppg NaBr. Once spacer at EDC. Close and circulate around and up to tubing tail. Open EDC and finish circulation to surface. Flow check well. Well dead. Paint flag 10580.3' (10478.39' EOP) TOP of fish 10495.53' MD Disconnect. Cycle EDC. Lost weight. Tool disconnected. Rate in : 1.05 bpm, 0.92 bpm out. MW in: 11.74 ppg, MW out: 11.77 ppg. POOH No Flow well. Well Static Inspect last 50' of pipe. No damage noted. L/D remainder of BHA #1 Pump forward at max rate to move eline downhole. Rig back and cut 361' eline. MU BOT external coil. Pull test to 50k Pressure test to 3500 psi. Prepare to pump 3/4" drift ball. Pump and recover 3/4" ball through coil. Begin MU fishing BHA. RIH with BHA #2. 3" GS Spear, Rupture Disc(5k), 3/4" Disconnect. G-Force Up/Down Jar, Wt Bars, G-Force Accelerator, 4 jts of 2-3/8" PH-6. Correct depth - 22' at 10300.22 'to 10278.22' based on previous run correction. RIH to 10400' WT CK. PUW = 42k, RIH = 18k. RIH and set down 3K @ 10498.6. PU and confirm fish latched with 46k up weight(4k overpull). Jar fish free with first down jar. RIH 3' and pick up. Jar free and see 1.5k weight. POOH keeping hole full across the top. 5/25/2021 At surface, flow check well. Good no flow, PU the injector and LD the fish. Fish OOH, string mill has some gouges on the gauge. Pump slack back, cut 447' of coil to find wire , reel has 2.43% slack. MU CTC, pull test to 50k, good pull test, MU stinger and nozzle to pump slack forward Head up BHI UQC & PT. Good PT, Install floats, change packoffs and PT. Good PT, PU injector and remove the nozzle & stinger. MU 3.1° motor to the BHA and see if it will drift the BOPE & Tree - if we swap to mud to clean , this will tell us if we need to swap back to KWF to PU the build BHA Drift failed, MU the milling BHA and RIH. Close the EDC and log tie in. Online with pumps, 2.7 bpm 1:1 returns at 12:58 ECD at the window, we will stay on KWF to dress the window Correct depth -20.5', Up WT = 39k. Start working down at 10573' at 1 fpm. Stacking WT at 10592', stall PU and bit stuck, 52k Pull free. Begin time milling at 10588'. Repeated stalls at 10591.7 ' to 10592'. 2.6 bpm in 2.7 bpm out Continue time milling at different speeds. .1' per minute to .1' per 10 minutes. Mill to 10591.7' with repeated stalls. Pull up hole and repeat passes. Repeated hard stalls at 10591.7'. No overpulls noted while PU. Rate 2.63 in/2.73 out. 11.83 ppg in/11.62 ppg out. Circ pressure 3800 - 3900 psi. POH POOH. 5/26/2021 Not able to clean up the bottom of the window, POOH to inspect mills and discuss a plan forward. OOH, flow check the well, good no flow, PU the injector to inspect the pipe and LD the BHA BHA OOH, tapered mill does not have any more wear on it than when it went in. The string mill has a lot of wear above the gauge on the up hole end. Call OE and discuss plan forward. Decision made to caliper the window & 7" to see if we can get a 3-1/4" liner through the window or set another WS RIH with READ 40 arm caliper logging BHA. Log Tie-In pass from 10330'. Correct - 21.5'. RIH and tag @ 10583'. PU and RIH again. RIH and tag @ 10594.4" Repeat and confirm tag. Wait for timed caliper arms to open. Log pass up @ 50fpm to 10,000'. POOH to surface OOH. Flow check well and confirm no flow. LD caliper tools and check for data. Heavy mud/shcmoo on BHA. Confirm good data and wait on processing from READ Houston Continue to wait on final processed logs from READ Houston. Final logs received. Discuss forward plan with CTD team. 5/27/2021 Processed Caliper Data and found the Whipstock released and was on bottom. Decision made to wait for and run the Northern Solutions Whipstock. Perform equipment maintenance and housekeeping while waiting for Whipstock to be delivered to the slope. Well Name: Field: County/State: MP L-06A Milne Point Hilcorp Energy Company Composite Report , Alaska 50-029-22003-01-00API #: 5/28/2021 Continue equipment maintenance & housekeeping while waiting on Whipstock Northern Solutions on location with Medium Expansion Wedge whipstock. Prep tool in pip shed and hold PJSM for PU MU NS whipstock to Inteq BHA RIH with BHA #5. NS 4 1/2" x 7" Whipstock with EDC in open position. Log tie-in pass from 10315' @ 5 fpm. Correct - 23.5'. RIH to setting depth of 10574' (BOWS). Close EDC. Orient WS 5 degrees LOHS. Pressure up coil to 3100 psi and see good indications of set. Set down 5k on whipstock POOH w/NS whipstock setting tool. Rate in .85 bpm Rate out .36 bpm. MW in 11.75 ppg. MW out 11.70 ppg OOH with Whipstock setting tool. Hold PJSM and flow check well. Confirm no-flow and LD setting tool. MU Northern Solutions window milling BHA with straight motor and 3.80" diamond window mill RIH with BHA #6. Northern Solutions 2 7/8" straight motor, 3.80" string reamer, 3.80" diamond window mill. RIH at 5000' at report time. MW in 11.76 ppg/MW out 11.69 ppg. Rate in .72 bpm/Rate out 1.21 bpm. 5/29/2021 Continue RIH with Window Milling BHA. Displace coil to drilling mud while logging tie in. Correct depth -23', displace well to Drilling Mud Well swapped to mud, close EDC and RIH to tag the pinch point. Dry tag at 10562.6'. Start milling window at 10564.9'. PU WT = 38k. Free Spin 2.5 BPM at 3600psi, WOB = 0.5-2.9k. In Rate = 2.5 bpm, Out Rate = 2.5 bpm. MW In = 9.08 ppg, MW Out = 9.06ppg. ECD = 11.9, IAP = 1383psi, OAP = 23psi 11:07. 10567.34' PU above the WS pump #1 liner gasket is leaking (pump 2 had to be shut down just after we started milling to replace a fluid end). Trap 12.1 ECD while pumps are off line to repair pumps. RU test pump to pump in sub on the lubricator to maintain ECD above 11.8 ECD Pump #1 back online, continue milling window from 10567.34' to 10571.7' (possible btm of window). In 2.5 bpm, Out 2.5 bpm. WOB falling off as we exit window 3.8k - .6k. Mill rat hole to 10582'. Ream window three times at 1 fpm. Dry drift clean. 85% sand noted in sample from 10,574' Open EDC and begin displacing to 9.0 ppg black mud to 11.8 ppg NaBr KWF. POOH f/10550' t/surface. 11.72 ppg NaBr In. 11.62 ppg NaBr Out OOH - PJSM. Flow Check Well - No Flow. LD BHA #6 Window mill and reamer. Window mill gauged 3.79" no go. Jet BOP stack with jet swirl nozzle. MU BOP test joint and function test BOP's. Clean and clear rig floor. 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: Install 4-1/2" Completion 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): 11,091'N/A Casing Collapse Conductor N/A Surface 3,090 psi Production 5,410 psi 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.W ell 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:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 / ADL0047434 190-010 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / KUPARUK RIVER OIL 50-029-22003-00-00 Hilcorp Alaska LLC Length Size 7,313' 10,390' 6,901' MD C.O. 432D PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-06 6.5# / L-80 / EUE 8rd TVD Burst 10,031' 7,240 psi Tubing Size:Tubing Grade: 5,750 psi 115' 4,590' 115' 3,333 10,390' 7" Perforation Depth TVD (ft): N/A and N/A N/A and N/A Tubing MD (ft): 13-3/8" 9-5/8" 115' 6,314' N/A 11,068'11,068'7,299' Authorized Signature: 6,314' 2/8/2021 2-7/8" Perforation Depth MD (ft): See Schematic See Schematic Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:40 pm, Jan 20, 2021 321-042 Chad Helgeson (1517) 2021.01.20 14:29:41 - 09'00' Test BOPE to 4000 psi. Annular to 2500 psi. DSR-1/21/21 DLB DLB 01/21/2021MGR22JAN21 3,333 ADL0025509 X Comm. 1/25/21 dts 1/25/2021 JLC 1/25/2021 RBDMS HEW 1/27/2020 CTD Setup Well: MPU L-06 Date: 1-13-2021 Well Name: MPU L-06 API Number: 50-029-22003-00-00 Current Status: Suspended Producer Pad: L-Pad Estimated Start Date: February 8th, 2021 Rig: Doyon 14 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-010 First Call Engineer: Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) Second Call Engineer: David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number: Job Type: CTD Setup Pressure below cement retainer: 4,033 psi @ 7,001’ TVD SBHP Survey 04/10/2012 | 11.1 ppg Maximum Expected BHP: 4,033 psi @ 7,001’ TVD KWF | 11.3 ppg MPSP: 3,333 psi Gas Colum Gradient (0.1 psi/ft) Max Inclination 57° @ 4,600’ MD Max Dogleg: 6°/100ft @ 2,000’ MD BPV Profile: 4” CIW Type H Brief Well Summary: MPU L-06 was drilled through the Kuparuk formation in March 1990 by Nabors 27E. The well was perforated in the C, B6, A3, A2 & A1 sands, fractured and an ESP completion was installed by Pool 102 in November 1990. This well has had 8 RWO to pull & replace the ESP’s. On the 9 th RWO to pull & replace the ESP the rig had a well control incident that lead to the P&A of the perforations. Notes Regarding Wellbore Condition x The 7” casing and cement plug was pressure tested to 1,500 psi with 11.5 ppg brine on 5/15/12. x Offset injectors with status: o C-17 – SI on 3/30/2000; main injection support o C-08 – SI on1/5/2021; observed good interaction once C-17 was SI. o C-19 – online; possible interaction but not very strong due to distance (~3,200’) o L-16A – online; possible interaction but unlikely due to L-07 producer location Objective: x Pull kill string. Drill cement and cement retainer to ~10,600’ (through the Kuparuk C sand into the top of the B6 sand but not into the A sands. x Run new 4-1/2” completion to setup the well for CTD. Pre-Rig Procedure: 1. RD well house. Clear and level area around well. 2. Set 4” HP BPV. RWO Procedure: 3. MIRU Doyon 14, ancillary equipment and lines to returns tank. 4. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 5. NU 13-5/8” BOP stack with 2-7/8” x 5” VBR’s in the upper and lower ram cavities. 6. Test BOPE to 250/4,000 psi, annular to 250/2,500 psi. Perform accumulator system test. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR rams and annular on 2-7/8” and 4-1/2” test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. CMIT - T X IA to 3500 psi. CTD Setup Well: MPU L-06 Date: 1-13-2021 Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 7. RD BOPE testing equipment. 8. RU to pull 2-7/8” kill string. 9. Pull the plug off tool, check for pressure under the BPV and pull the BPV. 10. MU landing joint. RU circulating equipment. 11. Circulate the well over to 8.3 ppg source water. a. The well currently is loaded with 11.5 ppg NaCl/NaBr and diesel to 2,500’ MD. 12. RD circulating equipment. 13. BOLDS, unseat the tubing hanger and pull to the rig floor. a. SO = 68K and PU = 98K when landed in 11.5 ppg NaCl/NaBr by Doyon 14 (block weight = 40K) in 2012. 14. Lay down the landing joint and tubing hanger. a. Inspect the tubing hanger and note any damage. If any damage is found, contact well head specialist for redress or replacement. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 15. POOH and lay down the 2-7/8” tubing. Equipment Disposition Tubing hanger Visually inspect on site and reuse Tubing & Pup joints Junk 16. RD 2-7/8” handling equipment and RU 4” DP handling equipment. Install wear ring. 17. PU, MU and RIH 6-1/8” tri-cone cement drilling assembly on 4” DP to tag on TOC. a. last tag with slickline on 3/29/2020 at 10,412’ SLM (~10,390’ MD) 18. PU and circulate the well over to 11.3 ppg LSND mud. 19. Drill cement from TOC to ±10,600’ MD (cement retainer set at 10,400’ MD) pumping sweeps as needed. 20. Circulate the well clean. Turn the pumps off and tag the TOC to ensure cleanout depth is sufficient. and on tubing x IC then Assure well is dead. CTD Setup Well: MPU L-06 Date: 1-13-2021 21. POOH laying down 4” DP and lay down 6-1/8” tri-cone cement drilling assembly. 22. Pull the wear ring. RD 4” DP handling equipment and RU 4-1/2” handling equipment. 23. PU and MU the following completion. a. WLEG/Mule shoe b. 1 joint, 4-1/2”, 12.6#, L-80, TXPM c. Nipple, 3.813” X profile, 4-1/2”, TXPM (RHC plug body installed), with 10’ handling pups d. 1 joint, 4-1/2”, 12.6#, L-80, TXPM e. Pup joint, 1 joint, 4-1/2”, 12.6#, L-80, TXPM f. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin g. Retrievable Packer, Halliburton AHR, 4-1/2”, 12.6#, L-80 EUE 8rd (setting depth ~10,347’) h. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin i. Pup joint, 4-1/2”, 12.6#, L-80, TXPM j. 1 joint, 4-1/2”, 12.6#, L-80, TXPM k. Pup joint, 4-1/2”, 12.6#, L-80, TXPM l. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin m. Ported Pressure Sub, 4-1/2”, 12.6#, L-80, EUE 8rd n. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin o. Pup joint, 4-1/2”, 12.6#, L-80, TXPM p. Crossover, 4-1/2” H521 Box x 4-1/2” TXP Pin q. Sliding Sleeve, 4-1/2”, 12.6#, L-80 Hydril 521 r. Crossover, 4-1/2” TXPM Box x 4-1/2” H521 Pin s. Pup joint, 4-1/2”, 12.6#, L-80, TXPM t. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin u. Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd v. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin w. Pup joint, 4-1/2”, 12.6#, L-80, TXPM x. XXX joints, 4-1/2”, 12.6#, L-80, TXPM 24. PU and MU the 4-1/2” tubing hanger. Make final splice of the TEC wire and ensure any unused control line ports are dummied off. 25. Land tubing hanger and RILDS. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 26. Set 4” HP BPV. 27. ND BOPE. Install the plug off tool. 28. NU the tubing head adapter and NU 4-1/16” 5M tree. 29. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 30. Pull the plug off tool and BPV. 31. Reverse circulate the well over to corrosion inhibited seawater follow by diesel freeze protect to 2,500’ MD. 32. Drop the ball & rod. 33. Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). CTD Setup Well: MPU L-06 Date: 1-13-2021 34. Bleed the tubing pressure to 2,000 psi and PT the IA to 3,500 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 35. Turn well over to production via handover form. Post-Rig Procedure: 36. RU slickline. 37. Pull the ball & rod and RHC plug body. 38. RD slickline. 39. RU E-line 40. PU, MU and RIH with CTD 4-1/2” x 7” whipstock assembly to ~10,590’. 41. Correlate on depth and set top of the whipstock at 10,562’ 15° right of high side. 42. RD E-line CTD Rig Work (scheduled to begin in May 2021): 1. MIRU and test BOPE. 2. Mill 3.80” single string window out of the 7” casing plus 10’ of rathole. 3. Driling 4-1/4” CTD sidetrack – 40° build section (±450’ MD) a. Kickoff in the Kuparuk C-sand 4. Driling 4-1/4” CTD sidetrack – 15° build section (±800’ MD) a. Drill down to the Kuparuk A-sand (primary target) 5. Run 2-7/8” L-80 slotted/solid liner to TD (±11,808’ MD) 6. Freeze protect the well with diesel. 7. RDMO. See 10-401 PTD for CTD procedure for more detail (will be submitted at a later date) Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP stack sketch 4. Blank RWO MOC Form Sundry 321-042 PTD MPUT L-06A _____________________________________________________________________________________ Revised By: TDF 1/6/2021 SCHEMATIC Milne Point Unit Well: MPU L-06 Last Completed: 5/21/2012 PTD: 190-010 TD = 11,091’ (MD) / TD = 7,313’(TVD) Halliburton HOS Cementer @ 1,881’ Orig. KB Elev. = 35’ Ground Elev. = 21’ RKB-THF: 23.95’ (Doyon 16)- 7” Est. TOC @ 8,820’ 9-5/85”88 Cast iron cement retainer set @ 10,400’ w/24 bbls cements below and 10 bbls cement above Top of Cement @ 10,390’ tagged 3/29/2020 Di esel Est. TOC @ 2,000’ PBTD = 10,983’(MD) / PBTD = 7,248’(TVD) KUP A Sands Arctic Pack RA Tag @ 10,304’ 2 1 11.5 ppg brine ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8"Conductor48#/ H-40 / Weld 12.715 Surface 115'0.157 9-5/8"Surface 36#/ J-55 / BTC 8.921 Surface 6,314’0.0773 7"Production 26#/ L-80 /BTC 6.276 Surface 11,068’0.0383 TUBING DETAIL 2-7/8"Killstring 6.5#/ L-80 /EUE 8rd 2.441 Surface 10,031’0.0058 JEWELRY DETAIL No Depth Item 1 23.95’4-1/2” Hanger 2 10,054’2-7/8” Mule Shoe –Min ID=2.441” PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C1/B6 10,566’10,593’ 7,001’7,016’27 11/21/1990 Closed KUP B6 10,632’10,662’ 7,039’7,056 30 11/20/1990 Closed KUP B6 10,678’10,693’ 7,065’7,074’15 11/20/1990 Closed KUP B6 10,714’10,724’7,086’7,092’10 11/20/1990 Closed KUP A3 10,800’10,821’ 7,137’7,150’21 11/20/1990 Closed KUP A2 10,834’10,878’ 7,158’7,184’44 11/20/1990 Closed KUP A1 10,900’10,904’ 7,197’7,200’4 11/20/1990 Closed OPEN HOLE / CEMENT DETAIL 13-3/8"485 sks Permafrost “C”in 30” Hole 9-5/8"316 bbl Permafrost E,67 bbl Class ‘G’in 12-1/4” Hole 7”65 bbl Class “G”in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 57° @ 4,600’ Max Hole Angle through perforations = 55° TREE & WELLHEAD Tree 2-9/16”5M WKM Wellhead 11”5M WKM,4-1/2” CIW BPV profile , 4-1/2” IBT Lift Threads x 4-1/2” Vam Top Hanging Threads GENERAL WELL INFO API: 50-029-22003-00-00 Drilled and Completed by Pool Rig 102 -11/27/1990 ESP RWO by Rig 4 –9/25/1993 ESP RWO by Nabors 4ES –11/21/1998 ESP RWO by Nabors 4ES –4/9/2001 ESP RWO by Nabors 4ES –6/17/2005 ESP RWO by Nabors 4ES-7/9/2007 ESP RWO by Nabors 3S-11/28/2008 Pull ESP, set CIBP, Run Killstring by Doyon 16 -5/21/2012 _____________________________________________________________________________________ Revised By: IAT 1/13/2021 PROPOSED Milne Point Unit Well: MPU L-06 Last Completed: 5/21/2012 PTD: 190-010 TD = 11,091’ (MD) / TD = 7,313’(TVD) Halliburton HOS Cementer at 1,881’ Orig. KB Elev. = 35’ Ground Elev. = 21’ RKB-THF: 23.95’ (Doyon 16)- 7” 3 5 7 Est. TOC at 8,820’ 9-5/85”88 TOC at ±10,600’ Est. TOC at 2,000’ 6 PBTD = 10,983’(MD) / PBTD = 7,248’(TVD) KUP A Sands Arctic Pack RA Tag at 10,304’ 4 2 1 ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8"Conductor48#/ H-40 / Weld 12.715 Surface 115'0.157 9-5/8"Surface 36#/ J-55 / BTC 8.921 Surface 6,314’0.0773 7"Production 26#/ L-80 /BTC 6.276 Surface 11,068’0.0383 TUBING DETAIL 4-1/2”Tubing 12.6#/ L-80 / TXPM 3.958 Surface ±10,462’0.0058 JEWELRY DETAIL No Depth Item 1 ±24’4-1/2”Tubing Hanger 2 ±10,269’ Gauge Carrier 3 ±10,279’Sliding Sleeve 4 ±10,289’Ported Pressure Sub 5 ±10,347’Retrievable Packer 6 ±10,409’Nipple, 3.813” X 7 ±10,461’WELG, bottom at ±10,462’ PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C1/B6 10,566’10,593’ 7,001’7,016’27 11/21/1990 Closed KUP B6 10,632’10,662’ 7,039’7,056 30 11/20/1990 Closed KUP B6 10,678’10,693’ 7,065’7,074’15 11/20/1990 Closed KUP B6 10,714’10,724’ 7,086’7,092’10 11/20/1990 Closed KUP A3 10,800’10,821’ 7,137’7,150’21 11/20/1990 Closed KUP A2 10,834’10,878’ 7,158’7,184’44 11/20/1990 Closed KUP A1 10,900’10,904’ 7,197’7,200’4 11/20/1990 Closed OPEN HOLE / CEMENT DETAIL 13-3/8"485 sks Permafrost “C”in 30” Hole 9-5/8"316 bbl Permafrost E,67 bbl Class ‘G’in 12-1/4” Hole 7”65 bbl Class “G”in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 57° @ 4,600’ Max Hole Angle through perforations = 55° TREE & WELLHEAD Tree 2-9/16”5M WKM (dry hole) Wellhead 11”5M WKM,4-1/2” CIW BPV profile , 4-1/2” IBT Lift Threads x 4-1/2” Vam Top Hanging Threads GENERAL WELL INFO API: 50-029-22003-00-00 Drilled and Completed by Pool Rig 102 -11/27/1990 ESP RWO by Rig 4 –9/25/1993 ESP RWO by Nabors 4ES –11/21/1998 ESP RWO by Nabors 4ES –4/9/2001 ESP RWO by Nabors 4ES –6/17/2005 ESP RWO by Nabors 4ES-7/9/2007 ESP RWO by Nabors 3S-11/28/2008 Pull ESP, set CIBP, Run Killstring by Doyon 16 -5/21/2012 TOWS 10,562' MD (mgr) ] Milne Point Doyon 14 13-5/8” BOP Stack Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: January 13th, 2021 Subject: Changes to Approved Sundry Procedure for Well MP L-06 Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,091 feet 10,400 feet true vertical 7,313 feet N/A feet Effective Depth measured 10,400 feet N/A feet true vertical 6,907 feet N/A feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 10,031' 6,689' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 115' 777-8333 1,730psi See attached schematic See attached schematic 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 4,590' 115' Burst 7,420psi 740psi 2,020psi 7' 7,299' 13-3/8 6,314' 5,410psi 6,314'Surface Intermediate 9-5/8" 3,520psi N/A Production Production Casing Conductor Liner Length 115' MILNE PT UNIT L-06 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-010 50-029-22003-00-00 Plugs ADL0047434 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Oil-Bbl measured true vertical Packer 11,068' WDSP2 WAG Water-Bbl MD TVDSize 11,068' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 8:07 pm, Jul 21, 2020 Chad A Helgeson 2020.07.21 16:40:04 -08'00' RBDMS HEW 7/23/2020 , ADL0025509 MGR22JUL2020 SFD 7/22/2020 SFD 7/22/2020DSR-7/22/2020 _____________________________________________________________________________________ Revised By: STP 3/25/2020 SCHEMATIC Milne Point Unit Well: MPU L-06 Last Completed: 5/21/2012 PTD: 190-010 TD =11,091’ (MD) /TD = 7,313’(TVD) Halliburton HOS Cementer @ 1,881’ Orig. KB Elev. = 35’ Ground Elev. = 21’ RKB-THF: 23.95’ (Do yon 16) 7” Est. TOC @ 8,820’ 9-5/8” Note OA appears to have an open shoe. 0.2 bpm @ 2000 psi. Cast iron cement retainer set @ 10,400’ w/24 bbls cements below and 10 bbls cement above Top of Cement PBTD = 10,983’(MD) / PBTD = 7,248’(TVD) KUP B Silts KUP A Sands Arctic Pack RA Tag @ 10,304’ 2 1 ` CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48# / H-40 / Weld 12.715 Surface 115' 0.157 9-5/8" Surface 36# / J-55 / BTC 8.921 Surface 6,314’ 0.0773 7" Production 26# / L-80 / BTC 6.276 Surface 11,068’ 0.0383 TUBING DETAIL 2-7/8" Killstring 6.5# / L-80 / EUE 8rd 2.441 Surface 10,031’ 0.0058 JEWELRY DETAIL No Depth Item 1 23.95’ 4-1/2” Hanger 2 10,054’ 2-7/8” Mule Shoe –Min ID=2.441” PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C1/B6 10,566’ 10,593’ 7,001’ 7,016’ 27 11/21/1990 Closed KUP B6 10,632’ 10,662’ 7,039’ 7,056 30 11/20/1990 Closed KUP B6 10,678’ 10,693’ 7,065’ 7,074’ 15 11/20/1990 Closed KUP B6 10,714’ 10,724’ 7,086’ 7,092’ 10 11/20/1990 Closed KUP A3 10,800’ 10,821’ 7,137’ 7,150’ 21 11/20/1990 Closed KUP A2 10,834’ 10,878’ 7,158’ 7,184’ 44 11/20/1990 Closed KUP A1 10,900’ 10,904’ 7,197’ 7,200’ 4 11/20/1990 Closed OPEN HOLE / CEMENT DETAIL 13-3/8" 485 sks Permafrost “C”in 30” Hole 9-5/8" 316 bbl Permafrost E, 67 bbl Class ‘G’ in 12-1/4” Hole 7” 65 bbl Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 700’ Max Hole Angle = 57° @ 4,600’ Max Hole Angle through perforations = 55° TREE & WELLHEAD Tree 2-9/16” 5M WKM Wellhead 11” 5M WKM, 4-1/2” CIW BPV profile , 4-1/2” IBT Lift Threads x 4-1/2” Vam Top Hanging Threads GENERAL WELL INFO API: 50-029-22003-00-00 Drilled and Completed by Pool Rig 102 - 11/27/1990 ESP RWO by Rig 4 – 9/25/1993 ESP RWO by Nabors 4ES – 11/21/1998 ESP RWO by Nabors 4ES – 4/9/2001 ESP RWO by Nabors 4ES – 6/17/2005 ESP RWO by Nabors 4ES- 7/9/2007 ESP RWO by Nabors 3S- 11/28/2008 Pull ESP, set CIBP, Run Killstring by Doyon 16 - 5/21/2012 Matt Herrera L-06 Suspended Well Inspection Review Report InspectNo: susMFH200620152932 Date Inspected: 6/20/2020 Inspector: Matt Herrera Well Name: MILNE PT UNIT L-06 Permit Number: 1900100 Suspension Approval: Sundry # 312-181 Suspension Date: 8/27/2012 Location Verified? F/1 If Verified, How? Other (specify in comments) - Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 6/19/2020 Operator: Hilcorp Alaska, LLC Operator Rep: Josh McNeal Wellbore Diagram Avail? W Photos Taken? f"i Well Pressures (psi): Tubing: 200 - Fluid in Cellar? 0 ' IA: 100 BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Good. No leaks on any flange connections or lock down screws. No SSV. All Valves operational. Gauges installed and in working order to note tubing and annulus pressures Condition of Cellar Water and Ice in cellar. Prodded ice to determine how thick up -solid to the bottom of the OA valve flange connection. No sheen or subsidence. Surrounding Surface Condition Good Wellhouse still on well with flowlines disconnected. Surrounding area clean with no standing water, stains or subsidence. Comments Well location verified per MPU L -Pad Location Map. Operator directed to melt ice and vac out water from cellar and monitor for any potential damage from ice in cellar. Supervisor Comments Photos (2) attached incluiding photo from Hilcorp after thaw and vac cellar. ✓ Thursday, July 23, 2020 . • • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMIIIISION SEP 1 8 Zits;, REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well Cl Other: Inspect Well ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development El Exploratory ❑ 190-010 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22003-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047434 MILNE PT UNIT KR L-06 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 11,091 feet Plugs measured 10,400 feet true vertical 7,313 feet Junk measured N/A feet Effective Depth measured 10,400 feet Packer measured N/A feet true vertical 6,907 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 6,314' 9-5/8" 6,314' 4,590' 3,520psi 2,020psi Intermediate Production 11,068' 7" 11,068' 7,299' 7,420psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic feet sCANWE N 0 V I 6 2ri1 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 EUE 8rd 10,031' 6,689' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmentL Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Stan Porhola Email sporhoIa(p�hiIcorp.com Printed Name Stan Porhola Title Operations Engineer Signature i��c % gLPhone 777-8412 Date 9/18/2015 Form 10-404 Revised 5/2015 f/io . ;74.15 RBDBRS427.3EP 2 2 2015 Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hilcorp.LLC Well Name: MPL-06 Oper.Rep: Bill Kruskie PTD No.: 190-010 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskieahilcorp.corn If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 05/17/12 Type of Inspection: Subsequent Sundry No.: 312-181 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing 50 IA 0 OA 0 Condition of Wellhead: Good,no visable leaks and all gauges are installed,wellhouse,well head sign installed, tree has two working valves. Condition of Surrounding Surface Location: Good. Follow Up Actions Needed: None. Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPL-06 2015 Suspended Well Inspection Form Tree:WKM 4 1/16" 5M • Orig. !clev. = 55.0' (PoolWellheadl1 5M WKMMPL-06 Orig. elev. = 21.0' (Pool 4.5" CIW BPV profile DF to GL = 34' Note: OA appears to have an open shoe. 0.2 bpm @ 2000 psi. _ 20" Conductor Casing 112' Halliburton Hos stage 1885' 0 cementer 9-5/8" 36#, J-55 BTC csg 6314' down squeezed 8/25/91 KOP @ 1000' Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. RA tag at 10303' X 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26#, L-80 Buttress casing (drift ID = 6.151", cap. = .0383 bpf) Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I-Prop. 28,603# 12/18 I-Prop. 2 7/8" 6.5 # L-80 8rd EUE Tbg. 10031' screened out w/ 14,082# 12/18 I-Prop. w/ Mule Shoe above perfs. • Perforation Summary: Ref log:SWS CCL log dated 3 May 90 Size SPF Interval (TVD) Cast iron cement retainer w/24 bbls cement below & 10400' 4.5" 5 10566'-10593' 7002'-7017' 10 bbls cement above 4.5" 5 10632'-10662' 7042'-7058' 4.5" 5 10678'-10693' 7067'-7076' 4.5" 5 10714'-10724' 7089'-7094' 4.5" 5 10800'-10821' 7139'-7152' 4.5" 5 10834'-10878' 7166'-7186' 4.5" 5 10900'-10904' 7200'-7202' 7" Float collar 10985' Mid-p erf TVD - 7102' 7" csg. shoe 11068' Mid-perf MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L-06 9/24/93 RWO Riq 4 7/16/98 RWO Nabors 4-ES 11/20/98 MDO ESP RWO /Calvins Nabors 4-ES API NO: 50-029-22003 04/10/01 B. Hasebe ESP RWO \labors 4-ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme C/O ESP,Add screens&Cup Pkr Nabors 3S 05/21/12 B. Bixby Pull ESP set CIBP and run work string • ill.40111 4aiiiiii..o. l%t. i. II,Ihiiiiio.„ , 1.• ,.„ .1- •01 .4,0,Ai ......,...„., ...„.14 ........,........, ... .... { ., . . - fie____ fm ':_ ra mailliia a WEIINANEY�-06 - .' lea R.Pow um eo48 r"�'° s, A.a,�x 01101111052482.201:02! 1 t _. — �-- - u *,. a.,,,„..,OE j i w ',.?'-f7- Fly , r i .L • . - Rw a. A - iii ... .: ....• 111 , 1 A(.' r' o i . . I ill Igik. ___ - - , 1 t.1- . .. ' -, ....2.=......"- Milliall MI MN iiiiii i•usc „.4),.._•40...,..__.,..,.....;., WELL NAME MPL•06 , ". . . .... OWNER Milne Point Unit t OPERATOR BP Exploration(Alaska)Inc , API NUMBER 50-029-22003-00 SUR, PERMIT 1900 LOCATION NW1:41,0Sec.DB,T13N,R10E DRILLING • ,• . . .... , . ..., :. .... ., , . _. ., ,--l .... • ,,,,• , • - • . , , ,,-4" -' •-,t ,,,,si.- ,,, '7' '1 ..., . ,, -, .,.... • . . • . .. . ,,. . .. . . . '.i...,.. - . . , .. . . . , - . ......_ • , ... . . .. • . - , - .., - - ,„„ .. , ..-. • . . ..„. -... '• • •. -, - • . ,- - . - -4'.. . - . .. • , .. .- , . .......•.. ... . . . . - .- - - .. .....- . . .. , . ..'' , . . .- • ., _ _. . . . • • • it 1 rim d .!• ,, 4 4001111 . ..,.. _ . ____ . r,. .. C / .. .. ,,i .,i 4 , . , .„,. i.:: .. , , 1 4,t '''''', :'—'"'"- 4 1. t4. . 1 4 I _ -- .T...-.... __ /1l _ rri►�.I .�" '� 71+r t 7,.'°"."v".= si Sx E ,_ F e ----- 1 i • k _ n.. '* a ria' - ,�,.: • w 4 .:. ,��. 4 sae ,�• 0 iw- , ce°^ , 9 _ - ` �': y /111 4C' , olir, F�. ',' 41, 1.? 408k . �. 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I t 1‘) > c & r. � t s . 9 5. .. .13a O313 a a.� Aro O fL ,,n N 53 to w r II O ., ..-- M • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report • Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hillcorp Well Name: MPU L-06 Oper.Rep: Bill Kruskie PTD No.: 1900100 Oper. Phone: 907-670-3387 Location Verified? Yes Oper.Email: i-Milne-WellsiteSupervisors(c.hi If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 05/17/12 Date AOGCC Notified: 08/20/15 Sundry No.: 312-181 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 50 Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: Double gate valves. SCANNED SEP 0 6 2016. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None Comments: Location verified by site map. Photos taken by operator available upon request. Attachments: none REVIEWED BY: / Insp.Supry JC il(3u1 ac Comm PLB 06/2014 2015-0823_Suspend_MPU_L-06_cs.xlsx Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I CC0 ~' 0 lO File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED of various kinds Logs [] Other Complete COMMENTS: Scanned by~Bren Vincent. Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd STATE OF ALASKA RECEIVED AKA OIL AND GAS CONSERVATION COMMON w ! ' 192012 REPORT OF SUNDRY WELL OPERATIONS /� `��, 11. Os Abandon L] Repair WeIIU Plug Perforations a Perforate a Loth C Well InsL Performed: Alter Casing ❑ Pull TubinC Stimulate - Frac ❑ Waiver ❑ Time Extensiofj Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ 190 -010 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ t. API Number: Anchorage, AK 99519 -6612 50 -029- 22003 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047434 MPL -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted MILNE POINT, KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 11091 feet Plugs measured 10400 feet true vertical 7312.9 feet Junk measured None feet Effective Depth measured 10400 feet Packer measured None feet true vertical 6906.57 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 13 -3/8" 48# H-40 35 -115 35 - 115 0 0 Surface 6280 9 -5/8" 36# J -55 34 - 6314 34 - 4589.83 3520 2020 Intermediate None None None None None None Production 11035 7" 26# L -80 33 - 11068 33 - 7298.99 7240 5410 Liner None None None None None None Perforation depth Measured depth 10566 - 10593 feet 10632 - 10662 feet 10678 - 10693 feet 10714 - 10724 feet 10800 - 10821 feet 10834 - 10878 feet 10900 - 10904 feet True Vertical depth 7000.98 - 7016.32 feet 7038.59 - 7055.88 feet 7065.15 - 7073.88 feet 7086.16 - 7092.03 feet 7137.15 - 7149.75 feet 7157.57 - 7184.08 feet 7197.37 - 7199.79 feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 32 - 10448 32 - 6934.08 Packers and SSSV (type, measured and true vertical depth) None None None Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 16 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 55 437 160 140 287 Subsequent to operation: ' 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorG Development 0 ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil II Gas 1J WDSP4U GSTOR b 3 WINJ 0 WAG GINJ o SUSP L w SPLUc 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature ,!4.i t, C.,...... Phone 564 -4424 Date 9/19/2012 F iE 3 DMS SEP 2 0 211 7• Zs• /Z_ /�'v Form 10-404 Revised 11/2011 Submit Original Only Daily Report of Well Operations ADL0047434 ACTIVITYDATE SUMMARY • _ .1 1, uspen.e. we si a inspec ion. 'Ti nessing waive. •y uc eve. WH is removed and well guard in place. No abnormalities encountered. Location is clean, no leaks found on or around the well. Report and photos sent to WIC. 8/27/2012 • • • • Milne Point Unit Well MPL -06, PTD1900100 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of MPL -06 on 8/27/2012. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Report of Sundry Well Operations (10 -404) • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Chuck Shieve waived witnessing the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • MPL -06 was suspended on 5/17/2012. The work was documented in a completion report (form 10 -407) submitted 6/11/12. • Follow -Up T /I /O pressures read 150/60/0 psi on 9/5/12. • MPL -06 is located on an active maintained pad and is accessible by the Milne Point road system ✓ • The strata through which the well was drilled is neither abnormally geopressured nor depleted. • Producing zones of the well are secured with Class 'G' cement (10131- 10985') • 10 bbls above and 24 bbls below a cement retainer at 10400' • The plug and casing were pressure tested to 1500 psi for 30 minutes. MLB -MD 09 -18 -12 • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPL -06 Field /Pool: Milne Point Permit # (PTD): 190 -010 API Number: 50- 029 - 22003 -00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/17/2012 Surface Location: Section: Sec. 08 Twsp: T13N Range: R10E Nearest active pad or road: E -Pad / Milne Point Road Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean / Wellhouse has been removed Pad or location surface: Good Location cleanup needed: NO Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: Nothing on pad Samples taken: No Access road condition: Good Photographs taken (# and description): Yes / Attached Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: All valves are in good working order and were left closed. Cellar description, condition, fluids: Good Rat Hole: None Wellhouse or protective barriers: Yes there is a well guard in place Well identification sign: Yes Tubing Pressure (or casing if no tubing): Zero Psi with valve closed Annulus pressures: Zero Psi with valve closed Wellhead Photos taken (# and description): Yes / Attached Work Required: None Operator Rep (name and signature): Brian Bixby AOGCC Inspector: Chuck Shieve Waived Other Observers: No Inspection Date: 8/27/2012 AOGCC Notice Date: Time of arrival: 10:30 AM Time of Departure: 11:00 AM Site access method: Drive to location Tree:WKM 4 1/10A OrIIPF elev. = 55.0' (Pool) Wellheadi 1 M P L -06 5M WKM Orig. GL elev. = 21.0' (Pool; 4.5" CIW BPV profile DF to GL = 34' Note: psOA i. shoe. appe .2 to have @ „ an open bpm 20 00 20” Conductor Casing 112' Halliburton Hos stage 1885' cementer 1, 9 -5/8" 36 #, J -55 BTC csg 6314' • down squeezed 8/25/91 KOP @ 1000' Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. RA tag at 10303' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7 ", 26 #, L -80 Buttress casing (drift ID = 6.151 ", cap. _ .0383 bpf) Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I -Prop. 28,603# 12/18 I -Prop. 2 7/8" 6.5 # L -80 8rd EUE Tbg. 10031' screened out w/ 14,082# 12/18 I -Prop. w/ Mule Shoe above perfs. Perforation Summary: Ref Iog:SWS CCL log dated 3 May 90 Size SPF Interval (TVD) Cast iron cement reta w/ 24 bbls cement below & 10400' 4.5" 5 10566'- 10593' 7002' -7017' 10 bbls cement above 4.5" 5 10632'- 10662' 7042' -7058' 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' 4.5" 5 10800'- 10821' 7139' -7152' 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900'- 10904' 7200' -7202' 7" Float collar 10985' Mid -pert TVD - 7102' 7" csg. shoe 11068' Mid -perf MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L -06 9/24/93 2WO Rig 4 7/16/98 RWO Nabors 4 -ES 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES API NO: 50 - 029 - 22003 04/10/01 B. Hasebe ESP RWO \labors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme CIO ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) 05/21/12 B. Bixby Pull ESP set CIBP and run work string 0 • , / . \ \ i \ \ \ \ \ \ \ \ N. \ : \ \ \ \ \ 1 1 \ \ -......1., 368' '----1 .../) -Z - "I t : , . 1 i , t iel \ Enter/Extt N. 131 \ 131' ‘ 0. I \ I • 1 H ___ 33 \ 1 32 A A. , I 1 I I I • ....- 28 co 24 4--- —Ill 25 20 30 1 , 30. / 16 A II - 7 , ,r 1 .1 .7 .--F 1 , i ‘, ; f i .....,.., 0 — L . 43 I 45 C 64 175' 1'1 ao; 11 a 8 --lima 113' 39 A — A 42 - 4 9 4 - 34 4 II 14 , I 3 a- / A 10 b _ t 15 A \ 0 411 ; 2 _ a 7 12 • 40 III a a a 0— j 01 ..u. (....) J clo -::: (....) A 0 - ^4 -a, --11■1 1 - - 9. --. - _ --- I-7- 1 7- -----._ , m MI 1 .,. 1 ' '' .., \ 1 \ 1 ‚It 1 1 , \ _. Enter/Exit I 1 i 1 , WELL PRODUCER II or 0 WELL INJECTOR A DATE 5/30/2012 SCALE : 1" = 150' MAP DATE : 2011 MPU - L PAD WELL SLOT W:CONaUCTOR D .. - =•44a6 -n.d • • MPU L Pad ,.. . ., 1=200 2012-DNIC0157-4-89 aef °metric II tI , . a, 4, „ . . ' '44'1/4, *414 ` •* $$k*,., ' ' ' 4 , . .. 14 . . 'Crokii444 * ' ', .f.4 , ,, Z!' j . :,....:, ,.,.. , - : ''''''*i; - 4* 4 0 400 1., ,,,:„.4,, ' 14, 0 ‘f 1140i t 0 ,,,,, ,, ., Ir. . . - iik . 4 ^ $ lik t, )100- , --.... t 4 . li olik. 41000N ..,, Or ,...,' 0 . 10 ' 'dr „ 1 i ot.N , 5 ill' C ....' '... •Iii , 5 5 5,, h r . , 4 r � 4- ' " ,, ,,,, r _ , , 4 k: , 1■#...„1:11b, 4#1",.. 4 ' ,fi r i k ..... m #.,< `` * 1* "s fir at 1 It # 4. 4, * 10 . \ - ywA #9F R i t 1 , q y .,, ' i of . s* * • • ,ii f t 4 iMMJW +wi M yi k dub t .' i. ',. ', , _ ,, - . , . �.. Y M R s Y i s . . ' *• , �. x t ., fi,..: f _ , ' . ,� V i A > 1 i 1 % . .■ r F ii. • k { t c ;1 'fie y • 'F :' s to � ..,. a '''''''- n. Jj� xi . . ' .. . , 1 ' , ' t ' A : - . - - - - -- - - -, .• - - - -, ' , . '''' - 1 ... ' - ., • . - # ::,--#: '. e-"":te.- - .„,- , 0 -14- 1 , , , -, : ' - ' -' .,•,'"---, , .... ' • ' ' . f '., ; '''. :',. ( .ft .....ottr ,14141 _ . „,,, ' ' '' '' 4' ''''''' '''' . '1, ";* ''''',7" ' 1 1 ; '°':'' :*: I '' ' •' ' ' 11111 1%, i , lit .. i ..,.. ,z,. .:. .....- ;: ,...`• #, _#- ----- : • ., .,,‘ . #) -',.. i . --, , , ,:,stke:::.ti,,,•, -,, : .,., - i it .. ..... _.. - i s - 1 V ' gi . . ,......,,,,......0 1 4 T. I. II, ' ''''' . . . . p — i • . II 1 . ) , • „ , .., V .t. f .... .. ... . .01.: ....„, A ' , . . . . .. , . . , A N I 1 I e . . . . . . . : . i . 1 i I * i 4 -*. , 1. '• ; #f - , 41 . l . - . . . . . a i ilk , . . - . ' ' .,.. 1; .,:i,ft 1,4 ''' ** ° "'" * ' t , NW - - ' 74' \''''.:•- . : .t!".7: -1/2 -t.. ,-. .`..".%'... ?Zt..." . i ... , • . ,, - - ., ,. . , .... t , _. , . • .,, . . . .., It. * . „ • * . ; Alt , ,.,,, a• t• . * , ' ,. • a jr / . .. a t li . . --N. 47 A , : • .. ..., , , ., .,.......... . ,._._ .... s.,... . 4 . . , 4.........„ , ',",..0 • f a . , 4*. .. .."' ' . a* . ,, • .4„ * .. * „ , * .,,., : ... . • • ,. ...k. • _ 14kaaa••••••-• , • ' .,!„ . , . J * it ' . . .. ‘ , , . ,,,..,.. . . - .. .. ',.. •• o ' * . • . * *e* ' a . . . 4 • • • RECEIVED STATE OF ALASKA • JUN 12 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ArgigGC la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended) lb. Well Class: 20AAC 25.105 20AAC 25:010 _ Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Comptetions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: ✓ BP Exploration (Alaska) Inc. 5/17/2012 190 - 010 312 - 181 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 3/7/1990 50 029 - 22003 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 3/19/1990 MPL -06 3161' FSL, 4962' FEL, Sec. 08, T13N, R10E, UM 8. KB (ft above MSL): 56 15. Field / Pool(s): Top of Productive Horizon: 2125' FSL, 924' FWL, Sec. 04, T13N, R10E, UM GL (ft above MSL): Milne Point / Kuparuk River Total Depth: 9. Plug Back Depth (MD +TVD): 2366' FSL, 1274' FWL, Sec. 04, T13N, R10E, UM 10131' 6748' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 544920 y- 6031351 Zone- ASP4 11091' 7313' ADL 025509 & 047434 TPI: x- 550765 y- 6035632 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 551113 y- 6035876 Zone- ASP4 None 18. Directional Survey: ❑ Yes 181 No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DITE / CNL / LDT / NGT / CYBERLOOK / GYRO / GR / CCL N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP I BOTTOM TOP I BOTTOM SIZE CEMENTING RECORD PULLED 13 -3/8" 48# H -40 Surface 115' Surface 115' 30" 480 sx Permafrost C 9 -5/8" 36# J -55 Surface 6314' Surface 4590' 12 -1/4" 526 bbls Permafrost E. 84 bbls Class 'G' 7" 26# L -80 Surface 11068' Surface 7299' 8 -1/2" 65 bbls Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): Killstring: 2 -7/8 ", 6.5 #, L -80 10031' None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ` 1 � ,, ,.`�� JU1't � '7 21112. DEPTH 10400' AL (MD)I Cement Retainer ND OF MATERIAL USED 10131' 34 Bbls Class 'G' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER-BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RSDMS JUN 1 I gill + 4// Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE ,_ 6 ./1. .e teee mit Original Only G • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 4585' None Schrader Bluff NC 5589' HRZ 10044' Kuparuk D 10421' Kuparuk C 10563' Kuparuk B 10578' Kuparuk A 10784' Miluveach 10967' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the oing ru a • • rrect to the best of my knowledge. Signed: Joe Lastufka ' ' Title: Drilling Technologist Date: eeil i /0- MPL -06 190 - 010 312 - 181 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only North America - ALASKA - BP • Page iittg Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 3/17/2012 00:00 - 12:00 12.00 RIGD N WAIT POST RIG STAGED ON TEXACO PAD. - RECIEVED APPROVAL FROM WTL AND TOWN TO RESUME WITH OPS. -WAIT ON PAD PREP FOR NEXT WELL. -STAGE SOME TRAILERS AND EQUIP. ON PRICE PAD. -PREP RIG AND CAMP FOR MOVE. - WAIT ON FIELD SUPPORT FOR RIG AND CAMP MOVE - DUE TO EXTREME TEMP. - 52 DEG. - PERFORM GENERAL RIG MAINT. 12:00 - 00:00 12.00 RIGD N WAIT POST RIG STAGED ON TEXACO PAD. - RECIEVED APPROVAL FROM WTL AND TOWN TO RESUME WITH OPS. - WAIT ON PAD PREP FOR NEXT WELL. -STAGE SOME TRAILERS AND EQUIP. ON PRICE PAD. -PREP RIG AND CAMP FOR MOVE. - WAIT ON FIELD SUPPORT FOR RIG AND CAMP MOVE - DUE TO EXTREME TEMP. - 52 DEG. - PERFORM GENERAL RIG MAINT. 3/18/2012 00:00 - 12:00 12.00 RIGD N WAIT POST RIG STAGED ON TEXACO PAD. - RECIEVED APPROVAL FROM WTL AND TOWN TO RESUME WITH OPS. -WAIT ON PAD PREP FOR NEXT WELL. -STAGE SOME TRAILERS AND EQUIP. ON PRICE PAD. -PREP RIG AND CAMP FOR MOVE. - WAIT ON FIELD SUPPORT FOR RIG AND CAMP MOVE - DUE TO EXTREME TEMP. -44 DEG. - PERFORM GENERAL RIG MAINT. 12:00 - 15:00 3.00 RIGD N WAIT POST WEATHER IMPROVED TO -32 DEG. 15:00 - 17:30 2.50 RIGD P POST -PREP CAMP FOR MOVE. -DDI FIELD SUPERINTENDENT ON LOCATION FOR MOVE. - PJSM WITH PEAK. REVIEW SOP FOR CAMP MOVE. - PROCEED WITH CAMP MOVE 17:30 - 19:00 1.50 RIGD N WAIT POST AT MILNE POINT ACCESS ROAD PEAK SAL TRANSMISSION FAILED. CALL OUT AND R/U ANOTHER TRUCK ON CAMP. 19:00 - 23:00 4.00 RIGD P POST CONTINUE WITH CAMP MOVE TO PRICE PAD. 23:02 - 00:00 0.97 RIGD P POST SPOT CAMP ON PRICE PAD. RIG RELEASED FROM MPL -06 AFE AT 2400 HRS. 4/27/2012 21:00 - 00:00 3.00 RIGD P PRE PREPARE RIG TO MOVE OFF OF PR331213 - MOVE CUTTINGS TANK TO PRICE PAD - PERFORM SPCC CHECKS ON MOVING SYSTEM - SECURE ALL LINES AND HOSES - HARD LINE CREW R/D FLOW BACK TANK AND LINES. - REMOVED FLOW BACK TANK FROM PAD - HAULED SIGN IN TRAILER TO MPL -06 - LAY DERRICK OVER AND SECURE Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 47 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/28/2012 00:00 - 06:00 6.00 MOB P PRE PJSM ON RIG MOVE WITH NEW CREW - ENSURE GOOD RADIO COMMUNICATIONS - SPCC, CHECK ALL MOVING SYSTEM LINES FOR INTEGRITY - RAISE CELLAR DOORS - RAISE RIG OFF GROUND AND MOVE RIG OFF WELL PR331213 - POSITION RIG ON PAD - REMOVE BOP STACK AND HAUL TO PRICE PAD - INSTALL REAR BOOSTER TIRES - REMOVE MAT BOARDS AND HERCULITE - DISCOVERED AN AREA, ON THE ICE PAD, UNDERNEATH THE MAT BOARDS, - THAT HAD MELTED AWAY POSSIBLY DUE TO A HEATER FOR THE FRONT WHEEL WELL. - WHEN THE REAR WHEELS ROLLED OVER THE AREA, IT CRUSHED 2 MAT BOARDS. - THE AREA IS APPROXIMATELY 4' X 6' AND 2 FEET DEEP WITH STANDING WATER. - THE AREA WAS FLAGGED OFF. - DDI SUPERINTENDENT AND WSL PRESENT TO PULL OFF WELL 06:00 - 19:00 13.00 RIGD N RREP PRE WORK ON REAR BOOSTER REMOTE STEERING SYSTEM (SOLENOID). - WHICH STEERS THE REAR BOOSTER WHEELS. - BP ENVIRONMENTAL REP MAKE INSPECTION OF ICE PAD WITH NO DEFICIENCY' - DDI SAFETY REP ALSO INSPECTED ICE PAD. 19:00 - 00:00 5.00 MOB P PRE PJSM, MOVE RIG OFF PUT RIVER PAD - MOVE RIG FROM PUT RIVER ICE PAD AND ICE ROAD - DOWN "F" PAD ACCESS ROAD TO SPINE ROAD - SPINE ROAD TO "R" PAD 4/29/2012 00:00 - 06:00 6.00 MOB P PRE PJSM FOR RIG MOVE - MOVE RIG FROM "R" PAD ON SPINE ROAD TO "Z" PAD - CLOSE -OUT WELL WORK TRANSFER PERMIT WITH 'F' PAD OPERATOR. 06:00 - 12:00 6.00 MOB P PRE MOVE FROM 'Z' PAD ON THE SPINE ROAD TO MILNE POINT CUT OFF'Y'. - MOVE LAST 3 MATING BOARDS OFF PUT RIVER ICE PAD. - HOLD FACE TO FACE 'END OF WELL HANDOVER WITH WELLS GROUP / MARTY FELL 12:00 - 18:00 6.00 MOB P ■- PRE TI T PAD AND INSPECT TIRES RES AND AND D MOVING SYSTEM. - CONTINUE ON TO MILNE POINT "Y" 18:00 - 00:00 6.00 MOB P PRE MOVE FROM MILNE POINT "Y" TO "L" PAD - PULL ON TO "L" PAD AT 24:00 - SPOT RIG ON PAD FOR EASY ACCESS TO CELLAR Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 48 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/30/2012 00:00 - 06:00 6.00 MOB P PRE PJSM, STAGE RIG ON MP -L PAD - PERFORM SPCC WALK AROUND'S - POSITION AND SET UP WSL TRAILER - REMOVE REAR BOOSTERS TIRES ON RIG - RAISE DERRICK, BRIDLE DOWN - RIG UP FLOOR EQUIPMENT - INSTALL BOP STACK ON CELLAR 06:00 - 00:00 18.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS - PERFORM WORK ORDERS - CHANGE OUT ACCUMULATOR LINES ON BOP - TABLE TOP WELL CONTROL AND RIG EVACUATION DRILLS - MOVE RIG CAMP FROM PRICE PAD TO MILNE POINT "A" PAD - SPOT AND SET UP AT 04:00 HOURS 5/1/2012 00:00 - 06:00 6.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS 06:00 - 18:00 12.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS - BP RWO SUPERINTENDENT PRESENTED THE MPL -06 GAS RELEASE - BRIEFING INCIDENT TO - KELLY'S AND JOHN'S CREWS - THIS CONCLUDES BRIEFING TO ALL 4 CREWS OF STEP #3. CHECK SIX: START ROLL OUT OF STEP # 4 OF - 'THE 7 STEP RESTART CRITERIA FOR RESUMPTION OF DOYON 16 OPERATIONS AT MILNE POINT. 18:00 - 00:00 6.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS - CLEAN CONTAMINATED GRAVEL FROM FRONT WHEEL DRIP PANS. - COMPLETE SHAKER WORK ORDER, CLEAN SHAKER SCREENS AND POSSUM BELLY. 5/2/2012 00:00 - 05:30 5.50 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS - INSPECT LIFTING EQUIPMENT. 05:30 - 10:00 4.50 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS - INSPECT LIFTING EQUIPMENT. - REVIEW ESP SPOOLER PROCEDURE. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 49 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 18:00 8.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - BILL HOPKINS PREFORMED DERRICK INSPECTION. - DDI SAFETY REP VISIT. 18:00 - 00:00 6.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS - BILL HOPKINS COMPLETED DERRICK AND SUB INSPECTION. - BP RWO SUPERINTENDENT PRESENTED THE MPL -06 GAS RELEASE TO NIGHT WSL, SCS AND TOUR PUSHER. - CHECK SIX REVIEWED UPDATED WELL KILL SOP WITH NIGHT WSL, SCS AND TOUR PUSHER. - REPAIR STABBING BOARD WINCH. - REPAIR STEAM LINE IN PIT # 4. 5/3/2012 00:00 - 05:30 5.50 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS 05:30 - 12:00 6.50 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS. - REVIEW BP SOP: REMOVAL OF FLANGE AND / OR JEWELRY FROM ANNULUS CASING VALE. 12:00 - 18:00 6.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - DOYON DRLG SUPERINTENDENT VISIT WITH KELLY'S CREW. - BILL HOPKINS INSPECT AND AUDIT THE SUBSTRUCTURE. - WELLS GROUP START CIRCULATION KILL ON MPL -06 WITH MI MUD ENGINEER AT 13:00 HRS. 18:00 - 00:00 6.00 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS. - WELLS GROUP COMPLETED WELL KILL AT 22:00 HRS - MONITOR TBG AND VA PRESSURES. - REMOVE HYDRAULIC TANK FROM PIPE SHED FOR SIGHT GLASS INSTALL. - LOADER CLEAR SNOW DRIFTS ON PAD. - REPLACE PIN KEEPERS ON REAR MOVE SYSTEM. - PRIME AND PAINT STAIRS IN TRUCK SHOP. Printed 5/29/2012 10:59:05AM 40 North America - ALASKA - BP Page 50 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/4/2012 00:00 - 05:30 5.50 MOB P PRE WAIT ON WELLS GROUP TO COMPLETE WELL KILL OPERATIONS ON MPL -06 - PERFORM RIG WORK ORDERS. - WELLS GROUP MONITOR TBG AND VA PRESSURES UNTIL 0 PSI. - OPEN VA AND TBG. MONITOR FOR FLOW FOR 1 HR- NO FLOW. - WELL KILL COMPLETED. WELLS GROUP RDMO. - LABEL SQUEEZE MANIFOLD VALVES. 05:30 - 13:00 7.50 MOB P PRE PBU WELLS GROUP - CLEAR SNOW THAT DRIFTED IN DURING WELL KILL OPERATION. - SERVICE TREE AND SET 2 -1/2" TYPE 'H' BPV. - R/U AND MOVE (3) UP -RIGHT BRINE TANKS. 13:00 - 14:00 1.00 MOB P PRE COMPLETE "WELL WORK TRANSFER PERMIT" WITH PAD OPERATOR. - ALL WELL HEAD VALVES SECURED. - CLEAN OUT SNOW AROUND CELLAR. - DIG SNOW OUT CELLAR BOX. - LAY HERCULITE AND MATS. 14:00 - 18:00 4.00 MOB P PRE PJSM RIG MOVE. - MOVE RIG AROUND MPL -PAD TO MPL -06 - SPOT OVER WELL. - RIG ACCEPTED ON MPL -06 AT 1800 HRS 18:00 - 00:00 6.00 RIGU P PRE PJSM, R/U AND SPOT CREW CHANGE TRAILER. - FUEL TRAILER - PIPE SHED RAMPS, ECT. - SPOT CUTTINGS BOX AND FLOWBACK TANK. - LOTO MASTER AND INNER VA VALVES. - R/U KILL MANIFOLD IN CELLAR. 5/5/2012 00:00 - 04:00 4.00 RIGU P PRE PJSM, - R/U KILL MANIFOLD IN CELLAR. - HARDLINE CREW R/U HARDLINE TO FLOWBACK TANK. - LOAD 266 BBLS 11.5 PPG BRINE INTO PITS. - PT HARDLINE TO 250/3500 PSI. - R/U O/A HOSE TO SLOP TANK. - LOAD 2 7/8" HANDLING EQUIPMENT ONTO RIG FLOOR. - 0 PSI ON O /A. 04:00 - 06:00 2.00 RIGU P PRE REVIEW DDI WELL KILL TRAINING PLAN - REVIEW VALVE ALIGNMENT SCENARIOS ON KILL MANIFOLD IN CELLAR WITH ALL RIG CREW MEMBERS. - ESTABLISH SPECIFIC TASKS, ROLES, RESPONSIBILITIES. 06:00 - 12:00 6.00 RIGU P PRE TRAIN, ASSESS AND DOCUMENT THAT ALL DDI CREWS ARE COMPETENT TO CONDUCT WELL KILL OPERATIONS AT MPU. -ALL CREWS WERE INSPECTED AGAINST THEIR KNOWLEDGE OF PROCEDURES AND COMPETENCY WITH RESPECT TO WELL KILL OPERATIONS. - CONDUCTED BY RWO FIELD SUPERINTENDANT, WSL, TOOLPUSHER, AND CHECK SIX REPRESENTATIVE. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 51 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:00 1.00 RIGU P PRE SERVICE RIG -CHECK ESD -TEST ALARM ON FLOW BACK TANK. 13:00 - 00:00 11.00 RIGU P PRE TRAIN, ASSESS AND DOCUMENT THAT ALL DDI CREWS ARE COMPETENT TO CONDUCT WELL KILL OPERATIONS AT MPU. -ALL CREWS WERE INSPECTED AGAINST THEIR KNOWLEDGE OF PROCEDURES AND COMPETENCY WITH RESPECT TO WELL KILL OPERATIONS. - CONDUCTED BY RWO FIELD SUPERINTENDANT, WSL, TOOLPUSHER, AND CHECK SIX REPRESENTATIVE. - REVIEW BP /DDI BRIDGING DOCUMENT. - REVIEW SOP FOR BREAKING CONTAINMENT. -18:00 I/A PSk 0 -18:00 NOTIFY AOGCC OF UPCOMING BOP TEST. 5/6/2012 00:00 - 12:00 12.00 RIGU P PRE TRAIN, ASSESS AND DOCUMENT THAT ALL DDI CREWS ARE COMPETENT TO CONDUCT WELL KILL OPERATIONS AT MPU. - ALL CREWS WERE INSPECTED AGAINST THEIR KNOWLEDGE OF PROCEDURES AND COMPETENCY WITH RESPECT TO WELL KILL OPERATIONS. - REVIEW BP /DDI BRIDGING DOCUMENT. - REVIEW SOP FOR BREAKING CONTAINMENT. - CONDUCTED BY WSL, TOOLPUSHER. - 04:30 I/A PSI 0 Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 52 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 20:00 8.00 RIGU P PRE TRAIN, ASSESS AND DOCUMENT THAT ALL DDI CREWS ARE COMPETENT TO CONDUCT WELL KILL OPERATIONS AT MPU. -ALL CREWS WERE INSPECTED AGAINST THEIR KNOWLEDGE OF PROCEDURES AND COMPETENCY WITH RESPECT TO WELL KILL OPERATIONS. - REVIEW BP /DDI BRIDGING DOCUMENT. - REVIEW SOP FOR BREAKING CONTAINMENT. - CONDUCTED BY WSL, TOOLPUSHER, CHECK SIX, RWO FIELD SUPERINTENDANT AND DDI FIELD SUPERINTENDANT. - SUBMIT DDI WELL KILL TRAINING SUMMARY TO RWO FIELD SUPERINTENDANT AND WTL FOR REVIEW. - SUBMIT AAR FINDINGS TO DDI TOWN TEAM FOR REVIEW. - CONDUCT WEEKLY SAFETY MEETING WITH ON COMING CREW TRIER SHIFT. -MAIN FOCUS ON CONTROL OF WORK / MANAGING RISK. - REVIEW RECENT SAFETY BULLETINS. - REVIEW DDI DERRICK AND SUB BASE INSPECTION RESULTS. - INVESTIGATE AND CORRECT FINDINGS. -PJSM, LOAD 4" DRILL PIPE INTO PIPE SHED, NUMBER AND STRAP THE SAME. -PJSM, HANG ESP SHEAVE IN DERRICK -18:00 UPDATE AOGCC FOR UPCOMING INITIAL BOP TEST. 20:00 - 21:00 1.00 WHSUR P DECOMP RECIEVED APPROVAL FROM WTL TO PROCEED WITH WELL OPS. - CONTINGENT UPON APPROVED OPS NOTE FROM TOWN TO PROCEED. -I /A PS k 10 PSI. 21:00 - 22:00 1.00 WHSUR P DECOMP CONDUCT RIG EVACUATION DRILL. - MUSTER IN SAFE BRIEFING AREA. - CONDUCT AAR TABLE TOP DISCUSSION IN DOG HOUSE. -CREW DISCUSSED SECURING WELL WITH SSV IF NEEDED. 22:00 - 00:00 2.00 BOPSUR P PRE - CONTINUE TO LOAD 4" DRILL PIPE IN PIPE SHED. -PJSM FOR TESTING KILL MANIFOLD, REVIEW DDI SOP. -R/U TO TEST MANIFOLD. - CONDUCT WEEKLY SAFETY MEETING WITH ON COMING CREW BEFORE THIER SHIFT. -MAIN FOCUS ON CONTROL OF WORK / MANAGING RISK. - REVIEW RECENT SAFETY BULLETINS. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 53 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/7/2012 00:00 - 01:30 1.50 WHSUR P DECOMP PJSM, REVIEW DDI SOP FOR KILL MANIFOLD TEST -TEST KILL MANIFOLD, HARDLINES AND 2 CHECK VALVES TO 250/3500 PSI 5 MIN EACH. -CHART RECORD TEST. -BLOW DOWN MANIFOLD AND LINES. 01:30 - 02:00 0.50 WHSUR P DECOMP METHANE GAS RIG EVACUATION DRILL. -ALL PERSONNEL ON LOCATION GATHERED AT MUSTER AREA. AAR - DISCUSSED WITH ALL HANDS THE IMPORTANCE OF OBSERVING ACTUAL WIND DIRECTION AT TIME OF EVACUATION BY VISUALLY VERIFYING WIND SOCKS, BOILER STEAM DIRECTION. - CONFIRMED WITH TRUCK DRIVERS THAT IN THE EVENT OF ACTUAL GAS RELEASE THEY WILL SHUT DOWN ALL IGNITION SOURCES AND PROCEED UPWIND FROM RIG. - DRIVERS WERE MADE AWARE OF 3RD PARTY ESCAPE PACK PLACEMENT CHART IN SCS SIGN IN TRAILER. HAND OUTS ARE AVAILABLE THERE ALSO. 02:00 - 02:30 0.50 WHSUR P DECOMP PJSM, REVIEW SOP FOR P/U LUBRICATOR AND TEST TO 250 PSI / 4000 PSI. -WSL, TOOLPUSHER, RIG CREW, AND DRILL SITE MAINTENANCE CREW IN ATTENDANCE. 02:30 - 03:00 0.50 WHSUR P DECOMP M/U LUBRICATOR ON WELLHEAD. R/U TO TEST. 03:00 - 03:45 0.75 WHSUR P DECOMP TEST LUBRICATOR AGAINST SWAB, MASTER VALVES. -TEST TO 250 PSI LOW / 4000 PSI HIGH WITH RIG TEST PUMP. -HOLD EACH TEST FOR 5 MINUTES. CHART RECORD EACH TEST. 03:45 - 05:00 1.25 WHSUR P DECOMP PULL BPV. - TEST AGAINST MASTER VALVE TO 250 PSI LOW / 4000 PSI HIGH. - SERVICE MASTER AND SWAB VALVE. - HOLD EACH TEST FOR 5 MINUTES. CHART RECORD EACH TEST. - PULL 2 -1/2" TYPF 'H' RPV - TBG IS ON A SLIGHT VAC. - IA UNREADABLE PRESSURE. 05:00 - 05:30 0.50 WHSUR P DECOMP TEST MASTER AND LUBRICATOR 250 LOW - 4000 PSI F/ 5 CHARTED MIN. -BLEED TO V PSI. -R/D LUBRICATOR. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 54 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 07:00 1.50 WHSUR P DECOMP R/U TO CHOKE, FILL LINES AND BODY TEST 250 LOW - 3500 PSI F/5 CHARTED MIN. - AT 06:00 HRS LEFT MESSAGE WITH AOGCC ON UPCOMING BOPE TEST TIME. - INSTALLED A '0' - 100 PSI GAUGE ONTO THE IA. WITH A READING OF 8 - PSI. - WSL MONITOR THE TBG AND IA FOR 15 MINUTES. - CALLED BP WTL AND REPORT THE 8 - PSI ON Al. BP WTL SAID TO DISCUSS THIS AT THE TOWN MORNING CALL WITH THE ENGINEERING TEAM. 07:00 - 08:00 1.00 EVAL P DECOMP PLAN FORWARD AFTER THE MORNING CALL. - HAVE WELL SUPPORT SHOOT TBG AND IA FLUID SHOTS. - REPORT RESULTS TO RWO ENGINEER. - PLAN TO BLEED TO FLOW BACK TANK. 08:00 - 09:00 1.00 WHSUR P DECOMP PJSM, BLOW DOWN RIG CHOKE AND DRAIN GAS BUSTER. -LOAD AND STRAP 4" DP INTO PIPE SHED. 09:00 - 10:30 1.50 EVAL P DECOMP PJSM WITH WELL SUPPORT CREW. - WELL SUPPORT TECH TOOK FLUID LEVEL SHOTS OF TBG AND IA. - SEND PAPER CHART TO MPU WELL OPS TL TO VERIFY RESULTS. - FLUID AT 300' - 400' MD - DISCUSSED RESULTS WITH RWO ENGINEER TL AND RWO SUPERINTENDENT. - DISCUSSED PLAN FORWARD. 10:30 - 11:30 1.00 WHSUR P DECOMP PJSM, R/U IA LINES AFTER R/D FOR THE FLUID SHOT - AND RETEST 250 PSI / 3500 PSI - FOR 5 CHARTED MINUTES. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 55 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- OOVHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 13:00 1.50 WHSUR P DECOMP PJSM, WSL AND TOOL PUSHER VERIFY ALL VALVE ALIGNMENT - CIRCULATE KWF (11.5 PPG NA/BR) DOWN THE TBG TO THE FLOW BACK TANK. - OPEN CHOKE TO FLOW BACK TANK. - PUMP 14 BBLS KWF DOWN THE TBG AT 1 BPM / 60 PSI AND '0' PSI DOWN STREAM. - WITH NO FLUID RETURNS TO SURFACE. - INCREASING TO 3 BPM / 250 PSI WITH 20 PSI DOWN STREAM - RETURNS TO SURFACE AFTER 14 BBLS PUMPED. - <1 BBL CRUDE IN RETURNS. - 25 BBLS TOTAL KWF PUMPED. - FCP = 3 BPM / 400 PSI WITH 30 PSI DOWN STREAM PRESSURE. - RETURN KWF = 11.5 PPG NA/BR, VERY CLEAN. - PUMPS OFF SHUT -IN WELL AT THE TREE FOR 15 MINUTES. - BLEED TRAPPED AIR OFF TBG. - WELL SHUT -IN AT THE TREE FOR 30 MINUTES. - CREW TOUR CHANGE PJSM. - RECORD BOTH TBG AND IA ON A SLIGHT VACUUM. - DISCUSSED RESULTS WITH RWO ENGINEER AND RWO SUPERINTENDENT. 13:00 - 14:00 1.00 WHSUR P DECOMP PJSM, BLOW DOWN AND R/D FLOW BACK TANK LINE - R/U TO RIG CHOKE AND FILL GAS BUSTER WITH KWF, 11.5 PPG NA/BR. - TEST CHOKE LINES 250 / 3500 PSI FOR 5 CHARTED MINUTES. 14:00 - 18:30 4.50 WHSUR P DECOMP PJSM, WSL AND TOOL PUSHER VERIFY ALL VALVE ALIGNMENT - SURFACE TO SURFACE CIRCULATION WITH 11.5 PPG NABR. - 14:50 HRS: PUMP (1 BPM / 100 PSI) 2 BPM / 200 PSI DOWN THE TBG WITH '0' PSI, IA PRESSURE. - NO RETURNS THROUGH THE GAS BUSTER TO THE PITS. - AFTER 17 BBLS PUMPED, CLEAN RETURNS ARRIVED AT THE PITS. - PUMPED TOTAL 440 BBLS OF 11.5 PPG KWF AT 3 BPM / 480 PSI - 11.5 PPG IN AND OUT, MAINTAINED. - LOST 84 BBLS TO THE FORMATION. - — 30 BPH LOSS RATE WITH PUMPS ON. - PUMPS OFF AT 15:15 HRS. WELL SHUT -IN FOR 30 MINUTES. - RECORD BOTH TBG AND IA ON A SLIGHT VACUUM. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 58 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase _ Description of Operations (hr) (ft) 18:30 - 20:00 1.50 WHSUR P DECOMP PJSM WITH VALVE CREW, REVIEW SOP FOR INSTALLING TWC. -CHECK LIFTING CERTS ON LUBRICATOR. -M /U LUBRICATOR -PT LUBRICATOR TO 250/4000 PSI AGAINST CLOSED MASTER VALVE 5 MINUTES EACH. CHART RECORD TESTS. - INSTALL TWC. 20:00 - 22:00 2.00 WHSUR P DECOMP LINE UP TO PERFORM ROLLING PRESSURE TEST ON BOTTOM OF TWC. - MONITOR FOR ANY RETURNS ABOVE TWC VIA WING VALVE. -PUMP DOWN VA STARTING 3 BPM AT 580 PSI. - CONTINUE PUMPING DECREASING TO 1 BPM AT 510 PSI, PUMP 27 BBLS. -PUMP 10 MIN TOTAL CHARTING TEST. - HALFWAY THROUGH TEST SLIGHT DRIBBLE NOTED ABOVE TWC. - NOTIFY ODE OF RESULTS. - DECISION MADE TO PULL AND INSPECT TWC. 22:00 - 00:00 2.00 WHSUR N DFAL DECOMP CLOSE MASTER, PT LUBRICATOR AGAINST MASTER -5 MINUTES EACH, CHART TEST. CLOSE SWAB. -C /O RUNNING TOOLS TO RETRIEVE TWC. -M /U LUBRICATOR. PT TO 250/4000 PSI AGAINST MASTER 5 MIN EACH. -CHART TEST. OPEN MASTER VALVE. -PULL TWC. CLOSE MASTER VALVE. -PT AGAINST MASTER VALVE 250/4000 PSI 5 MIN EACH. -CHART TEST. - INSPECT TWC. FOUND SLIGHT NICK IN UPPER SEAT ON TWC. -KEEP VA FULL WITH CHARGE PUMP. 5/8/2012 00:00 - 01:30 1.50 WHSUR N DFAL DECOMP PJSM, REVIEW SOP FOR TESTING LUBRICATOR AND TWC. -M /U LUBRICATOR AND NEW TWC. -PT TO 250/4000 PSI 5 MINUTES EACH. -CHART TEST. -SET TWC. 01:30 - 02:00 0.50 WHSUR N DFAL DECOMP LINE UP TO PERFORM ROLLING PRESSURE TEST ON BOTTOM OF TWC. -MONITOR FOR ANY RETURNS ABOVE TWC VIA WING VALVE. -PUMP DOWN VA STARTING 3 BPM AT 600 PSI. - CONTINUE PUMPING DECREASING TO 1.2 BPM AT 555 PSI, PUMP 35 BBLS. -PUMP 10 MIN TOTAL CHARTING TEST. 02:00 - 03:00 1.00 WHSUR P DECOMP R/U TO TEST TWC FROM ABOVE TO 250/4000 P515 MIN EACH. -CHART TEST. 03:00 - 03:30 0.50 WHSUR P DECOMP PJSM, REVIEW SOP FOR R/D DSM LUBRICATOR. -CLOSE MASTER AND SWAB VALVE. -R/D DSM LUBRICATOR AND COMPONENTS. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 57 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 05:00 1.50 WHSUR P DECOMP PJSM FOR R/D KILL MANIFOLD. - BLOW DOWN ALL CIRCULATING LINES, CHOKE MANIFOLD. -R/D AND REMOVE KILL MANIFOLD FROM CELLAR. -R/U HOSE TO FILL VA CONTINUOSLY USING RIG CHARGE PUMP AND BLEEDER. 05:00 - 07:00 2.00 BOPSUR P DECOMP PJSM WITH CAMERON WH REP, REVIEW SOP FOR N/D TREE, N/U BOPE. -TWO BARRIERS IN PLACE ARE MONITORED KWF, TESTED TWC AND HANGER SEALS. - MARK TREE ALIGNMENT PINS FOR RE- INSTALLATION. - WITH GAUGE INSTALLED ON VA MONITOR FOR PRESSURE. -FILL VA CONTINUOSLY USING RIG CHARGE PUMP AND BLEEDER. -N /D TREE AND ADAPTOR FLANGE. - CAMERON REP INSPECT HANGER LIFTING THREADS. TOP- 2 7/8" EUE 8RD. - 7 (R) TURNS TO M/U. - REMOVE TREE AND ADAPTOR FLANGE FROM CELLAR. -I /A TAKING APPROX 16 BPH. 07:00 - 10:30 3.50 BOPSUR P DECOMP PJSM. N/U 13 5/8" X 5M BOPE. - N/U 11" / 5M X 13 5/8" / 5M ADAPTER SPOOL. - N/U BOPE STACK. FUNCTION TEST ALL RAMS & HCR VALVES. OK. 10:30 - 12:00 1.50 BOPSUR P DECOMP PJSM. RIG UP TO TEST BOPE. 12 HOUR LOSSES TO WELL = 121 BBLS. 12:00 - 13:00 1.00 BOPSUR P DECOMP FINISH RIGGING UP TO TEST BOPE. - PJSM ON TESTING BOPE. 13:00 - 22:30 9.50 BOPSUR P DECOMP CONDUCT FULL TEST ON BOPE, - AOGCC STATE REP MATT HERRERA WITNESSING TEST. - DETECT LEAK BETWEEN WELLHEAD FLANGE AND BOPE FLANGE. - PROPERLY TORQUE ALL STUDS, OK. - RESUME FULL TEST ON ALL BOPE COMPONENTS. - TESTING © 250 / 4000 PSI, 5 MIN EACH / CHARTED. - TEST ANNULAR PREVENTOR @ 250 / 3500 PSI, 5 MIN EACH / CHARTED. - TEST UPPER AND LOWER VBRS WITH 2 7/8" AND 4" TEST JTS. - PERFORM ACCUMULATOR DRAW DOWN TEST. - PERFORM PRESSURE BLEED TEST ON MANUAL AND HYD. CHOKE TO 1500 PSI 5 MIN EA. CHARTED. - TEST LEL ALARMS. - 1 -F /P NOTED ON LEL AUDIBLE METHANE ALARM. - ELECTRICIAN REPAIRED ALARM, RE -TEST GOOD. - I/A TAKING APPROX 9 BPH. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 58 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 23:00 0.50 BOPSUR P DECOMP - R/D BOP TESTING EQUIPMENT. - DRAIN STACK, BLOW DOWN CHOKE, KILL LINE AND GAS BUSTER. 12 HR LOSSES TO WELL = 100 BBLS. 23:00 - 00:00 1.00 BOPSUR P DECOMP PJSM, PU LUBRICATOR AND OPSO LOPSO FOR PULLING TWC. 5/9/2012 00:00 - 01:00 1.00 BOPSUR P DECOMP PJSM, REVIEW SOP FOR PULLING TWC. -DSM REPS, CAMERON WH REPS, WSL, TOOLPUSHER, RIG CREW IN ATTENDANCE. -M /U LUBRICATOR, LUBRICATOR EXTENSION AND PUMP IN SUB. 01:00 - 02:00 1.00 BOPSUR P DECOMP -P/T LUBRICATOR / OPSO LOPSO TO 250/4000 PSI 5 MINUTES EACH. -CHART RECORD TEST. 02:00 - 02:45 0.75 BOPSUR P DECOMP PULL TWC. - MONITOR FOR TBG PRESSURE. 0 PRESSURE OBSERVED. -FILL VA WITH 5.5 BBLS OF 11.5 PPG. KWF. -SHUT IN VA. -WELL ON VACUUM AFTER FILLING VA. - MONITOR WELL 30 MINUTES. WELL ON VACUUM. 02:45 - 03:30 0.75 BOPSUR P DECOMP R/D LUBRICATOR , OPSO LOPSO, AND DSM EQUIPMENT. -FILL HOLE WITH 11.5 PPG KWF VIA TRIP TANK. 03:30 - 03:50 0.33 BOPSUR P DECOMP PJSM, REVIEW SOP FOR M/U TBG HANGER RETRIEVAL TOOL ON LANDING JOINT. - CAMERON WH REPS, WSL, TOOLPUSHER, RIG CREW IN ATTENDANCE. -M /U LANDING JOINT / HANGER RETRIEVAL TOOL. M/U TOP DRIVE TO LANDING JOINT. - CAMERON WH REPS BACKED OUT LDS. 03:50 - 04:00 0.17 PULL P DECOMP PULL TBG HANGER FREE WITH TOP DRIVE M/U TO LANDING JOINT. -TBG HANGER UNSEATED WITH 100 K ON WEIGHT INDICATOR. -P /U 2 FEET WITH TBG HANGER. METHANE LEL ALARM SOUNDED IN CELLAR. -0 READING IN CELLAR. - DRILLER SLACKED OFF 1 FOOT WITH HANGER. 04:00 - 04:10 0.17 EVAL P DECOMP RIG LEL ALARM SOUNDED IN CELI AR SENSORS ALL READ- 0- LEL. -TOUR PUSHER CHECKED AREA WITH HAND HELD MONITOR. - DETERMINED TO BE FALSE ALARM. 04:10 - 04:30 0.33 PULL P DECOMP CONTINUE TO PULL TBG HANGER FREE. -PULL HANGER UP 4 FT. UP WT 110K W /BLOCKS INCLUDED. - MONITOR WELL. STATIC. 04:30 - 04:35 0.08 BOPSUR P DECOMP CLOSE ANNULAR. LINE UP CHOKE TO GAS BUSTER -START PUMPING ESTABLISH RETURNS. - H2S ALARM SOUNDED FROM SENSOR IN CELLAR. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 59 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:35 - 05:15 0.67 BOPSUR P DECOMP SECURE WELL BY CLOSING CHOKE AND TOP DRIVE IBOP. - EVACUATE RIG TO MUSTER AREA. - VERIFY HEAD COUNT- ALL ACCOUNTED FOR. - LEVEL 0 NOTIFICATIONS MADE. - REVIEW DDI RIG RE -ENTRY SOP. - DRILLER AND FLOORHAND DONNED SCBA. -MAKE SWEEP WITH PORTABLE GAS MONITOR FROM CELLAR TO RIG FLOOR. - NO GAS DETECTED. CELLAR SENSOR READING 0 PPM. - DRILLER CALLED ALL CLEAR TO RETURN TO THE RIG. 05:15 - 05:30 0.25 BOPSUR P DECOMP HANDS RETURNED TO THE RIG -WELL REMAINS SHUT IN. 05:30 - 12:00 6.50 BOPSUR P DECOMP WELL REMAINS SHUT IN. - DISCUSS WELL PROGRAM WITH TOWN. -FILL VA THRU KILL LINE EVERY HALF HOUR. -WELL TAKING 4 - 6 BBLS / HOUR. -WORK ON GAS ALARMS. 12:00 - 14:00 2.00 PULL P DECOMP PRE TOUR SAFETY MEETING WITH CREW COMING ON TOUR. - SERVICE RIG, DO CHANGE OUT. -PRE JOB MEETING / HAZARD ANALYSIS / RISK MANAGEMENT ASSOCIATED WITH JOB. - CONTINUE TO FILL HOLE EVERY HALF HOUR. - TOTAL LOSSES TO WELL IN PAST 12 HRS. 67 BBLS. 14:00 - 15:00 1.00 PULL P DECOMP CHECK FOR PRESSURE, OPEN ANNULAR. -PULL HANGER TO RIG FLOOR, 110K UP WT. -THIS INCLUDES WT OF TOP DRIVE, WHICH 1S 40,000 LBS. - ACTUAL WEIGHT BEING PULLED IS 70,000 LBS. -CUT ESP CABLE JUST ABOVE 1ST CLAMP. -BREAK OUT AND LAY DOWN HANGER AND PUP. -MAKE UP SAFETY JT W/ FULL OPEN SAFETY VALVE. -RIH W/ SAFETY VALVE, M/U TOP DRIVE. 15:00 - 17:30 2.50 PULL P DECOMP PJSM. CLOSE ANNULAR, LINE UP TO CIRCULATE WELL. - PUMP 11.5 PPG BRINE DOWN 2 7/8" EUE 8 RND TUBING. -PUMP @ 3 BPM / 440 PSI, TAKING RETURNS THRU CHOKE AND MUD GAS SEPARATOR. -LOSS RATE WHILE PUMPING 10 - 12 BPH. Printed 5/29/2012 10:59:05AM • North America - ALASKA - BP Page 60 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 18:30 1.00 PULL P DECOMP PJSM FOR PULLING ESP WITH CENTRALIFT REP, CREW, WSL AND TOUR PUSHER. - CENTRALIFT PROVIDED CERTS FOR ESP SHEAVE. - REVIEW SOP FOR PULLING ESP. - DISCUSS ESP CABLE MANAGMENT FOR SHUTTING IN THE WELL. -HOLE FILL, RISK OF POTENTIAL SWABBING DUE TO CUPS ON PACKER. -SPILL CONTAINMENT FOR ESP CABLE WHILE SPOOLING. -NON SHEARABLES ACROSS BOP WHEN PULLING PUMP. - FLOWCHECK WELL FOR 30 MIN BEFORE PULLING PUMP TO SURFACE. 18:30 - 19:30 1.00 PULL P DECOMP WITH 0 PSI ON WELL, OPEN CHOKE, ON VAC. OPEN ANNULAR. - 6 BBLS TO FILL HOLE. -BREAK OFF TOP DRIVE, UD SAFETY JT AND FLOOR VALVE. - BLOW DOWN CHOKE AND TOP DRIVE, DRAIN GAS BUSTER. -HANG ESP SHEAVE, SECURE WITH SAFETY CABLE. 19:30 - 20:00 0.50 PULL P DECOMP POH AND UD 2 7/8" TBG. SPOOLING ESP CABLE. -UD 3 JTS 2 7/8" TUBING. - ATTACH ESP LINE TO SPOOLING UNIT 20:00 - 21:00 1.00 PULL P ■- DECOMP POH AND UD 2 7/8" TBG, SPOOLING ESP CABLE. - MONITOR FOR POTENTIAL SWABBING. 21:00 - 21:30 0.50 PULL P DECOMP STOP PULLING TBG. - REPOSITION SPILL CONTAINMENT FOR ESP CABLE -DUE TO WIND DIRECTION. 21:30 - 00:00 2.50 PULL P DECOMP CONTINUE POH AND UD TUBING, SPOOLING ESP CABLE. -40 JTS OUT NOTED ESP CABLE DAMAGE. - KINKED CABLE AT 338' AND 345'. PARTED ARMOR ON CABLE AT 350' -TOTAL LOSSES TO WELL IN THE PAST 12 HRS= 26 BBLS. -TOTAL LOSSES TO WELL IN THE PAST 24 HRS= 93 BBLS. - WELL CURRENTLY TAKING 6 - 8 BPH 5/10/2012 00:00 - 02:30 2.50 PULL P DECOMP CONTINUE POH AND UD 2 7/8" TUBING, SPOOLING ESP CABLE. -67 JTS OF 2 7/8" TBG OUT. - POWER TONG NOT OPERATING PROPERLY. -HIGH GEAR FAILURE, DEVELOPED LEAK IN GEAR BOX. 02:30 - 03:00 0.50 PULL N RREP - DECOMP PJSM, SWAP OUT POWER TONGS. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 61 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 09:30 6.50 PULL P DECOMP CONTINUE POH AND LID 2 7/8" TUBING, SPOOLING ESP CABLE. - WELL CONTINUES TAKING 6 - 8 BPH. - @ 3200' - 3550' MULTIPLE RUPTURES ON ESP LINE. - JT 139, DEPTH 4448', (2) HOLES, 3/4" DIAMETER. - MONITOR WELL SEVERAL TIMES WHILE POOH, 15 MIN EACH, WELL STABLE. 09:30 - 10:00 0.50 PULL P DECOMP KICK DRILL WHILE TRIPPING - SIMULATED CUTTING ESP CABLE, LOWERING CLEAN JT ACROSS STACK. - FULL OPEN SAFETY VALVE INSTALLED AND CLOSED. - SIMULATED CLOSING ANNULAR PREVENTOR. - WELL SECURED, MONITOR WELL PRESSURES, CHECK PIT GAIN. - AAR CONDUCTED BY CHECK SIX AND TOOLPUSHER. - WELL SHUT IN, ALL HANDS AT THEIR RESPECTIVE STATIONS. 2 MIN 38 SEC. 10:00 - 12:00 2.00 PULL P DECOMP CONTINUE POH AND UD 2 7/8" TUBING, SPOOLING ESP CABLE. - WELL CONTINUES TAKING 6 - 8 BPH. - TOTAL LOSSES FOR LAST 12 HOURS = 92 BBLS OF 11.5 PPG BRINE. - O/A PRESSURE = 0 PSI. 12:00 - 12:30 0.50 PULL P DECOMP SERVICE AND INSPECT RIG EQUIPMENT. 12:30 - 13:30 1.00 PULL P DECOMP PJSM W/ CENTRILIFT, IDENTIFYING ALL HAZARDS. - REVIEWED PROCEDURES. 13:30 - 14:00 0.50 PULL P DECOMP CONDUCTED KICK WHILE TRIPPING DRILL. - MADE CUT ON SPARE PIECE OF ESP CABLE. - LOWERED TBG INTO WELL WITH CLEAN JT ACROSS BOPE. - INSTALLED SAFETY VALVE, CLOSED SAFETY VALVE. - SIMULATED CLOSING ANNULAR PREVENTOR. - MONITOR FOR PIT GAIN. - WELL SHUT IN, ALL HANDS AT THEIR RESPECTIVE STATIONS 2 MIN 17 SEC. - AAR ON DRILL. FINDINGS INCLUDED THE NEED FOR A HORN OR OTHER LOUD ALARM FOR A WELL CONTROL EVENT. 14:00 - 15:00 1.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" TUBING. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP ID Page 62 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:00AM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 16:30 1.50 PULL N RREP DECOMP DRILLER NOTED EXCESSIVE AMOUNT OF , GAS BREAKING OUT OF FLOW NIPPLE. (PACKER GAS). NO FLOW. - DRILLER NOTED 25% LEL, NO HIGH LEVEL ALARMS. ELECTED TO SHUT IN WELL. - ESP CABLE WAS CUT AND SECURED TO TBG. y, , - (1) FULL JT HANGING ABOVE WAS LOWERED ACROSS BOP. - FULL OPENING SAFETY VALVE INSTALLED & CLOSED. - f CLOSEQ WSL NOTIFIED. , - DURING THE CLOSE IN PROCESS A FAILURE OF THE BOP REMOTE ACTIVATION SYSTEM OCCURRED. - ALL HANDLES ON THE ACCUMULATOR WERE PUT IN THE NEUTRAL POSITION. - ODE AND WTL IN TOWN NOTIFIED. SUPERINTENDANT IN THE FIELD NOTIFIED. - 4" DP SAFETY JT PICKED UP WITH OPEN FULL OPEN SAFETY VALVE ON TOP. - TOP DRIVE SCREWED IN, MADE READY TO PUMP DOWN TUBING. - 291 JTS LAID DOWN, DEPTH OF END OF PIPE 1362'. - BRIAN BIXBY, (MILNE POINT), NOTIFIED. - SITP = 0 PSI, VA = 0 PSI, 0/A = 0 PSI. NO PIT GAIN. -WELLS INTEGRITY TEAM LEADER RYAN DANIEL NOTIFIED JIM REGG WITH THE AOGCC @ 15:58 AND ALSO NOTIFIED GUY SCHWARTZ WITH THE AOGCC @ 16:15 ABOUT CURRENT STATUS OF THE WELL AND BOPE USE. 16:30 - 18:00 1.50 PULL N RREP DECOMP TOWN SITUATION ROOM CONGREGATING. - GIVEN PERMISSION TO PUMP DOWN TUBING TO KEEP WELL FULL. - PUMP (8) BBLS @ 1/2 - 1 BPM/ 140 PSI, KEEPING VA BELOW 50 PSI. - SHUT DOWN AND OBSERVE VA PRESSURE RETURN TO 0 PSI. - CLOSE CONTACT WITH TOWN TEAM MAINTAINED THROUGHOUT. - INVESTIGATE FAILURE WITH ACCUMULATOR SYSTEM, DOYON FIELD SUPERINTENDANT PRESENT. Printed 5/29/2012 10:59:05AM Noah America - ALASKA - BP Page 63 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 18:00 - 21:00 3.00 PULL N RREP (ft) DECOMP - KEEP HOLE FULL. PUMP 7- 8 BBLS @ 1BPM DOWN TBG EVERY 1/2 HR NOT EXCEEDING 50 PSI ON VA. - RECORD VA AND TBG PRESSURES EVERY 1/2 HR. I /A= 12 PSI, TBG 10 PSI. - AFTER PUMPING VA WOULD BLEED TO 12 PSI. - DEVELOP A PLAN FORWARD WITH TOWN TEAM TO SECURE WELL WITH UPPER VBR, CIRCULATE WELL AT 1362', MONITOR AND CIRCULATE WELL WHILE MAKING ACCUMULATOR REPAIRS. - WSL, DDI FIELD SUPERINTENDANT, RWO FIELD SUPERINTENDANT, TOOL PUSHERS, DDI HSE REP AND BP HSE IN ATTENDANCE. - NOTIFY MPU ENVIROMENTAL OF APPROX 75 GAL HYDRAULIC OIL SPILL IN SECONDARY CONTAINMENT AT ACCUMULATOR. AT 18:30 - CONTINUE TO CLEAN AT ACCUMULATOR AREA. 21:00 - 22:00 1.00 PULL N RREP DECOMP RECIEVED APPROVED PLAN FOWARD FROM TOWN TEAM. - CONDUCT PJSM WITH RIG CREW, WSL, DDI FIELD SUPERINTENDANT, TOOL PUSHERS AND DDI HSE REP. 22:00 - 00:00 2.00 PULL N RREP DECOMP FOLLOW PROCEDURE STEPS. - COMPLETE A LOTO ON ACCUMULATOR AIR PUMP AND ELECTRIC PUMP. - DISCONNECT UPS TO REMOTE PANEL. - REPLACE PUSH TO OPERATE SOLENOID. - FILL ACCUMULATOR RESIVOIR WITH 75 GAL HYD FLUID. - UNLOCK AND TURN ON KOOMEY AIR PUMPS. - PRESSURE UP KOOMEY TO 2600 PSI. - LOSSES TO WELL IN LAST 12 HRS= 87 BBLS. 5/11/2012 00:00 - 00:30 0.50 PULL N RREP DECOMP PJSM WITH RIG CREW, WSL, DDI FIELD SUPERINTENDANT, TOOL PUSHERS. - REVIEW PLAN FORWARD FOR CLOSING UPPER VBR, CIRC WELL AND MAKE ACCUMULATOR SYSTEM REPAIRS. 00:30 - 01:00 0.50 PULL N RREP DECOMP FOLLOW PROCEDURE STEPS. - ISOLATE PIT 3 TO PUMP FROM AND TAKE RETURNS TO. - OPEN HCR AT KOOMEY. OPEN CHOKE AND VALVE # 5 TO GAS BUSTER. - MONITOR WELL- CONTINUES ON VAC. - CLOSE UPPER VBR. OPEN ANNULAR. - STAGE PUMP UP TO 3 BPM MONITORING TBG AND VA PSI. - PUMP © 3 BPM 140 PSI. 20 PSI ON VA. 17 PSI ON O /A. - PUMP 1 CIRCULATION 45 BBLS 11.5 PPG BRINE. - SHUT DOWN PUMP. MONITOR WELL FOR 10 MIN. - HOLE CONTINUES TAKING FLUID 6 BPH. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 64 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date!Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 12:00 11.00 PULL N RREP DECOMP CONTINUE TO CIRCULATE. - PUMP 1 BPM 40 PSI. I /A= 15 PSI. - FOLLOW PROCEDURE STEPS AND MAKE ACCUMULATOR REPAIRS. - HOLE CONTINUES TAKING 6 BPH WHILE CIRCULATING. - TOTAL FLUID LOSS LAST 12 HOURS = 77 BBLS OF 11.5 PPG BRINE. - AOGCC REP MATT HERRERA GIVEN 24 HOUR NOTICE FOR IMPENDING BOPE TEST @ 08:00 HRS. - BOPE USEAGE REPORT GENERATED AND SUBMITTED @ 10:30. 12:00 - 18:00 6.00 PULL N RREP DECOMP CONTINUE TO CIRCULATE. - PUMP 1 BPM 40 PSI. VA= 15 PSI. - FOLLOW PROCEDURE STEPS AND MAKE ACCUMULATOR REPAIRS. - HOLE CONTINUES TAKING 6 BPH WHILE CIRCULATING. - MIKE MILLER CONTACTED AND APPROVED PLAN FOR PLUGGING CONTROL LINE TO CHANGE OUT PUMP RUN PRESSURE AND HIGH / LOW BYPASS. - TRACTION REPORTS GENERATED FOR 75 GALLON HYDRAULIC OIL SPILL IN ACCUMULATOR ROOM AND BOPE USEAGE. - TRACTION REPORTS 4128456 AND 4128481 RESPECTIVELY. 18:00 - 20:00 2.00 PULL N RREP DECOMP CONTINUE TO CIRCULATE. - PUMP 1 BPM 40 PSI. I /A= 10 PSI. O /A= 16 PSI. - FOLLOW PROCEDURE STEPS AND MAKE ACCUMULATOR REPAIRS. - HOLE CONTINUES TAKING 6 - 7 BPH WHILE CIRCULATING. 20:00 - 20:15 0.25 PULL N RREP DECOMP PJSM WITH CREW, RIG ELECTRICIAN, MECHANIC, DDI FIELD SUPERINTENDANT, WSL AND TOOL PUSHER. - REVIEW APPROVED PLAN FOR PLUGGING CONTROL LINE TO C/O PUMP RUN PRESSURE AND HIGH / LOW BYPASS. 20:15 - 21:00 0.75 PULL N RREP DECOMP CONTINUE PUMING 1 BPM 40 PSI. I /A= 10 PSI. 0/A= 16 PSI. -CLOSE IN AND LOTO BOTTLE BANK, VALVE TO AIR PUMP, N2 BOTTLES, - PLACE UPPER PIPE RAM AND CHOKE HANDLES IN NEUTRAL POSITION. - BLEED DOWN MANIFOLD PRESSURE AND VERIFY- LEAVE MANIFOLD BLEEDER VALVE OPEN. - REMOVE AND PLUG PUMP RUN PRESSURE AND HIGH / LOW BYPASS. - CLOSE MANIFOLD BLEEDER VALVE. - REMOVE LOCKS ON AIR PUMP, N2 BOTTLES AND BOTTLE BANK. - OPEN BOTTLE BANK SLOW. OPEN AIR SUPPLY TO PUMP, CHARGING SYSTEM TO 2600 PSI. - MOVE UPPER PIPE RAMS AND CHOKE LINE HANDLES TO CLOSED POSITION. - RIG ELECTICIAN AND MECHANIC HAVE REACHED 16 HR WORK DAY. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 65 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date!Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 PULL N RREP DECOMP CONTINUE TO CIRCULATE. - PUMP 1 BPM 40 PSI. I /A= 10 PSI. O /A= 16 PSI. - CONTINUE TO CLEAN AT ACCUMULATOR. - MONITOR VA AND O/A PRESSURES. - HOLE CONTINUES TAKING 6 -7 BPH. - TOTAL FLUID LOSS LAST 12 HOURS = 82 BBLS OF 11.5 PPG BRINE. KEEP 1 HAND STATIONED AT ACCUMULATOR. . 5/12/2012 00:00 - 12:00 12.00 PULL N RREP DECOMP CONTINUE TO CIRCULATE. - PUMP 1 BPM 40 PSI. I /A= 10 PSI. O /A= 16 PSI. - CLEAN ACCUMULATOR. - ELECTRICIAN AND MECHANIC BACK TO WORKING ON ACCUMULATOR @ 06:30. - MONITOR VA AND O/A PRESSURES. - HOLE CONTINUES TAKING 6 -7 BPH. - KEEP 1 HAND STATIONED AT ACCUMULATOR. - RIG ELECTRICIAN AND MECHANIC TO RESUME REPAIR ON ACCUMULATOR. - IN LAST (12) HOURS, FLUID LOSS TO WELL = 67 BBLS 11.5 PPG BRINE. 12:00 - 16:30 4.50 PULL N RREP DECOMP CONTINUE TO CIRCULATE. - PUMP 1 BPM 40 PSI. I /A= 10 PSI. O /A= 16 PSI. - CONTINUE TO CLEAN / REPLACE PARTS ON ACCUMULATOR. - MONITOR VA AND O/A PRESSURES. - HOLE CONTINUES TAKING 6 -7 BPH. - KEEP 1 HAND STATIONED AT ACCUMULATOR. . - RIG ELECTRICIAN AND MECHANIC TO RESUME REPAIR ON ACCUMULATOR. 16:30 - 17:30 1.00 PULL N RREP DECOMP PJSM W/ ALL PERTINENT HANDS, TOOL PUSHER AND RIG SUPERINTEDANT. - DISCONNECT HANDLES AT ACCUMULATOR AND FUNCTION TEST ACTUATORS. OK. - STATE AOGCC REP MATT CURRARA HERE TO INSPECT AND WITNESS FUNCTION TEST OF ACCUMULATOR. - SHUT DOWN PUMP, MONITOR WELL, VA ON SLIGHT VACUUM. - PERMISSION GRANTED BY WTL TO FUNCTION, (OPEN) UPPER PIPE RAMS DURING FUNCTION TEST. 17:30 - 18:15 0.75 PULL N RREP DECOMP WITH APPROVAL FROM WTL TO PROCEED. - REVIEW PLAN TO FUNCTION BOPE. - SHUT DOWN PUMP. OPEN AT CHOKE. MONITOR FOR FLOW. - WELL CONTINUES ON VAC. OPEN UPPER PIPE RAMS. - FUNCTION TEST ALL BOPE- EXCLUDING BLIND SHEAR RAM. - ALL COMPONENTS FUNCTIONED PROPERLY. - ACCUMULATOR OPERATING AT 100 % - FUNCTION TEST WITNESSED BY AOGCC, MATT HERRERA. - CLOSE UPPER PIPE RAMS, CONTINUE TO CIRCULATE 1 BPM 40 PSI WITH RETURNS THROUGH CHOKE AND GAS BUSTER. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 66 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:15 - 19:30 1.25 PULL P DECOMP NOTIFY AND RECIEVE APPROVAL TO PROCEED WITH RIG OPS FROM MIKE MILLER, WTL AND RWO FIELD SUPERINTENDANT. - INSTRUCT AND TRAIN CREW HOW TO ISOLATE AND PREVENT HYDRAULIC FLUID FOM ENTERING CONTROL PANEL BOX AT ACCUMULATOR BY ISOLATING A WHITEY VALVE ON ACCUMULATOR MANIFOLD. 19:30 - 19:45 0.25 PULL P DECOMP PJSM WITH CREW, CENTRALIFT, WSL AND TOOL PUSHER - REVIEW SOP FOR POH WITH ESP. - USE TRIP TANK, CONTINUOUSLY FILL HOLE. - CHECK HOLE FILL FLUID WT TO VERIFY 11.5 PPG. - REVIEW PLAN FOR SHUTTING WELL IN WITH ESP CABLE. - REVIEW PLAN FOR NON SHEARABLES ACCROSS BOP. - MONITOR WELL BEFORE PULLING PUMP TO SURFACE. 19:45 - 21:00 1.25 PULL P DECOMP SHUT OFF PUMP. CONTIUES ON VAC. - OPEN UPPER PIPE RAMS. 1/2 BBL TO FILL HOLE. - MONITOR WELL, HOLE CONTINUES TO TAKE 6 -7 BPH. - LOAD CENTRALIFT TOOLS ONTO RIG FLOOR. - BREAK OFF TOP DRIVE, UD SAFETY JT AND FLOOR VALVE. - BLOW DOWN CHOKE, DRAIN GAS BUSTER, BLOW DOWN TOP DRIVE. - FILL TRIP TANK 21:00 - 23:00 2.00 PULL P DECOMP UD 1 JT 2 7/8" TBG. CENTRALIFT SPLICE ESP CABLE. - POH SLOW UD 2 7/8 TBG, SPOOLING ESP CABLE. - MONITOR HOLE FILL ACCOUNTING FOR LOSSES. 23:00 - 23:15 0.25 PULL P DECOMP CONDUCT DRILL FOR NON SHEARABLES ACROSS BOP. - SIMULATE ESP PUMP AT SURFACE WITH WELL FLOWING. 23:15 - 23:45 0.50 PULL P DECOMP - POH UD 2 7/8 TBG, SPOOLING ESP CABLE. - STOP POH BEFORE ESP PUMP IS ACROSS BOP. 23:45 - 00:00 0.25 PULL P DECOMP M/U SAFETY VALVE. - MONITOR WELL BEFORE PULLING ESP PUMP. - HOLE TAKING 6 BPH - TOTAL LOSSES TO WELL IN LAST 12 HRS. 69 BBLS. 5/13/2012 00:00 - 00:30 0.50 PULL P DECOMP MONITOR WELL. WELL TAKING 6 -7 BPH. - INSTRUCT AND TRAIN CREW HOW TO ISOLATE AND PREVENT HYDRAULIC FLUID FOM ENTERING CONTROL PANEL BOX AT ACCUMULATOR BY ISOLATING A WHITEY VALVE ON ACCUMULATOR MANIFOLD. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 67 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 01:00 0.50 PULL P DECOMP PJSM WITH CREW, CENTRALIFT, WSL AND TOOL PUSHER - REVIEW SOP FOR POH WITH ESP. - USE TRIP TANK, CONTINUOUSLY FILL HOLE. - CHECK HOLE FILL FLUID WT TO VERIFY 11.5 PPG. - REVIEW PLAN FOR SHUTTING WELL IN WITH ESP CABLE. - REVIEW PLAN FOR NON SHEARABLES ACCROSS BOP. 01:00 - 06:30 5.50 PULL P DECOMP POH AND L/D LAST 2 JTS 2 7/8" TBG. - NOTE SAND IN LAST 2 JTS. - TOTAL COUNT= 326 JTS 2 7/8" UD. - PULL PUMP OUT, REMOVE ESP CABLE @ PER CENTRALIFT REP. - UD PACKER AND SCREENS. - RUN ESP PUMP IN HOLE - POH AND UD ESP PUMP © PER CENTRALIFT REP. - RECOVERED 170 ESP CABLE CLAMPS, 4 SHIELDS, 5 PUMP CENTRALIZERS. - CONTINUE TO FILL HOLE CONTINUOUSLY. - HOLE TAKING 6 BPH. 06:30 - 07:30 1.00 PULL P DECOMP PJSM. RIG DOWN CENTRILIFT SHEAVE. - RIG DOWN ALL EQUIPMENT ASSOCIATED WITH JOB. 07:30 - 08:30 1.00 PULL P DECOMP CLEAR / CLEAN RIG FLOOR. - RECOVERED 170 LA SALLE CLAMPS, 5 PROTECTROLIZERS, 4 FLAT GUARDS. 08:30 - 10:00 1.50 PULL P DECOMP PJSM. RIG UP TO TEST BOPE. 10:00 - 10:30 0.50 PULL P DECOMP PRE JOB SAFETY MEETING ON TESTING BOP EQUIPMENT. - THOROUGH REVIEW OF PROCEDURE AND ASSOCIATED RISKS. - 60 BBLS 11.5 PPG BRINE LOST TO WELL @ 12:00. LOSS RATE 4 - 5 BPH. 10:30 - 19:00 8.50 BOPSUR P DECOMP CONDUCT BOPE TEST AS PER AOGCC AND BP REQUIREMENTS. 1pe - TEST ALL VALVES ON CHOKE MANIFOLD © ' l 250 LOW, 4000 PSI HIGH, 5 MIN EACH / CHARTED. SET TEST PLUG. RILDS. - PRESSURE TEST ALL VALVES, BLIND RAMS AND PIPE RAMS @ 250 PSI LOW AND 4000 PSI HIGH, 5 MIN EACH / CHARTED. - TEST ANNULAR PREVENTOR @ 250 / 3500 PSI / 5 MIN / CHARTED. - TEST UPPER AND LOWER VARIABLE BORE RAMS WITH 2 7/8" AND 4" TEST JT. - CONDUCT DRAW DOWN TEST ON ACCUMULATOR. - AOGCC INSPECTOR MATT HERRERA WAIVED WITNESSING THE TEST. - TESTING WAS WITNESSED BY DOYON TOOLPUSHER AND BP WELL SITE LEADER. - DAY CREW CONDUCTED WEEKLY SAFETY MEETING PRIOR TO COMING ON TOUR. TOPICS INCLUDED CONTROL OF WORK, RISK MANAGEMENT AND COMMUNICATION SKILLS. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 68 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 21:00 2.00 BOPSUR P DECOMP BLOW DOWN TESTING LINES AND CHOKE. DRAIN GAS BUSTER. - R/D HOLE FILL LINE ON VA - BO4LDS. PULL TEST PLUG - R/U RUNNING TOOL, SET WEAR RING, RI4LDS. - NOTIFY ODE ABOUT ISSUE WITH BENT ALIGNMENT PIN ON TBG HANGER. - DECISION MADE NOT TO MAKE DUMMY TBG HANGER RUN. 21:00 - 21:15 0.25 BOPSUR P DECOMP PJSM WITH HES REP, CREW, TOOL PUSHER AND WSL. - REVIEW RETAINER HANDLING AND RUNNING PROCEDURE, REVIEW SOP FOR P/U DP. .z - LOAD CEMENT RETAINER AND RUNNING TOOLS ONTO RIG FLOOR. 21:15 - 22:30 1.25 ZONISO P DECOMP M/U XO, HES 7" EZSB MECHANICAL SETTING TOOL ON 2 JTS 4" DP. G ✓ - MAKE DUMMY RUN THROUGH HANGER. - M/U HES 7" EZSVB CEMENT SQUEEZE RETAINER, P/N 100004370. - SHEAR RELEASE ON RETAINER IS 40K. - CMT RETAINER= 2.63', VD= 1.19 ", O /D= 5.5" - SETTING TOOL= 4.99', VD= 1.25 ", O /D= 5.65" 22:30 - 00:00 1.50 ZONISO P DECOMP P/U AND DRIFT DP, RIH WITH 7" CMT RETAINER BHA. - CONTINUOUSLY FILL HOLE. - USE CAUTION NOT TO TURN DP WHEN M/U, MONITOR RUNNING SPEED, SET DP IN SLIPS EASY TO PREVENT PREMATURE SETTING. - CURRENT DEPTH 1902' - NIGHT CREW CONDUCTED WEEKLY SAFETY MEETING PRIOR TO COMING ON TOUR. - CHECK SIX LED SAFETY MEETING ON CONTROL OF WORK. - IMPORTANCE ABOUT STOPPING THE JOB FOR RISK MANAGMENT. - ASSERTIVE COMMUNICATION SKILLS. - WELL TAKING 4 BPH. LOSSES TO WELL IN LAST 12 HRS= 53 BBLS. 5/14/2012 00:00 - 00:30 0.50 ZONISO P DECOMP PJSM WITH HES REP, CREW, TOOL PUSHER AND CREW. - REVIEW RUNNING PARAMETERS FOR CMT RETAINER. - SOP FOR P/U DP. 00:30 - 05:30 5.00 ZONISO P DECOMP - P/U DP, DRIFT AND RIH WITH 7" CMT RETAINER BHA. - CONTINUOUSLY FILL HOLE. - USE CAUTION NOT TO TURN DP AND MONITOR RUNNING SPEED, SET DP IN SLIPS EASY TO PREVENT PREMATURE SETTING. - AT 0500 135 JTS 4" DP IN THE HOLE. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP 1 Page 69 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table ©41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 12:00 6.50 ZONISO P DECOMP - P/U DP, DRIFT AND RIH WITH 7" CMT RETAINER BHA. - CONTINUOUSLY FILL HOLE. - USE CAUTION NOT TO TURN DP AND MONITOR RUNNING SPEED, SET DP IN SLIPS EASY TO PREVENT PREMATURE SETTING. - TOTAL LOSSES TO WELL IN LAST (12) HOURS = 60 BBLS OF 11.5 PPG BRINE. - UP WT = 150K, DOWN WT = 110K @ 9484'. 12:00 - 12:30 0.50 ZONISO P DECOMP SERVICE AND INSPECT RIG. 12:30 - 13:00 0.50 ZONISO P DECOMP PRE JOB SAFETY MEETING ON RUNNING IN HOLE W/ RETAINER. 13:00 - 15:00 2.00 ZONISO P DECOMP CONTINUE IN HOLE, 329 JTS. 171K UP WT, 112K DOWN WT. 15:00 - 15:30 0.50 ZONISO P DECOMP PJSM. SET HALLIBURTON CEMENT RETAINER A 10,400'. - PICK UP TO UP WT & SLACK OFF SEVERAL TIMES TO CLEAR AREA. - PICK UP TO UP WT, PUT (37) RIGHT HAND TURNS IN PIPE, 7K FT /LBS TORQUE. - PULL UP 10K OVER, WAIT (3) MIN, PULL 10 MORE, WAIT & 1 MORE TIME. - UP WT NOW 30 OVER @ 202K. PULL UP TO 222K AND SEE SHEAR. - PICK UP 2' AND PUT 27 RT HAND TURNS. - SLACK OFF TO 97K, (15K SETTING DOWN ON RETAINER). 15:30 - 16:00 0.50 ZONISO P DECOMP RIG UP CEMENTING LINES TO DRILL PIPE. 16:00 - 16:30 0.50 ZONISO P DECOMP ESTABLISH INJECTION RATES. , - PUMP INTO FORMATION, OBSERVING NO RETURNS. - 1 BPM / 130 PSI, 2 BPM / 400 PSI, 3 BPM / 750 PSI, 4 BPM/ 1100 PSI. - SHUT DOWN PUMP. 16:30 - 18:00 1.50 ZONISO P DECOMP PRE JOB SAFETY MEETING WITH ALL HANDS. - DISCUSS CEMENTING JOB, MAX PRESSURES. - EMPHASIS ON GOOD COMMUNICATION. 18:00 - 18:35 0.58 ZONISO P DECOMP SLB PUMP 5 BBLS WATER. - PT LINES TO 300/4000 PSI 5 MIN EACH. - BLEED OFF PRESSURE. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP 10 Page 70 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:35 - 19:20 0.75 ZONISO P DECOMP - 18:40 SLB BATCH UP 34 BBLS 15.8 PPG CLASS G PUMPABLE PLUG CEMENT. SLB SET PUMP TRIP AT 2500 PSI. - SLB PUMP 34 BBLS CEMENT 5 BPM © 1400 PSI. - DECREASING TO 3 BPM © 650 PSI. - FOLLOWED WITH 5 BBLS WATER PUMPING (7 4.8 BPM @ 1250 PSI. - ISOLATE CEMENTERS, LINE UP WITH RIG PUMP. - CEMENTERS CLEAR LINES BUT STAY RIGGED UP. - PUMP 73 BBLS 11.5 BRINE PUMPING @ 4 BPM, 1100 PSI INCREASING TO 1460 PSI. - WITH CEMENT AT RETAINER, SQUEEZE 24 BRI S RFl OW RETAINER FROM 10.400' - PUMPING 4 BPM 1600 PSI, PRESSURE INCREASING TO 1980 PSI PUMPING 3 SPM. - SHUT DOWN PUMP. 19:20 - 21:00 1.67 ZONISO P DECOMP NOTE 1600 PSI DRILL PIPE PRESSURE. - P/U 5' UNSTING FROM RETAINER, DP PRESSURE BLED TO 0 PSI. - R/D CIRCULATING LINE AND HEAD PIN. - L/D 10' PUP, POH 4 STDS. - M/U 10' PUP WITH HEAD PIN AND CIRCULATING HOSE. - PULL SINGLE TO 9990' - CLOSE ANNULAR, LINE UP AND REVERSE CIRCULATE. - REV CIRC PUMPING 5 BPM @ 1070 PSI. CIRC 1.5 DP VOLUMES. - DUMP 33 BBLS CONTAMINATED FLUID - TOP OF CEMENT AT 10,131', CIP 9 19:40 21:00 - 22:00 1.00 ZONISO P DECOMP R/D SLB CEMENTERS AND RELEASE. - CHECK FOR PRESSURE. OPEN ANNULAR. - CHECK FOR FLOW- STATIC - UD 10' PUP AND SINGLE. - BLOW DOWN LINES. 22:00 - 23:00 1.00 ZONISO P DECOMP PJSM, REVIEW SOP FOR CUT AND SLIP DRLG LINE AND LOADING PIPE SHED. - CUT AND SLIP 61' OF DRLG LINE. - CONTINUE TO MONITOR WELL- STATIC. - LOAD 2 7/8" TBG INTO PIPE SHED. - NUMBER, STRAP AND DRIFT TBG. 23:00 - 00:00 1.00 ZONISO P DECOMP CONTINUE TO MONITOR WELL WHILE LOADING PIPE SHED WITH 2 7/8" TBG. - NUMBER, STRAP AND DRIFT TBG. - WELL IS STATIC. - LOSSES TO WELL IN THE LAST 12 HRS= 44 BBLS - 90 BBLS BULLHEADED 5/15/2012 00:00 - 08:00 8.00 ZONISO P DECOMP CONTINUE TO MONITOR WELL WHILE LOADING PIPE SHED WITH 2 7/8" TBG. - NUMBER, STRAP AND DRIFT TBG. - CLEAN RIG FLOOR. 08:00 - 08:30 0.50 ZONISO P DECOMP PRE JOB SAFETY MEETING ON LAYING DOWN DP. - EMPHASIS ON HAND PLACEMENT, COMMUNICATION. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 71 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table ©41.80ft (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 ZONISO P DECOMP POOH & LAY DOWN 4" DP. - CONTINUOUS HOLE FILL, NO FLUID LOSS OR GAIN. 12:00 - 12:30 0.50 ZONISO P DECOMP SERVICE AND MAINTAIN RIG. 12:30 - 13:00 0.50 ZONISO P DECOMP PRE JOB MEETING ON LAYING DOWN DP. - EMPHASIS ON GOOD COMMUNICATION TECHNIQUES. - AWARENESS ON SKATE OPERATION AND POTENTIAL DROPPED OBJECTS. 13:00 - 20:00 7.00 ZONISO P DECOMP CONTINUE TO POOH & LD /DP. - CONTINUOUS HOLE FILL W/ POOH. - NO LOSSES OR GAINS DURING OPERATION. - UD HALLIBURTON CEMENT RETAINER RUNNING TOOL - 1800 FIRS, MATT HERRERA OF AOGCC WAIVED STATES RIGHT TO WITNESS BARRIER TEST 20:00 - 21:00 1.00 ZONISO P DECOMP M/U WEAR RING RUNNING TOOL - BACK OUT LOCK DOWN SCREWS - PULL WEAR RING AND LAY DOWN SAME - CLEAR CLEAN RIG FLOOR 21:00 - 23:00 2.00 ZONISO P DECOMP PJSM ON TESTING DOWN HOLE BARRIER -r} - R/U TEST EQUIPMENT Pitt - PRESSURE TEST = DOWN HOLE BARRIER - 1500 PSI, 30 MINUTES, CHARTED - NOTIFY WTL FOR AUTHORIZATION TO PROCEED - PERMISSION GRANTED - R/D TEST EQUIPMENT 23:00 - 00:00 1.00 ZONISO P DECOMP PJSM ON RIG UP AND RUN 2 7/8 TUBING - R/U CASING TONGS - BEGIN RUNNING 2 7/8, 6.5 #, L -80, 8 RD, TUBING TO 191' 5/16/2012 00:00 - 12:00 12.00 ZONISO P DECOMP PJSM ON RUNNING 2 7/8 EUE 8RD KII I STRING - SERVICE RIG FLOOR AND EQUIPMENT - RIH WITH 2 7/8, 6.5 #, L -80, 8 RD, TUBING F/191' T/9336' - DISPLACEMENT IS CORRECT, WELL IS NOT TAKING OR GIVING BACK FLUID - LOSSES TO WELL IN 12 HRS = 0 BBLS. 85K UP WT, 65K DOWN WT. 12:00 - 12:30 0.50 ZONISO P DECOMP SERVICE & INSPECT RIG COMPONENTS. 12:30 - 13:00 0.50 ZONISO P DECOMP PRE JOB SAFETY MEETING, PICKING UP TUBULARS. - EMPHASIS ON HAND PLACEMENT AND GOOD COMMUNICATION. - REVIEWED PROCEDURE AND PROPER TORQUE. 13:00 - 15:00 2.00 ZONISO P DECOMP CONTINUE IN HOLE W/ 2 7/8" EUE 8 RND KILL STRING. - 319 JTS TOTAL. BREAK CIRCULATION, 3 BPM / 725 PSI. - 90K UP, 68K DOWN WT. BOTTOM OF SHOE @ 10,031. Printed 5/29/2012 10:59:05AM North America - ALASKA - BP Page 72 of 72 Operation Summary Report Common Well Name: MPL -06 AFE No Event Type: WORKOVER (WO) Start Date: 1/7/2012 End Date: X4- 00VHW -E (4,400,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/7/1990 12:00:OOAM Rig Release: 3/19/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @41.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 17:00 2.00 ZONISO P DECOMP PJSM. MAKE UP HANGER AND PUPS. - INSTALL TWO WAY CHECK VALVE, M/U LANDING JT. - LAND HANGER AND RUN IN LOCK DOWN SCREWS - UD LANDING JT 17:00 - 19:00 2.00 ZONISO P DECOMP R/U TEST EQUIPMENT - TEST TWC FROM BELOW - 250 PSI LOW, 1000 PSI HIGH, 30 MINUTES CHARTED - R/D TEST EQUIP 19:00 - 20:00 1.00 ZONISO P DECOMP BLOW DOWN CHOKE, KILL AND MUD LINES - BLOW DOWN CHOKE MANIFOLD 20:00 - 22:30 2.50 ZONISO P DECOMP PJSM, REMOVE RAMS FROM STACK - REMOVE UPPER PIPE RAMS AND BLIND RAMS FROM BOP STACK - CLEAN AND EMPTY PITS 22:30 - 00:00 1.50 ZONISO P DECOMP PJSM, N/D STACK - REMOVE KOOMEY LINES FROM BOP - N/D BOP STACK - R/D MUD MANIFOLD 5/17/2012 00:00 - 03:00 3.00 ZONISO P DECOMP PJSM, N/U CAMERON ADAPTER FLANGE - TEST PACK OFF / SEALS TO 5000 PSI, 30 MINUTES, PER CAMERON - TEST TREE AND ADAPTER WITH DIESEL - 250 PSI LOW, 5000 PSI HIGH, 5 MINUTES, CHARTED 03:00 - 04:00 1.00 ZONISO P DECOMP N/U CAMERON DRY HOLE TREE - FILL WITH DIESEL 04:00 - 05:00 1.00 ZONISO P DECOMP TEST TREE - R/U TEST EQUIP - TEST TREE TO 250 PSI LOW, 5000 PSI HIGH, 5 MINUTES, CHARTED - R/D TEST EQUIP 05:00 - 06:00 1.00 ZONISO P DECOMP SECURE TREE - INSTALL MANIFOLD AND GAGES ON OA, IA, AND TREE CAP - CLOSE ALL VALVES - RELEASE RIG AT 06:00 Printed 5/29/2012 10:59:04AM Tree:WKM 4 1/16" M P L -06 Orig elev. = 55.0' (Pool) Wellhead:11" 5M Ong MBE elev. = 21.0' (Pool; 4.5'CIWBPVprofile DF to GL = 34' Note: OA appears to have an open shoe. 0.2 bpm @ 2000 psi. 20" Conductor Casing 112' Halliburton Hos stage 1885' o cementer 9 -5/8" 36 #, J -55 BTC csg 6314' down squeezed 8/25/91 9 KOP © 1000' (1 �' Max Hole Angle: 56.60° © 4457' S 9, Hole angle through perfs. = 55 deg. L7L,1 / RA tag at 10303' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7 ", 26 #, L -80 Buttress casing (drift ID = 6.151 ", cap. = .0383 bpf) Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I -Prop. 28,603# 12/18 I -Prop. 2 7/8" 6.5 # L - 80 8rd EUE Tbg 10031' screened out w/ 14,082# 12/18 I -Prop. w/ Mule Shoe above perfs. Perforation Summary: o Ref Iog:SWS CCL log dated 3 May 90 6'3 v • Size SPF Interval (TVD) Cast iron cement retainer w/ 24 bbls cement below & 10400' 4.5" 5 10566'- 10593' 7002' -7017' 10 bbls cement above 4.5" 5 10632'- 10662' 7042' -7058' 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' 66 '- 4.5" 5 10800'- 10821' 7139' -7152' Z� �' • 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900'- 10904' 7200' -7202' ` 7" Float collar 10985' Mid -pert TVD - 7102' 7" csg. shoe 11068' Mid -perf MU - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L -06 9/24/93 RWO Rig 4 7/16/98 RWO Nabors 4 -ES 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES API NO: 50 - 029 - 22003 04/10/01 B. Hasebe ESP RWO Vabors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme 0/0 ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) 05/21/12 B. Bixby Pull ESP set CIBP and run work string • r ; L e Ft tiaimn � SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W, 7th AVENUE, SUITE 100 CONSERVATION COM1IHSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader . J D MAY 2 2 2012 BP Exploration (Alaska), Inc. P.O. Box 196612 I010-0 Anchorage, AK 99519 -6612 Re: Milne Point Field, Kuparuk River Oil Pool, MPL -06 Sundry Number: 312 -181 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy Foerster Chair 5F DATED this 2 l day of May, 2012. Encl. , STATE OF ALASKA �; , t -1 ' EC E I Y E D ALA. OIL AND GAS CONSERVATION COM SION MAY 1 4 201 APPLICATION FOR SUNDRY APPROVAL i' S 1 z 1 1 Z 20 AAC 25.280 AOGCC 1. Type of Request tv io' ❑ Abandon S' ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program pr Suspend • ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension r erations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 190 - 010 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22003 - 00 - 00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPL-06 Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): e, . (, ADL 047434 ' Milne Point Unit / Kuparuk River aads - C. f(. ft., 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11091' ' 7313' 10983' 7248' 10496' (Bull Plug) None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 115' 115' 1740 750 Surface 6279' 9 -5/8" 6314' 4590' 3520 2020 Intermediate Production 11033' 7" 11068' 7299' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10566' - 10904' 7001' - 7200' 2 -7/8 ", 6.5# L -80 10497' Packers and SSSV Type: 7 ", 26#, Baker BOT Cup Packer Assembly Packers and SSSV 10447' / 6934' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory El Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 11, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: 5/11/2012 `' ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: Guy Schwartz ❑WAG ❑ SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Name r. id Ree Title Engineering Team Leader Prepared By Name/Number: 614/2 Signature Phone 564 - 5743 Date 0/a Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �„'' Z 13K OP Number: J U [ Plug Integrity l.� BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: ° 3go ® &c, g ni ik. Alb &( �.. tiSP G ...ler a-S ;/.1.. ef i Gs� Subsequent Form Required: C �� 7 APPROVED MM S Z.'— / 2-- Approved By: COMMIS SIONER THE CO Date S _ F orm 10- 4BlltitatcM W1' 1p 2 2 9ft Submit In Duplicate I'V �C�LJMJ ��, III��"'IIIHT /w W s .��., L 0 R 0 N A .. ��,� 1 _ .t • • by 0 MPL -06 Expense Rig Workover Well Objective: Shut down operation on Well MPL -06 Shutdown Justification: Doyon 16 had a failure of the BOP remote activation system on 5/10/2012. BP requests approval to shutdown operations on MPL -06 while an investigation is conducted and a long term plan for the well is developed. Prior to shutdown of operations a cement retainer will be set. Cement will be pumped below the retainer and 100' above. Cementing is a safety precaution due to the high pressure gas in the / reservoir. Not long ago the well had 2500 psi on surface and we don't want to see that again while future options are being evaluated. Additionally, 11.5 KWF will be left in the well. This will keep the well in a safe condition while the reservoir team figures out what the long term plan is. The cement and retainer can be milled so wellbore utility will not be lost. A -10,000' kill string will be ran before setting a TWC a surface. This would meet BP's two barrier policy. There is no immediate plan of action for future work on MPL -06. MASP: 3,433 psi Well Type: Producer Pad Engineer: Chris Stone 564 -5518 Intervention Engineer: Sean McLaughlin 564 -4387 • • bp • BP Exploration Alaska Inc. MPL -06 Suspend Operations Recommend Sean McLaughlin Date: RWO Engineer Agree Dave Reem Date: ETL Agree James Willingham Date: WTL Agree Steve Rossberg Date: D &C Operations Manager Decide Carl Mountford Date: D &C Engineering Manager • • MPL -06 Suspension of Workover operations Scope of operations: o Complete accumulator repair o Finish decomplete of tubing, ESP, cup packers, and screens o Testing BOPE o Secure the well for suspension Reference Documents: • ETP 10 -60 - Zonal isolation (Section 6.1 - Principles of Suspension) • AOGCC 20 AAC 25.110 (Suspended Wells) Verify Start - up Checklist: V BP Alaska has verbal approval from the commission to proceed with workover suspension operations on MPL -06. zr A Sundry request for shut down of operations has been filed with the state. 5K Primary and secondary well barriers shall be installed in the wellbore to provide two temporary barriers Issues and Potential Hazards: > Abnormally pressured well - Currently 11.5 ppg KWF in the hole with a static loss rate of 6 -8 bph. Suspension Plan: 1. Continue to keep hole full via continuous circulation. ➢ Monitor T /I /O pressures every hour - > Monitor loss rate > Maintain a minimum of 700 bbls of 11.5 ppg brine on surface 2. Repair accumulator system to full working capacity. Approval to proceed will be given by Willingham. ➢ Ensure 24hr notification has been given to the state for full BOPE test. _ Dirti of f _p - � 3. Shut down pump and check for pressure and flow. its 4. Open upper VBR's 5. Pull remaining ESP completion out of hole while maintaining continuous hole fill. °' > Plan for non - shearable equipment across the stack. The pump, packer, and screen assembly is 140' long. > If latched on to pump and a kick occurs plan to pull pump and cup packer (93.26') completely out of hole. There is a 2 -7/8" EUE pup below the cup packer. The 4 -1/2" screens will be across the stack. Proceed with pump lay down, stabbing safety joint, or operating blind shears as the situation warrants. Drill these scenarios and work out the " bugs prior to laying down the pump assembly. 6. Run test plug in tubing spool. 7. Test BOPE per program. Test VBR's with both 2 -7/8" and 4" test joints. 8. PU a 7" HES Cast Iron Mechanical Set Cement Retainer and run in on 4" drill pipe. 9. Set the Retainer at -10,400' per HES instructions. > Target set depth is 40' above the cup packer depth and 166' above top perforation. ➢ The shear release on the retainer is 30klbs. Well: MPL -06 Version: draft 2 Suspend Well • • ➢ Document the following barrier information in Openwells • Manufacture, type, and model number • Tool configuration • Serial number 10. The WSL needs to verify the SLB field test blend has the following parameters before pumping cement: ➢ Fluid Loss: <250mL ➢ Free Fluid: trace or OmL ➢ Thickening Time: 3:30 - 6 hrs at 180 degF ➢ 1,000 -psi compressive strength: 15hrs max 11. RU Schlumberger cementers. PT cement lines to 4,000psi. Pump 34 bbls 15.8ppg Class G ' cement at -6bpm. Maximum pump pressure will be 2000 psi. Cement volume = Volume below the retainer (22 bbls), 8 bbls excess, and 100' above (4 bbls). ➢ The depth of fill is unknown. 12. Cement as follows: ➢ 5 -bbls seawater to PT ➢ 34 -bbls 15.8 -ppg Class "G" plug cement ➢ Displace with 5 bbl seawater followed by 11.5 ppg brine / ➢ Utilize the rig pumps for displacement ➢ Pump 30 bbls of cement below the retainer, unsting from the retainer and pump 4 bbls of cement above. ➢ Record cement -in -place time in openwells. 13. Pull five stands and circulate a bottoms up. Pull out of hole laying down drill pipe. 14. Close blind /shear rams. Test lower barrier to 1,500 psi for 30 minutes. Verify pressure test with the WTL before proceeding. Notify inspectors for witness for this bottom plug pressure test. ➢ Use the "BPXA STP Wellbore Testing Criteria Calculator". The latest version is embedded in the Tubular Pressure Testing RP. o WSL and Toolpusher to sign. Attach pressure chart and calculator to OpenWells. 15. Verify no wellbore pressure and open B/S rams 16. Run 2 -7/8" killstring with mule shoe to 10,200'. '/ 17. Record circulating rate and pressures, as well as PU /SO weights before landing hanger, on daily operations report. Land Hanger. 18. Run in lock down screws and test pack off to 5000 psi. 19. Set TWC and test from below to 250 psi low / 1000 psi high for 30 -min. 20. ND BOPE and NU adapter flange, tubing head adapter, and tree. .i 21. Pressure test tubing head adapter and tree with diesel to 250 psi low / 5,000 psi high for 5 minutes. 22. Confirm MPU Wells Group assumes freeze protect responsibilities after the rig moves off. 23. Wait on investigation and /or orders. Well: MPL -06 Version: draft 3 Suspend Well Tree:WKM 2 9/16" Orig. elev. = 55.0' (Pool) Wellheadl 1 5M W M P L -06 Orig. elev. = 21.0' (Pool; 2.5" CIW BPV profile DF to GL = 34' J L. 20" Conductor Casing 112' SLB 2 7/8" x 1" KBMM GLM 139' Halliburton Hos stage 1885' 0 cementer 9 -5/8" 36 #, J -55 BTC csg 6314' down squeezed 8/25/91 KOP @ 1000' SLB 2 7/8" x 1" KBMM GLM 10205' Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. 2 -7/8" HES XN nipple 10348' ( 2.205" No -Go ID ) RA tag at 10303' WeIILift Discharge Gauge 10361' Centrilift Pumps 160P11 & 10365' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. 18P75 Coated, PMSXD /SXD 1:1 ( drift ID = 2.347 ", cap. = 0.00592 bpf) Gas Separator GasMaster 10399' ir 7 ", 26 #, L -80 Buttress casing . 's Coated ID (drift ID = 6.151 ", cap. = .0383 bpf) Intake TVD 6906' o o.o ]9 Centrilift tandem seal section GSB3DB UT /LT SB /SB PFSA 10404' ' 3entrilift 562 series Motor (rerated) Stimulation Summary: 195 HP KMH -A 2177 V/ 53 A 10418' 6/15/91 Frac, All zones 169,139# of 1 16/20 I -Prop. 28,603# 12/18 I -Prop. r We I ILift MGU Gauge w/ 6 Fin screened out w/ 14,082# 12/18 I -Prop. Centralizer 10438' above perfs. Gauge TVD 6928' is BOT Safety Shear Sub 10441' Perforation Summary: Ref Iog:SWS CCL log dated 3 May 90 1 1 2 7/8" Ported Tbg ,1t. 10445' BOT Cup Packer )( 10447' Size SPF Interval (TVD) BOT Excluder Screen w/ 10456 -97' 4.5" 5 10566'- 10593' 7002' -7017' bull plug 4.5" 5 10632' - 10662' 7042' -7058' _ 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' 4.5" 5 10800'- 10821' 7139' -7152' 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900' - 10904' 7200' -7202' 7" Float collar 10985' Mid -perf TVD - 7102' 7" csg. shoe 11068' Mid -perf MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L -06 . 9/24/93 RWO Rig 4 7/16/98 RWO Nabors 4 -ES API NO: 50- 029 -22003 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES 04/10/01 B. Hasebe ESP RWO Vabors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme C/O ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) Tree:WKM 2 9/16" M P L -0 Origai elev. = 55.0' (Pool) Wellheadi 1" 5M WI Orig. elev. = 21.0' (Pool) 2.5" CIW BPV profile DF to GL = 34' J Note: OA appears to have Suspend well an open shoe. 0.2 bpm @ 2000 psi. 20" Conductor Casing 112' Halliburton Hos stage 1885' cementer 9 -5/8" 36 #, J -55 BTC csg 6314' down squeezed 8/25/91 KOP @ 1000` Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. RA tag at 10303' X Kill String - 2 -7/8" 6.5 ppf, L -80 8rd 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7 ", 26 #, L -80 Buttress casing (drift ID = 6.151 ", cap. = .0383 bpf) Stimulation Summary: 6/15/91 Frac. All zones 169,139# of 16/20 I -Prop. 28,603# 12/18 I -Prop. screened out w/ 14,082# 12/18 I -Prop. above perfs. ___- -- EOT @10,200' Perforation Summary: Ref Iog:SWS CCL log dated 3 May 90 - Estimated TOC @ 10,300' Size SPF Interval (TVD) 7" HES Cement Retainer @ 10,400' 4.5" 5 10566'- 10593' 7002'- 7017' 4.5" 5 10632'- 10662' 7042' -7058' 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' bbl cement pumped below 4.5" 5 10800'- 10821' 7139' -7152' retainer 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900'- 10904' 7200' -7202' 7" Float collar 10985' Mid -pert TVD - 7102' 7" csg. shoe 11068' Mid -pert MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L -06 9/24/93 2WO Rig 4 7/16/98 FWO Nabors 4 -ES 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES API NO: 50- 029 -22003 04/10/01 B. Hasebe ESP RWO \labors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme C/0 ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, May 11, 2012 3:29 PM To: 'McLaughlin, Sean M' Cc: Hubble, Terrie L Subject: RE: MPL -06 - shut down of operations /Suspend well. Sean, You have verbal approval to proceed with the suspension of MPL -06 as outlined in your attached procedure. One change to the procedure is needed: on step 14 increase test pressure to 1500 psi and chart for 30 min. Also notify inspectors for witness for this bottom plug pressure test. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Friday, May 11, 2012 3:05 PM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L Subject: RE: MPL -06 - shut down of operations Guy, As requested in the plan to shutdown operations please provide us with verbal approval. Pumping cement below and 100' above the retainer is a safety precaution due to the high pressure gas in the reservoir. Not long ago the well had 2500 psi on surface and we don't want to see that again. Additionally, we will leave the 11.5 KWF in the well. This will keep well in a safe state while the reservoir team figures out what the long term plan is. The cement and retainer can be milled so we are not giving up the wellbore utility. The original schematic is attached. Regards, sean From: McLaughlin, Sean M Sent: Friday, May 11, 2012 2:48 PM To: 'Schwartz, Guy L (DOA)' Cc: Hubble, Terrie L Subject: RE: MPL -06 - shut down of operations sorry just realized i sent canvas schematic rather than jpeg. From: McLaughlin, Sean M Sent: Friday, May 11, 2012 2:41 PM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L Subject: RE: MPL -06 - shut down of operations Guy, 5/16/2012 Page 2 of 2 • • Attached is a draft procedure and schematic. sean From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, May 11, 2012 1:14 PM To: McLaughlin, Sean M Cc: Hubble, Terrie L Subject: RE: MPL -06 - shut down of operations Can you send me a well sketch with details? Did you pull out the rest of the ESP completion? Guy Schwartz Senior Petroleum Engineer AOGCC 793 - 1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Friday, May 11, 2012 11:26 AM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L Subject: MPL -06 - shut down of operations Guy, As you have heard Doyon 16 had a failure of the accumulator system last night. BP would like to shut down operations on MPL -06 while an investigation is conducted. The plan will be to set a cement retainer and squeeze cmt below and lay 100' of cement above. We would then run a 4000' kill string and set a TWC. This would meet BP's two barrier policy. There is no immediate plan of action for future work on MPL -06. The wellbore will be secure but remain capable of future wellbore utility. A 10 -403, schematic, and operation plan will be sent over. I wanted to get you in the loop sooner rather than later. Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 5/16/2012 MPG( L-0 ca W m P icio --U I o Regg, James B (DOA) From: Burnett, Richard D [burnr8 @BP.com] / Sent: Friday, May 11, 2012 11:30 AM I �� To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Miller, Mike E Cc: Willingham, James M; Daniel, Ryan; Kilfoyle, Jeffery A; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Schultz, Mikel; Bill, Michael L (ASRC); Mountford, Carl F; Bjork, David; Reem, David C; AK, D &C Rig 16 Well Site Leader; Yeager, Kevin E; Haynes, Paul H (ORBIS) Subject: Doyon 16 BOPE usage report Attachments: MPL -06 BOPE Usage Report to AOGCC 5- 11- 2012.pdf Jim - Attached please find the BOPE usage form for the recent BOPE closure on MPL -06. Please let me know if I can answer any questions or if you need any further clarification. Thanks, Rich Rich Burnett Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) JUN 1 201 +1 (907) 748 -5821 (Cell Phone) Harmony 2157 Alternate: Greg Sarber 1 • • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Rich Burnett Wellsite Leader Name: Paul Haynes Contact Number: 659 -5329 Contact Number: 659 -4177 Traction Number: Pending Well Location /Name & Rig Name: Milne Pt L -06 Doyon Rig #16 Permit To Drill (PTD) Number: 190 -010X Date and Time of Incident: 05 -10 -2012 15:00 hrs Original Scope of Work: While tripping 2 7/8" EUE 8 rnd tubing out of the hole, packer gas broke out at the bell nipple and the driller got a 25% LEL read out on a hand held gas monitor. The well was Shut in using the annularpreventer. There was no flow at the time of shut in, and after shutting in there was no pressure on the tubing, I/A or O /A. There was no pit gain. The well continued to take fluid at 6 — 8 bph. Operational Description Leading up to Well Control Event: POOH w/ ESP completion string. BOPE Used and Reason: To shut in well in order to circulate out packer gas. The annular preventer was initially used to secure the well. A hydraulic oil leak developed in the BOPE accumulator system when the annular was closed. The upper pipe rams were closed to better enable the rig team to perform repairs on the accumulator hydraulic system. The rig team continued to circulate brine into the well through the tubing to maintain hole fill. Is a BOPE Test Required after use ( Yes / No): Yes If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: After making necessary repairs on the accumulator system a full BOPE test will be done and witnessed by the AOGCC State Representative. Additional Comments: AOGCC State Representative has been notified of impending test. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aogcc.brudhoe.bavalaska.Qov Email CC List Well Integrity Team Leader: Ryan Daniel HSE Advisor: Jeff Kilfoyle Engineering Team Leader: Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager: Steve Rossberg Wells Intervention Manager: Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC Rev 1 September 1, 2010 UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained Casing Pressure on the IA Page 1 of'l • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 06, 2011 12:19 PM To: Regg, James B (DOA) Subject: FW: UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained Casing Pressure on the IA Sorry, forgot to include you. From: Maunder, Thomas E (DOA) Sent: Tuesday, September 06, 2011 12:18 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained Casing Pressure on the IA Jerry, Our opinion is that this well should not be included on the Monthly Injector Report. As the title says it is for injectors and MPL -06 is a producer. I can appreciate with the ESP failure that the IA pressure winds up exceeding the 2000 psi and you are obligated by CO 496 to provide notice to the Commission and you have done that. The next step to meet the Commission's requirements would be if the IA pressure exceeds 45% of burst (.45 x 7280 = 3276 psi) which is not likely. Are there any other producers on the Monthly Report? Neither Jim nor could remember having seen a similar message for producers. Call or message Tom Maunder, PE with any questions. `9 ;. ,. s 4, � i i `1 AOGCC m: AK, D &C Well Integrity Coordinator [ mailto :AKDCWelllntegrityCoordinator @bp.com] Se • Friday, September 02, 2011 3:20 PM To: Re. 6 James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OP, PU OSM; AK, OPS MPU Fiel• •s TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations T- .m Lead; AK, D &C Well Services Ope : ions Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU intro! Room; Stone, Christopher Cc: AK, D &C W- Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: UNDER LUATION: MPL -06 (PTD #1900100) Sustained Cas' • • Pressure on the IA « P Producer MPL -06 (PTD #1900100) TIO Plot.doc» «MPL -06 (PTD 19s 100) wellbore schematic.pdf» or\t" 10/11/2011 UNDER EVALUATION: MPL -06 (P, #1900100) Sustained Casing Pressuri the IA Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] 4/4 Sent: Friday, September 02, 2011 3:20 PM ' l To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained Casing Pressure on the IA Attachments: ESP Producer MPL -06 (PTD #1900100) TIO Plot.doc; MPL -06 (PTD 1900100) wellbore schematic.pdf All, 7 ESP producer MPL -06 (PTD #1900100) has had a down hole motor failure. Since the ESP stopped operating, the IA pressure exceeded MOASP • • • with tubin. /IA/OA •ressures of SSV /2060/20. The current plan forward is to shut -in the offset injector (MPC -08) to reduce pressure support being directed to MPL -06. The well is scheduled for a rig workover to repair the ESP in Q4 of 2011. The well will be reclassified as Under Evaluation. Once the rig begins working over the ESP, the well will be reclassified as appropriate and notification sent out. The well will additionally be added to the Monthly AOGCC Injector report for pressure monitoring. Plan forward: 1. WIE: Monitor TIO plot for IA pressure stabilization 2. Rig workover to repair ESPY w fit", ` Z (]`(9 A schematic and TIO plot are enclosed for reference. «ESP Producer MPL -06 (PTD #1900100) TIO Plot.doc» «MPL -06 (PTD 1900100) wellbore schematic.pdf» Please call if you have questions or concerns. Thank you, From: AK, D &C Well Integrity Coordinator Sent: Sunday, July 31, 2011 9:12 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Chebul, Josh M Subject: OPERABLE: MPL -06 (PTD #1900100) Sustained Casing Pressure Mitigated All, ESP producer MPL -06 (PTD #1900100) has been brought back online on 07/29/2011 drawing the IA pressure back below MOASP after an acid treatment. The wellhead pressures recorded on 07/30/2011 were tubing /IA /OA equal to 282/320/260 psi. The well is reclassified as Operable. A TIO plot has been included for reference. Please call if you have any questions. 9/6/2011 UNDER EVALUATION: MPL -06 (P, #1900100) Sustained Casing Pressurep the IA Page 2 of 2 Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 09, 2011 8:07 PM To: 'Maunder, Thomas E (DOAy; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); AK, D &C Well Integrity Coordinator; Chebul, Josh M Subject: UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained casing pressure on the IA All, Well MPL -06 (PTD #1900100) is an ESP producer that had been shut -in on 06/16/11 due to scale build -up in the tubing. On 07/07/11, the well was reported to have sustained casing pressure on the IA. The wellhead pressures were SSV /2020/0 psi. The current plan forward is to shut -in the offset injector (MPC -08) to reduce pressure support being directed to MPL -06. In addition, an acid treatment will be pumped down the tubing in attempt to dissolve the scale and bring the well back on -line. The well has been reclassified as Under Evaluation for further diagnostics diagnostics. A TIO plot and wellbore schematic have been included for reference. Thank you, Torin Roschinger (filling in for Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 9/6/2011 MPU L -06 PTD #1900100 9/2/2011 TIO Pressures Plot Well: MPL -06 4,000 S 3,000 - — 0— Tbg —a— IA 2,000 —A— OA OOA — r— 000A On 1,000 - 4 .1.411.1111 _401111144.4A • +♦ * t rr-'- ra- *- �.... ..rr -4..i. �_ - -4'-arar4a -ra 06/04/11 06/18/11 07102111 07116/11 07/30/11 08!13111 08227111 Tree:WKM 2 9/16" 5M ID DFMilk � Orig. = 55.0' (Pool) Wellhead:11" 5M WKM MPL-06 L -06 Orig. GL ev. = 21.0' (Pool; 2.5" CIW BPV profile _ DF to GL = 34' ' ,' [ 20" Conductor Casing 112' SLB 2 7/8" x 1" KBMM GLM 139' Halliburton Hos stage 1885' 0 cementer 9 -5/8" 36 #, J -55 BTC csg 6314' A ■ down squeezed 8/25/91 KOP @ 1000' SLB 2 7/8" x 1" KBMM GLM 10205' Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. ta 2 -7/8" HES XN nipple 10348' ( 2.205" No -Go ID ) RA tag at 10303' WeIILift Discharge Gauge � � 9 g 10361' ` Centrilift Pumps 160P11 & 10365' 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. 18P75 Coated, PMSXD/SXD 1:1 ( drift ID = 2.347 ", cap. = 0.00592 bpf) Gas Separator GasMaster 10399' 7 ", 26 #, L -80 Buttress casing , • ,' Coated ID Intake TVD 6906' (drift ID = 6.151 ", cap. = .0383 bpf) irNu JA kSyP 1 esor ,iw at" . Centrilift tandem seal section GSB3DB UT /LT SB /SB PFSA 10404' " r, entrilift 562 series Motor (rerated) Stimulation Summary: 95 HP KMH -A 2177 V / 53 A 10418' 6/15/91 Frac, All zones 169,139# of , 16/20 I -Prop, 28,603# 12/18 I Prop. ` _`s WeIILIft MGU Gauge w/ 6 Fin 10438' screened out w/ 14,082# 12/18 I -Prop. Centralizer above perfs. Gauge TVD 6928' BOT Safety Shear Sub 10441' Perforation Summary: Ref log:SWS CCL log dated 3 May 90 aril 2 7/8" Ported Tbg Jt. 10445' BOT Cup Packer 10447' MEI Size SPF Interval (TVD) BOT Excluder Screen w/ 10456 -97' 4.5" 5 10566'- 10593' 7002' -7017' bull plug 4.5" 5 10632'- 10662' 7042' -7058' e-- 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' 4.5" 5 10800'- 10821' 7139' -7152' 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900'- 10904' 7200' -7202' 7" Float collar 10985' Mid -perf TVD - 7102' 7" csg. shoe 11068' Mid -perf MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L -06 9/24/93 RWO Riq 4 7/16/98 FWO Nabors 4 -ES 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES API NO: 50 -029 -22003 04/10/01 B. Hasebe ESP RWO \labors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme C/0 ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) - STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 151 / ti) Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ " 190 -0100 3. Address: P.O. Box 196612 Stratigraphic Service p 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22003 -00 -00 8. Property Designation (Lease Number) : ,,,. 9. Well Name and Number: ADLO- 047434 a MPL -06 10. Field /Pool(s): .. MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 11091 feet Plugs (measured) None feet true vertical 7313 feet Junk (measured) None feet Effective Depth measured 10983 feet Packer (measured) 10447 feet true vertical 7248 feet (true vertical) 6934 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 48# H-40 35 - 115 35 - 115 1740 750 Surface 6280' 9- 5/8 "36 #J -55 34 - 6314 34 - 4590 3520 2020 Production 11035' 7" 26# L -80 33 - 11068 33 - 7299 7240 5410 Production Liner Liner r sL �} Perforation depth: Measured depth: SEE ATTACHED - AU t? �d - - True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 32 - 10448 32 - 6934 Packers and SSSV (type, measured and true vertical depth) 7" BOT Packer 10447 6934 RECE 0 , 12. Stimulation or cement squeeze summary: 'SiQn Intervals treated (measured): pp�� b �• Treatment descriptions including volumes used and final pressure: K`�+�{ rqC� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 35 149 381 263 Subsequent to operation: 32 133 366 276 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El i Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — isi Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSPO 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: NA Contact Joe Lastufka Printed Na = Lastufk AK, Title Petrotechnical Data Technologist dt°1**)? Signatu 1 L Phone 564 -4091 Date 8/22/2011 ‘' X81. AMA AUG 2 4 ZQ11 Form 10 -404 Revised 10/2010 Submit Original Only MPL-06 190 -010 ' PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPL-06 11/27/90 PER 10,566. 10,593. 7,000.98 7,016.32 MPL -06 11/27/90 PER 10,632. 10,662. 7,038.59 7,055.88 MPL-06 11/27/90 PER 10,678. 10,693. 7,065.15 7,073.88 MPL-06 11/27/90 PER 10,714. 10,724. 7,086.16 7,092.03 MPL -06 11/27/90 PER 10,800. 10,821. 7,137.15 7,149.76 MPL -06 11/27/90 PER 10,834. 10,878. 7,157.57 7,184.08 MPL-06 11/27/90 PER 10,900. 10,904. 7,197.37 7,199.79 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPL -06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/25/2011' RU to Tbg, PT surface equipment, Continued on 07 -26 -11 7/26/2011 iT /I /0= 2400/2360/0 Acid Treatment Pump into Tbq w/ 53 bbls diesel 3 bbls 60/40 to I prove injection. Pump 13 bbls acid, flush w/ 3 bbls 60/40. Displace w/ 42 bbls crude. FWHP= 2500/2500/20 DSO to flowback after 30 min soak. SV,WV,SSV shut MV,IA,OA Open 7/27/2011 TWO = 2100/2400/0. Tubing displacement post acid treatment. Pumped 50bbls crude down tubing. FWHP's = 2100/2400/0. Swab, SSV, Wing = shut. IA, OA, Master = open. Flowback hardline still rigged to well. FLUIDS PUMPED BBLS 53 DIESEL 92 CRUDE 6 60/40 METH 13 ACID 164 TOTAL Tree:WKM 2 9/16" 5M• Orig. Div. = 55.0' (Pool) Wellheadl 1" 5M WKM M P L -06 Orig. GL elev. = 21.0` (Pool: 2.5" CIW BPV profile DF to GL = 34' Al , 20" Conductor Casing 112' 4;1 SLB27 /8 "x1" KBMMGLM 139' Halliburton Hos stage 1885' 0 cementer 9 -5/8" 36 #, J -55 BTC csg 6314' down squeezed 8/25/91 KOP @ 1000` SLB27/8 "x1" KBMM GLM 10205' Max Hole Angle: 56.60° @ 4457' '` Hole angle through perfs. = 55 deg. 2 -7/8" HES XN nipple 10348' %' -% ( 2205" No -Go ID ) RA tag at 10303 ,, f WeIILift Discharge Gauge 10361' `' Centrilift Pumps 160P11 & 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. 18P75 Coated, PMSXD /SxD 1:1 10365' ( drift ID = 2.347 ", cap. = 0.00592 bpf) , .� _` Gas Separator GasMaster 10399' 7 ", 26 #, L -80 Buttress casing Coated ID (drift ID = 6.151 ", cap. = .0383 bpf) i r Intake TVD 6906' it`P Centrilift tandem seal section GSB3DB UT /LT SB /SB PFSA 10404' Centrilift 562 series Motor (rerated) Stimulation Summary: = 195 HP KMH -A 2177 V/ 53 A 10418' 6/15/91 Frac, All zones 169,139# of 16/20 I -Prop. 28,603# 12/18 I -Prop. WeIILift MGU Gauge w/ 6 Fin 10438' screened out w/ 14,082# 12/18 I -Prop. Centralizer above perfs. Gauge TVD 6928' BOT Safety Shear Sub 10441' Perforation Summary: Ref Iog:SWS CCL log dated 3 May 90 j 2 7/8" Ported Tbg Jt. 10445' Iii— . - BOT Cup Packer 10447' Size SPF Interval (TVD) BOT Excluder Screen w/ 10456 -97' 4.5" 5 10566'- 10593' 7002' -7017' bull plug 4.5" 5 10632'- 10662' 7042' -7058' _ 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' 4.5" 5 10800'- 10821' 7139' -7152' 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900'- 10904' 7200' -7202' 7" Float collar 10985' Mid -pert TVD - 7102' 7" csg. shoe 11068' Mid -pert MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L -06 9/24/93 2W0 Riq 4 7/16/98 FWO Nabors 4 -ES API NO: 50- 029 -22003 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES 04/10/01 B. Hasebe ESP RWO Nabors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme C/O ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) OPERABLE: MPL -06 (PTD #19001004ustained Casing Pressure Mitigated • Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] �,. $I,I Sent: Sunday, July 31, 2011 9:12 PM �( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Chebul, Josh M Subject: OPERABLE: MPL -06 (PTD #1900100) Sustained Casing Pressure Mitigated Attachments: MPL -06 (PTD #1900100) TIO Plot.doc All, ESP producer MPL -06 (PTD #1900100) has been brought back online on 07/29/2011 drawing the IA pressure back below MOASP after an acid treatment. The wellhead pressures recorded on 07/30/2011 were tubing /IA /OA equal to 282/320/260 psi. The well is reclassified as Operable. A TIO plot has been included for reference. «MPL -06 (PTD #1900100) TIO Plot.doc» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 3 01' From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 09, 2011 8:07 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike 3 (Swift); AK, D &C Well Integrity Coordinator; Chebul, Josh M Subject: UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained casing pressure on the IA All, Well MPL -06 (PTD #1900100) is an ESP producer that had been shut -in on 06/16/11 due to scale build- up in the tubing. On 07/07/11, the well was reported to have sustained casing pressure on the IA. The wellhead pressures were SSV /2020/0 psi. The current plan forward is to shut -in the offset injector (MPC- 08) to reduce pressure support being directed to MPL -06. In addition, an acid treatment will be pumped down the tubing in attempt to dissolve the scale and bring the well back on -line. The well has been reclassified as Under Evaluation for further diagnostics diagnostics. A TIO plot and wellbore schematic have been included for reference. Thank you, Torin Roschinger (filling in for Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 8/1/2011 MPU L -06 PTD #1900100 7/31/2011 TIO Pressures Plot Well: M PL-06 4,000 - - - • 3,000 - .\/ 2,000 - -&-- OA OOA -0- 000A i -On 1 1,000 - • 1 i t.11 . «ice •-•1W .j 1 j • - - * - - - - * -- - - - - * - -.-4, --.- -•* -• . - •a,• 05/07/11 05/21/11 06/04/11 06/18/11 07/02/11 07/16/11 07/30/11 1 i i G 1 1 UNDER EVALUATION: MPL -06 (PTo #1900100) Sustained casing pressure .the IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] --� Sent: Saturday, July 09, 2011 8:07 PM 1 7(t/ 1( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); AK, D &C Well Integrity Coordinator; Chebul, Josh M Subject: UNDER EVALUATION: MPL -06 (PTD #1900100) Sustained casing pressure on the IA Attachments: MPL -06 TIO Plot 07- 09- 11.doc; MPL- 06.pdf All, Well MPL -06 (PTD #1900100) is an ESP producer that had been shut -in on 06/16/11 due to scale build- up in the tubing. On 07/07/11, the well was reported to have sustained casing pressure on the IA. The wellhead pressures were SSV /2020/0 psi. The current plan forward is to shut -in the offset injector (MPC- 08) to reduce pressure support being directed to MPL -06. In addition, an acid treatment will be pumped down the tubing in attempt to dissolve the scale and bring the well back on -line. The well has been reclassified as Under Evaluation for further diagnostics diagnostics. 9 9 A TIO plot and wellbore schematic have been included for reference. «MPL -06 TIO Plot 07- 09- 11.doc» «MPL- 06.pdf» 1 ( LtO N+. if= 7 Z92 Thank you, Torin Roschinger (filling in for Jerry Murphy) Z 7 ` ` ti1 Well Integrity Coordinator ice � � 4 i� Office (907) 659 -5102 Harmony Radio x2376 pub 0y JUL Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 7/13/2011 MPU L-06 PTD 1900100 7/9/2011 l[DO Pressures Plot —�-�------------- '-------------- - -- | Well: M MAR 4,000 - � . 3,000 ' | . { | —0— —II— IA --A-- OA -- OOA —4— 0004 n | ` 1,0OO '''''' 04/09/11 04/23/11 05/07/11 05/21/11 06/04)11 06/18/11 07/02/11 Tree:WKM 2 9/16" 5M 0 Orig. DF gat 55.0' (Pool) Wellhead11" 5M WKM M P L -06 Orig. GLIIIIPlr. = 21.0' (Pool; 2.5" CIW BPV profile DF to GL = 34' J ._ ,,,___ I. 20" Conductor Casing 112' 1 1,1 SLB 2 7/8" x 1" KBMM GLM 139' Halliburton Hos stage 1885' 0 cementer 9 -5/8" 36 #, J -55 BTC csg 6314' 4 down squeezed 8/25/91 KOP @ 1000' SLB 2 7/8" x 1" KBMM GLM 10205' Max Hole Angle: 56.60° @ 4457' if H EA ole angle through perfs. = 55 deg Ali ma 2 -7/8" HES XN nipple 10348' C ji ( 2.205" No -Go ID ) RA tag at 10303' t r : WeIlLift Discharge Gauge 10361' Centrilift Pumps 160P11 & 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. L 18P75 Coated, PMSXD /SXD 1:1 10365' AN ( drift ID = 2.347 ", cap. = 0.00592 bpf) Gas Separator GasMaster 10399' 7 ", 26 #, L -80 Buttress casing � • " �` Coated ID (drift ID = 6.151", cap. = .0383 bpf) Intake TVD 6906' ti1i tP 7:5-0E-A" N °t Centrilift tandem seal section GSB3DB UT /LT SB /SB PFSA 10404' - � Centrilift 562 series Motor (rerated) Stimulation Summary:�� 195 HP KMH A 2177 V / 53 A 10418' 6/15/91 Frac, All zones 169,139# of 16/20 I-Prop. 28,603# 12/18 I -Prop. WeIlLift MGU Gauge w/ 6 Fin 10438' screened out w/ 14,082# 12/18 I -Prop. Centralizer above perfs. Gauge TVD 6928' BOT Safety Shear Sub 10441' Perforation Summary: ... Ref log:SWS CCL log dated 3 May 90 i ! 2 7/8" Ported Tbg Jt. 10445' � BOT Cup Packer 10447' Size SPF Interval (TVD) .. .... BOT Excluder Screen w/ 10456 -97' 4.5" 5 10566'- 10593' 7002' -7017' .... bull plug 4.5" 5 10632'- 10662' 7042' -7058' -- 4.5" 5 10678'- 10693' 7067' -7076' 4.5" 5 10714'- 10724' 7089' -7094' 4.5" 5 10800'- 10821' 7139' -7152' 4.5" 5 10834'- 10878' 7166' -7186' 4.5" 5 10900' - 10904' 7200' -7202' 7" Float collar 10985' Mid -pert TVD - 7102' 7" csg. shoe 11068' Mid -pert MD - 10735' PBTD TVD - 7255' DATE REV. BY COMMENTS Milne Point Unit 11/27/90 Drill Pool Arctic 102 7/20/91 Comp EWS WELL L-06 9/24/93 RWO Riq 4 7/16/98 FWO Nabors 4 -ES 11/20/98 MDO ESP RWO / Calvins Nabors 4 -ES API NO: 50- 029 -22003 04/10/01 B. Hasebe ESP RWO Nabors 4 -ES 6/16/05 L. Hulme ESP Replacement Nabors 4ES 7/7/07 L. Hulme ESP Replacement Nabors 4ES 11/27/08 L. Hulme C/0 ESP, Add screens & Cup Pkr Nabors 3S BP EXPLORATION (AK) STATE OF ALASKA A~ OIL AND GAS CONSERVATION C011~SION REPORT OF SUNDRY WELL OPERATIONS is ~~ 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ®Other Change Out ESP 8 Add Screens ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. WeII Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development • ^ Exploratory 190-010 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22003-00-00 - 7. KB Elevation (ft): ~, 9. Well Name and Number: MPl-06 8. Property Designation: 10. Field /Pool(s): ADL 047434 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11091- feet true vertical 7313 - feet Plugs (measured) 10496' (Buii Piug) Effective depth: measured 10983 feet Junk (measured) None true vertical 7248 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' 1740 750 Surface 6279' 9-5/8" 6314' 4590' 3520 2020 Intermediate Production 11033' 7" 11068' 7299' 7240 5410 Liner ;ta~ ~E~ ~; ~ 2001 ~ Perforation Depth MD (ft): 10566' - 10904' Perforation Depth TVD (ft): 7001' - 7200' 2-7/8", 6.5# L-80 10497' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" , 26#, Baker BOT Cup Packer Assembly 10447' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~`` ~C>LS~ 6.1~C~ (J Treatment description including volumes used and final pressure: Pull Tubing, Change Out ESP, Add BOT Excluder Screens (10456' - 10496') and a 7", 26# Baker BOT Cup Packer Assembly (10447' 10451' . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1940 0 Subsequent to operation: 68 348 647 240 224 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram - ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact David Bjork, 564-5683 N/q Printe Sondra Stewman _ Title Drilling Technologist ~~~~ Prepared By Name/Number: Si ture Phone 564-4750 Date ~ - (~'~~Sondra Stewman 564-450 Form 10-404 Revised 04/2006 ~~ tr.~O ~~ ~ ~ ~~~,a ~~ ,~/ Submit Original Only Tree:WKM 2 9/16" ~ Orig~elev. = 55.0' (Pool Wellheadl1 5M W M P L-46 Orig. elev. = 21.0` (Pool 2.5" CIW BPV profile DF to GL = 34' I20" Conductor Casing 112' SLB 2 7/8" x 1" KBMM GLM 139' Halliburton Hos stage 1885' cementer I9-5/8" 36#, J-55 BTC csg 6314' down squeezed 8/25/91 KOP @ 1000` Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. RA tag at 10303' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7", 26#, L-80 Buttress casing (drift ID = 6.151", cap. _ .0383 bpf) Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I-Prop. 28,603# 12/18 I-Prop. screened out w/ 14,082# 12/18 I-Prop. above perfs. Perforation Summar}L Ref log_SWS CCL log dated 3 May 90 Size SP Interval (TVD) 4.5" 5 10566'-10593' 7002'-7017' 4.5" 5 10632'-10662' 7042'-7058' 4.5" 5 10678'-10693' 7067'-7076' 4.5" 5 10714'-10724' 7089'-7094' 4.5" 5 10800'-10821' 7139'-7152' 4.5" 5 10834'-10878' 7166'-7186' 4.5" 5 10900'-10904' 7200'-7202' Mid-petfi TVD - 7102' Mid-perf MD - 10735' PBTD TVD - 7255' DATE REV. BY 11/27(90 9/24/93 11/20!98 04/10/01 MDO B. Hasebe 6/16/05 7/7/07 L. Hulme L. Hulme 11/27/08 L. Hulme COMMENTS Pool Arctic 102 7/20/91 Comp EWS Riq 4 7/16/98 WO Nabors 4-ES ~ RWO / Calvins Nabors 4-ES ESP RWO Nabors 4-ES ESP Replacement Nabors 4ES ESP Replacement Nabors 4ES C/O ESP, Add screens & Cup Pkr Nabors 7" Float collar 7" csg. shoe 10985' 11068' Milne Point Unit WELL L-06 API NO: 50-029-22003 BP EXPLORATION (AK) SLB 2 7/8" x 1" KBMM GLM 10205' 2-7/8" HES XN nipple 10348' ( 2.205" No-Go ID ) WeIILift Discharge Gauge 10361' Centrilift Pumps 16oP11 a 10365' 18P75 Coated, PMSXD/SXD 1:1 Gas Separator GasMaster 10399' Coated ID Intake TVD 6906' Centrilift tandem seal section ' GS63DB UT/LT SB/SB PFSA 10404 :entrilift 562 series Motor (rerated) 95 HP KMH-A 2177 V / 53 A 10418' WeIILift MGU Gauge w/ 6 Fin 10438' Centralizer Gauge TVD 6928' BOT Safety Shear Sub 10441' 2 7/8" Ported Tbg Jt. 10445' BOT Cup Packer 10447' BOT Excluder Screen w/ 10456-97' bull plug • • BP EXPLORATION Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To Hours Task Code NPT 11/14/2008 106:00 - 14:30 8.501 RIGD P 14:30 - 15:00 0.50 ~ MOB ~ P 15:00 - 18:00 ~ 3.00 ~ RIGU ~ P 18:00 - 20:00 I 2.001 BOPSUR P Start: 11 /14/2008 Rig Release: 11 /28/2008 Rig Number: Page 1 of 7 ~ Spud Date: 3/7/1990 End: Phase Description of Operations PRE Rig down off of MPF-87A. Jack the Camp and prepare for moving. Scope and lower the Derrick at 0900 hrs. Move the Camp, Shop, Generator and Parts House from MPF-Pad to MPL-Pad at 1200 hrs. Back the Carrier off of well slot MPF-87 with the Toolpusher and Pad Operator present at 1330 hrs. Prepare for mobilization. PRE Move the Carrier, Pipe Shed and Pits Modules from MPF-Pad to MPL-Pad. Stage the Modules on the pad out of the way and spot the Carrier to work on the BOP Stack Configuration. We will be changing the Ram configuration due to a MAASP > 3,000 psi. PRE PJSM. Prepare the Cellar and gather up work equipment and parts for changing out the Ram configuration. Call out for additional mobile heaters and rig up. PRE Crew change, PJSM. Spot cradle with BOP stack in cellar. Raise BOPE in the Cradle and remove VBR blocks from lower set of Rams. 20:00 - 00:00 4.00 BOPSUFI N WAIT ~ PRE 11/15/2008 ~ 00:00 - 08:30 ~ 8.50 ~ BOPSUFj P ~ ~ PRE 08:30 - 00:00 15.501 BOPSUFjN ~ WAIT ~ PRE 111/16/2008 100:00 - 18:00 I 18.001 BOPSUFiN I WAIT I PRE 18:00 - 00:00 6.00 BOPSU N WAIT PRE 11/17/2008 00:00 - 00:00 24.00 BOPSU N WAIT PRE 11/18/2008 100:00 - 00:00 24.00 BOPSUF~ N WAIT PRE Stop the operation due to accident on the Rig. IP got his fingers stuck in a pinch point while closing the Ram Door. Employee was sent to the medic for evaluation. Make notifications to MPU Safety and Well Ops Coordinator, Workover Ops Superintendent, ADW Drilling HSE Advisor and Workover Engineer. Hold safety stand down with the crew, both WSLs, both Toolpushers, ADW Drilling HSE Advisor and Nabors Safety. Resume work on the BOP Stack Configuration. We will be changing the Ram configuration to a 3 Ram_± Annular Stack due to a MAASP > 3,000 psi... Remove Ram blocks and install in new stack. Stand down all operations and place the Rig on Code 8 until further notice. Discuss with BP Workover Ops Superintendent and Nabors Superintendent on way forward to establish a written safety plan for the Rig. Call out Peak Truck Pusher and move the Modules to the side of the Pad and position them such that we can connect all steam and power lines. Review procedures for accuracy and changes. Brainstorm on what areas/hazards exist on the Rig to formulate a list for our written safety work plan. At 18:00 hrs had Rig visit by Nabors Workover Superintendent and Nabors Safety. Rig crew divided into three teems and conduct hazard hunt of Carrier, Pipe Shed, Boiler /Pits, Shop, Gen skid, and camp. Stand down all operations.and place the Rig on Code 8 until further notice. Rig crew divided into three teems and conduct hazard hunt of Carrier, Pipe Shed, Boiler /Pits, Shop, Gen skid, and camp. Repeat hazard hunt with day crew. Get approval to begin working on quick fixes to some of the hazards encountered. No major work_and/or projects are authorized to commence. Work on hazard hunt pick list. Continue working on quick fixes to some of the hazards encountered from hazard hunt. No major work and / or projects are authorized to commence. Continue working on quick fixes to some of the hazards Printed: 12/18/2008 1:24:01 PM • BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 11/14/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/28/2008 Rig Name: NABOBS 3S Rig Number: Date 'From - To Hours ~ Task Code'., NPT Phase Description of Operations 11/18/2008 00:00 - 00:00 24.00 BOPSU N WAIT PRE encountered from hazard hunt. No major work and / or projects are authorized to commence. Pre-job assessment completed prior to each task. 11/19/2008 00:00 - 16:00 16.00 BOPSU N WAIT PRE Continue workin on uick fixes to some of the hazards encountered from hazard hunt. No major work and / or projects are authorized to commence. Pre-job assessment completed prior to each task. 16:00 - 20:00 4.00 BOPSU N WAIT PRE Conduct safet meetin with both da and ni ht tours, workover superintendent, NAD superintendent, ADW safety, Toolpusher's and WSL's. Wrap up safety standown with crews prior to commencing rig operations. 20:00 - 00:00 4.00 BOPSU P PRE PJSM. ND and .onfiaure BOP stack to orientate and accomadate a double gate below annular. Separate single gate from annular and mud cross. Set annular on double gate. 11/20/2008 00:00 - 06:00 6.00 BOPSU P PRE Continue to NU annular to double gate. NU bag and double gate to flow cross. Set stack on cradle. Complete hazard assessment prior to each pick. 06:00 - 09:00 3.00 BOPSU P PRE Pre-tour safety meeting and checks with day crew. Review procedure and perform hazard analysis on laying the BOP over in the Cradle with the Toolpusher present. Lay down the Annular, Double Gate and Mud Cross in the Cradle with no issues. 09:00 - 14:30 5.50 RIGU P PRE Work on the area around well slot MPL-06. Call out Trucks to move the Rig and having to wait on Peak trucks due to Nabors 4ES moving. Remove the BOPE Cradle from the Cellar and move over to the well. Spot the BOPE behind the well along with the Single Gate and Test Spool. Spot Rig Mats, plywood and herculite around the well. 14:30 - 20:00 5.50 RIGU N WAIT PRE Wait on trucks to move the Rig onto well slot MPL-06. 20:00 - 00:00 4.00 RIGU P PRE Peak trucks on location. Conduct safety meeting with drivers and crew. Move pipe shed over to well slot. Call pad-op and witness sub spotting over MPL-06. Position pipe shed and connect to sub. Set boards and jack rig and shed into position. 11/21/2008 00:00 - 07:00 7.00 RIGU P PRE Spot pits, place boards and herculite. Spot Upright tank in spill containment next to pits. Spot LRS unit next to upright. Move change room. Connect pit lines, steam lines and electrical between modules. Raise and scope Derrick at 03:45 hrs. String and hang blocks. Secure Derrick and Rig Floor. The Rig was accepted at 0700 hrs on 11/21/2008. 07:00 - 11:00 4.00 KILL P DECOMP Rig up double annulus valve on the IA. Rig up lines to the Tree and Kill Manifold to kill the well. Spot the Tiger Tank and rig up hardline for returns. 11:00 - 14:30 3.50 KILL P DECOMP Hold meeting with Schlumberger coil unit on MPL-34 and Pad Operator to discuss spacing issues. Heat the 11.0 ppg brine in the Upright Tank to 125 degF and ship to the Pits to be able to rig down Little Red and move them out of the way. 14:30 - 16:00 1.50 KILL P DECOMP Fill lines and pressure test surface lines to 3,500 psi. Pressure test return line to the Tiger Tank to 500 psi. 16:00 - 17:00 1.00 WHSUR P DECOMP RU Lubricator with Well Su ort Techs. Pressure test to 500 si with diesel a ainst closed swab valve. Pull 2-1/2" T e "H" BPV. Note wellhead ressures of Tb = 1,100 si IA = 2 000 si OA = 20 si. 17:00 - 17:30 0.50 KILL P DECOMP Hold pre-kill safety meeting with WSL, Toolpusher, Nabors Printed: 12/18/2008 1:24:01 PM • • BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 11/14/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/28/2008 Rig Name: NABORS 3S Rig Number: Date ~I From - To Hours Task Code NPT Phase ', Description of Operations 11/21/2008 17:00 - 17:30 0.50 KILL P DECOMP Crew, MI Mud Engineer and CH2M Hill Vac Truck Drivers. 17:30 - 18:00 0.50 KILL P DECOMP Line up to bleed gas off of the IA to the Tiger Tank. Crack the Choke open and observe gas coming right at the Rig due to wind direction. The wind direction changed during the day and has also increased in wind speed. Close the Choke and shut down venting operation. 18:00 - 21:00 3.00 KILL C DECOMP Discuss plan forward /hazards with Milne Operations, Pad Operator and Coil Unit. Discuss with Anchorage Engineering as well. Decision made to re-spot the Tiger Tank at a safe location away from the Rig and Coil and run hardline to it. 21:00 - 00:00 3.00 KILL C DECOMP PJSM. Call out wells support with hardline trailer. Use heavy equipment to clear pathway for hardline to Tiger tank thru center of pad. Re-spot Tiger tank on north side of pad. RU hardline from rig to Tiger tank. Tiger tank downwind and 180 11/22/2008 00:00 - 02:30 2.50 KILL C DECOMP 02:30 - 04:30 2.00 KILL P DECOMP 04:30 - 06:00 1.50 KILL P DECOMP 06:00 - 06:30 0.50 KILL P DECOMP 06:30 - 09:30 3.00 KILL P DECOMP Continue to RU hardline to Tiger tank (approx 300 feet from rig). Barricade and place signs to route traffic around hazard areas. Blow air and steam thru hardline. Get initial strap and check high level alarm on Tiger tank. PJSM. Initial wellhead pressures: TBGP = 530 psi / IAP = 1950 psi /OAP = 20 psi. Open well and bleed IA thru choke to Tiger tank from 1950 psi to 1100 psi in 60 minutes, bled all gas then swapped to fluid. Break circulation down tubing with 11 ppg brine taking returns from the IA thru the choke at 1 BPM / 1100 psi. Circulate 65 bbls at 3 BPM / 950 psi. Shut choke and blow down hardline. Returned 26 bbls to Tiger tank during circulation. Bullhead 40 bbls down tubing at 3 BPM / 1380 psi. Shut in well and monitor tubing pressure for 20 min. Tubing pressure fell to 0+ psi. Pre-tour checks and monitor the SITP. SITP = 0 psi , SICP = 1,350 psi• Open the choke and break circulation with 11.0 ppg brine down the Tubing taking returns up the IA through the Choke to the Tiger Tank. Initial rate of 2 bpm with 480 psi on the Tubing and 1,500 psi on the IA. Increase rate to 3 bpm for the remainder of the circulation with maximum pressures of 1,370 psi on the Tubing and 1,950 psi on the IA. Finish circulation with a pump rate of 2 bpm with 400 psi on the Tubing and 80 psi on the IA. Check weight of returns and getting 10.9+ ppg returns. Pumped a total of 535 bbls of brine with 315 bbls of returns on 09:30 - 11:00 1.50 KILL P DECOMP Shut down and blow down all surface lines and hardline to the Tiger Tank. Monitor the well and both the Tubing and IA are blowing with no discernible pressure. Allow the well to U-tube and still blowing. 11:00 - 14:00 3.00 KILL P DECOMP Line up returns to the Pits and circulate an additional 150 bbls of 11.0 ppg brine down the Tubing and up the IA to aid in cleaning up. Break circulation at a rate of 3 bpm / 730 psi. Getting 10.9 ppg brine returns initially and then 11.0 ppg brine returns. Lost 19 bbls of brine while circulatina (-85% returnsl_ Shut down and monitor the well for 30 minutes. Both the T. Shinn onr! 14 pro rloarJ _ c4a}in Alcithcr hln~niinn nnr nn a vac Ptlntetl: 1Z/18/ZUUB 1:14:01 PM r~ u n u BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 11/14/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/28/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code ' NPT Phase Description of Operations 11/22/2008 14:00 - 14:30 0.50 WHSUR P DECOMP PU T-bar and set 2-1/2" T e "H" TWC with Cameron re . Screw in with 5-1/2 turns and measure the travel at 1-1/2". 14:30 - 18:00 3.50 WHSUR P DECOMP Pressure test the TWC from below by pumping down the IA with 11.0 ppq brine at a rate of 1.2 bpm / 300 psi for 10 charted mins - ood test. Pum ed a total of 22 bbls. No ressure noted on the Tubin above the TWC while testin from below. Bleed off pressure and blow down lines. Line up to test the TWC from above. Test TWC from above to 3.500 psi for 10 e: charted minutes - ood test. RD lines and clear cellar for ND tree. 18:00 - 20:30 2.50 WHSUR P DECOMP PJSM. Pre-tour checks. Two-hole and mark adapter and tree. ND tree in two pieces to get out of cellar. Break out and set tubing adapter to side. Function test LDS and alignment pin - good. MU 2-7/8" 8rd pup to hanger - 9 turns. Monitor well during ND, well on light vacuum. 20:30 - 00:00 3.50 BOPSU P DECOMP PJSM. NU 11" x 13" DSA, 13" test spool and single gate rams_ to wellhead torque all connections. IA still on vacuum. 11/23/2008 00:00 - 06:00 6.00 BOPSU P DECOMP PU BOP stack with annular, double ate and mud cross off of cradle. NU stack to single gate. Final configuration: annular, double ate flow cross, sin le ate, tests ool. Secure stack and hook u koome lines 06:00 - 18:00 12.00 BOPSU P DECOMP NU Choke Block and tighten the bolts. Install Rams in the Double Gate with the following configuration: 2-7/8" Fixed on top and Blind Rams on the bottom. The 2-7/8" x 5" VBR's are in the Single Gate below the Mud Cross. Connect Choke and Kill Lines. Install Flow Riser. Fill the Stack and Choke Manifold with water. Function test and body test the BOPE looking for any leaks prior to testin . 18:00 - 19:30 1.50 BOPSU P DECOMP D A leakin on 11"wellhead connection and Ian Ti hten DSA and gland nuts. Shoot fluid level with Well Su ort. Fluid level at 1 19:30 - 23:30 4.00 BOPSU P DECOMP Test ROPE to 250 psi low / 3500 psi high. Use 2-7/8" test joint on 2-7/8" VBR's, 2-7/8" fixed rams and annular. Perform accumulator test. L/D test joint and suck out stack. Blow down choke manifold. Test witnessed by BP WSL and NAD Toolpusher. AOGCC rep Chuck Sheave waived witness at 19:45 hrs. Monitor IA during BOPE test. 23:30 - 00:00 0.50 BOPSU P DECOMP Shoot fluid level with Well Su ort. Fluid level fell to 300' (approx 9 bbls). R/U Little Red Services to IA to fill annulus. 11/24/2008 00:00 - 01:30 1.50 WHSUR P DECOMP Pressure test LRS lines to 200 psi. Gravity feed 11 ppg brine to IA. Fill hole with 9 bbls. Blow down lines to pits. Monitor well for 15 min. Well on a vac. 01:00 - 03:00 2.00 WHSUR P DECOMP PJSM. Hang blocks, slip and cut drilling line and secure dead man. 03:00 - 04:30 1.50 WHSUR P DECOMP PJSM. PUMU Opso-Lopso, pump-in-sub and Well Support lubricator. Screw into tubing hanger with 9 turns. Pressure test lubricator to 500 si with diesel. Pul! TWC, tubing on vac. LD lubricator, pump-in-sub, and Opso-Lopso. Clear rig floor. 04:30 - 06:30 2.00 PULL P DECOMP PJSM. PUMU landing joint with TIW valve. Screw into tubing hanger with 9 turns. BOLDS with Cameron technician. IA is on a vac and the OA is at 0 psi. Pull the Hanger off seat at PUW = 75K and pull the Hanger with PUW = 70K. 06:30 - 08:30 2.00 PULL P DECOMP Circulate bottoms up at a rate of 4 bpm / 1,100 psi with 11.0 Printed: 12/18/2008 1:24:01 PM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 11/14/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/28/2008 Rig Name: NABOBS 3S Rig Number: Date From - To 'Hours Task Code NPT' Phase Description of Operations 11/24/2008 06:30 - 08:30 2.00 PULL P DECOMP ppg brine. It took 12 bbls to fill the well. Some crude observed in initial returns and cleaned u after that. Weight of clean returns at 11.0 ppg. RU Elephant Trunk and containment while circulating. Pumped a total of 405 bbls. Monitor the well for 30 mins -the IA and Tubing are on a vac. Visually confirm IA level fallin . 08:30 - 09:30 1.00 PULL P DECOMP Break off circulating hose and blow down circulating lines. 09:30 - 10:30 1.00 PULL P DECOMP Cut the ESP Cable and secure to the Tubing with Cehtrilift rep with 2 bands. Break out and lay down the Hanger. 10:30 - 11:30 1.00 PULL P DECOMP RIH with single joints of 2-7/8" Tubing from the Pipe Shed to to SOW = 40K. Tag 30' in on Joint #13 from the Shed = 10,840'. Re-confirm depth with same tag depth. Confirm with Anchorage Engineering on plan forward. 11:30 - 00:00 12.50 PULL P DECOMP POOH with existin 2-7/8" ESP Com letion standin back in the Derrick. Double displace every 5 stands out to kee the hole full with 11.0 brine. 25 stands out at 1430 hrs. Avera in 7.5 bbls er hour loss rate while POOH. 11/25/2008 00:00 - 03:00 3.00 PULL P DECOMP Continue to POH with ESP completion standing back in Derrick. Pumping across hole, well taking 9 bbl/hr loss rate while tri in Recoverd 327 jts, 2 GLM ass'y, 1 XN, 171 LaSalle clamps, 6 Protectilizers, 3 Flat guards. 03:00 - 07:30 4.50 PULL P DECOMP PJSM. Break out and LD ESP pump. Pump across hole while LD ESP. Clean and clear rig floor. Remove ESP equipment. 07:30 - 13:30 6.00 CLEAN P DECOMP PUMU mule shoe and XO to tubing. RIH out of Derrick on 2-7/8" tubing. Pump across hole while RIH. 13:30 - 15:30 2.00 CLEAN P DECOMP PU singles from shed to jt #18 from shed tagged fill at 10,839'. RU to reverse circulate. 15:30 - 16:30 1.00 CLEAN P DECOMP Reverse circulate from 10,839' to 10,852' at 3 BPM / 400 psi. Bottom losses averaged 60 BPH during reverse. 16:30 - 18:30 2.00 CLEAN P DECOMP Circulate the Ion wa thru the choke at 3.5 BPM / 740 si surface to surface without losses. Minimal san return 18:30 - 21:00 2.50 CLEAN P DECOMP Blow down and RU Little Red. Ensure fluid lines for LRS are clear. P/T line to 3,500 psi. Evacuate fluid from pill pit to build hi-vis pills. Build 30 bbl hi-vis sweep. Monitor well -static losses. 21:00 - 00:00 3.00 CLEAN P DECOMP PJSM. PU singles from shed and RU circulating head to each joint. PUW = 64K, SOW = 37K. Circulate the long wav and wash down from 10,852' to 10 947'. Circulate 10 bbl sweep followed by 150 bbls 11 ppg brine at 6 BPM / 1980 psi between each connection. Wash down with out hard obstruction. PU and SO weights unchanged. Reciprocate pipe 1-1/2 tool joint length while circulating. Recovering fine sands. 11 ppg brine returns while circulating. 11/26/2008 00:00 - 04:30 4.50 CLEAN P DECOMP Circulate at 10,947' a 20 bbl hi-vis sweep at 6 BPM / 1980 psi with Little Red in conjuction with rig pump. Recovering fine sands thru out, circulate until clean. 11 ppg brine returns while circulating. Reciprocate pipe 1-1/2 tool joint while circulating. Shut down umps, RIH to bottom at 10 947' with out r ri Monitor well for 30 min -static. Clear rig floor. -Circulated total = 1206 bbls. -Loss while circulatin total = 23 bbls. 04:30 - 06:00 1.50 CLEAN P DECOMP PJSM. LD singles used to wash. POH from 10,947' to 10,543' (23' above perfs). Monitor well for 15 min - OK. Printed: 12/18/2008 1:24:01 PM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 11/14/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/28/2008 Rig Name: NABOBS 3S Rig Number: i I Date ', From - To Hours ' Task Code NPT Phase Description of Operations - -- - 11/26/2008 04:30 - 06:00 1.50 CLEAN P DECOMP Continue to LD singles used to wash. RU to stand back in Derrick. 06:00 - 12:00 6.00 CLEAN P DECOMP POH standing back 2-7/8" tubing in Derrick, pumping across the top. 12:00 - 14:00 2.00 RUNGO RUNCMP BOLD muleshoe. Clean and clear Rig floor. Lay down elephant trunk. Prep for running completion 14:00 - 21:30 7.50 BUNCO RUNCMP PUMU Baker Excluder screen with 7" 26# cup packer assembl .Shear type safety joint pinned at 35,200 #'s. PUMU Centrilift ESP BHA. String ESP cable over sheave and connect. 21:30 - 00:00 2.50 BUNCO RUNCMP PJSM. RIH out of Derrick with 2-7/8" tubing. Running speed very slow (30-40 FPM) due to Baker cap packer floating string in hole. PumDlna across top of hole. pushing fluid awav as we RIH with ESP / acker ass' .Call out load of brine to acount for losses. Flow check well every 10 stands while running completion. 23 stands in at 24:00 hrs. - Use best-o-life thread dope, install LaSalle clamps on first 9 joints and one every other joint. - Stop and flush pump every 2000' and check conductivity. Circulate at .5 BPM / 1600 psi. 11/27/2008 00:00 - 06:00 6.00 BUNCO RUNCMP Continue running ESP completion very slowly (25-35 FPMI. Flow check well every 10 stands, static losses are 3 bbls/hr. Pushing additional fluid away while running completion. Using best-o-life on threads, place LaSalle clamps on every other joint. Flush pump and check conductivity every 2000' (.5 BPM / 1600 psi). 06:00 - 11:30 5.50 BUNCO RUNCMP Crew change. Continue RIH with ESP 2-7/8" tubing from Derrick. 110 stands in hole C~ 11:30. 11:30 - 16:30 5.00 BUNCO RUNCMP Centrilift make cable to cable splice. 16:30 - 21:30 5.00 BUNCO RUNCMP Continue RIH w/ ESP completion as per running order 326 jts, 2 GLM's, 1 XN ass'y. Ran 170 LaSalle clamps, 5 protectilizers, 4 flat guards and 7 SS bands. 21:30 - 22:30 1.00 BUNCO RUNCMP Re-dress and MU tubing hanger and landing joint and TIW valve with Cameron rep. Install penatrator and orient for ESP cable splice. Install shipping cap on penatrator. Flush pump with 10 bbls at .5 BPM / 2000 psi. 22:30 - 00:00 1.50 BUNCO RUNCMP Make penatrator splice with Centralift, install and test conductivity. Run remaining ESP cable over sheave. RD tongs and clear rig floor. 11/28/2008 00:00 - 01:30 1.50 BUNCO RUNCMP PUW = 74K SOW = 40K. Land tubin han er. RILDS as per Cameron rep. LD landing joint and TIW valve. 01:30 - 02:30 1.00 BOPSU P RUNCMP Set TWC with Cameron re Pressure test from above to 1000 psi for 10 charted min. 02:30 - 07:00 4.50 BOPSU P RUNCMP PJSM. ND BOPE. 07:00 - 12:00 5.00 WHSUR P RUNCMP NU tubing head adaptor from previous tree. NU class B 2-9/16" tree. Test hanger void to 5000 psi for 30 minutes. Centrilift final checks OK -Intake psi=3954 psi /Discharge psi=3934 /Temp 170 deg F / 3.7 ohms phase to phase / 500 meg ohms phase to ground. Test tree with diesel to 5000 psi. 12:00 - 13:00 1.00 WHSUR P RUNCMP PUMU lubricator and ull TWC. D Rod BPV 13:00 - 15:30 2.50 WHSUR P RUNCMP MIRU LRS and freeze protect IA with 65 Bbls of crude - 1.5 BPM 2600 psi. Bullhead tubing with 15 Bbls of crude - 1/2 BPM, 2600 psi. Printed: 12/18/2008 1:24:01 PM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 11/14/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/28/2008 Rig Name: NABORS 3S Rig Number: Date ', From - To Hours Task Code NPT Phase Description of Operations 11/28/2008 15:30 - 16:00 0.50 WHSUR P RUNCMP Remove double IA valve. Normal up tree and cellar. 16:00 - 16:00 24.00 RIGD P POST Release rig ~ 16:00 for move to MPL-34i Printed: 12/18/2008 1:24:01 PM /~- SP,~ATE~+OF ALASKA ^~ 11!14/07 Q,L AND GAS C®N$ERVATl~ON CIOMII~ISSIC}N BOFE Test Report Submit ~: Contractor: Nabors Rig No.. 3S DATE: 11/23/2008 Rig Rep.: J. Greco / J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-448x5 Op. Fax. 659-4628 Rep.: W. Hoffman / V.Voipe Field/Unit & WeA No.: MP !- 06 PTD ~ 79AAl80 Operaiion: Drlg: Test: Initial: x Test Pressure: Rams: 254/3500 MISC. INSPECTIONS: Workover: x Weekly: Anr~ar: 25013500 TEST DATA Test Result Test Resuf# Location Gen.: P Wetl S P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test. Result. Annular Preventer 1 135/8 5000 P Pipe Rams 1 2 7/8 P Lower Pipe Rams 1 2 718 X 5 P Blind Rams 1 Blthd P Choke Ln. Valves 1 3118" 5000 P HCR Valves 2 31/8" 5000 P Kill Line Valves 1 21/16" 50fl0 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Lower Kelly 0 NE Batl Type 1 P Inside BOP 1 P Explor.: Si-Vl-eekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA CHOKE MANIFOLD: Quantity Test Result No. Vahres 13 P Mama! Chokes 1 P Hydrau~ Chokes 1 P ACCt1MtILATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1500 P 2~ psi Attained 40sec P FuN Pressure Attaired 2 min 55 sec P Blirtt Switch Covers: All stations P Nitgn. Bottles (avg): 1950 Test Results Number of Failures: 0 Test Tune: 5 Hours Repair or replacement of meat w be made~t days.. Inspector 659-3607, foEEaw witle written canfkmat~ to Superv~er at: Remarks: Tested with 2 7/8" test faint against Two wav deck 24 GIVEN YES X NO Date 09/21/08 Time 0900 hrs est start 1800 tars F ~, Witness J. Fritts / V. BOP Test (for rigs) BFL 11/14/07 ~ ~~~" ~i_-i~ c, ~. 2~~ Cocn~onents tested ALL Notify the North Slope By _ Chuck Sheve Nabors 3s BOP Test MP L-06 11-23-08.x1s r ~~ I~EC-~IV~L~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SIGN ~Q~ ~ ~ ~~~~ REPORT OF SUNDRY WELL OPERATIOJ~'t~~ca Oil & Gay Cans. ~tammission 1. Operations Abandon ~ RepairWell ~ PlugPerforations ~ Stimulated Otl-~~~fID Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' Exploratory ~ 190-0100 3. Address: P.O. Box 196612 Stratigraphic ~' ServiCe ' 6. API Number: Anchorage, AK 99519-6612 50-029-22003-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56 ~ KB MPL-06 8. Property Designation: 10. Field/Pool(s): ADLO-047434 ` MILNE POiNT~ Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11173 - feet Plugs (measured) None true vertical 7362.5 feet Junk (measured) None Effective Depth measured 10983 feet ~~~~~~ ~~~ ~ ~ ~~~~ true vertical 7248 feet Casing Length Size MD TVD Burst Collapse Conductor 80` 20" Surface - 115' Surface - 115' Surface 6279' 9-5/8" 36# J-55 Surface - 6314' Surface - 4590' 3520 2020 Production 11033' 7" 26# L-80 Surface - 11068' Surface - 7299' ~ 7240 5410 Perforation depth: Measured depth: 10566 - 10593 10632 - 10662 10678 - 10693 10714 - 10724 10800 - 10821 10834 - 10878 10900 - 10904 True Vertical depth: 7000.98 - 7016.32 7038.59 - 7055.88 7065.15 - 7073.88 7086.16 - 7092.03 7137.15 - 7149.76 7166 - 7186 7200 - 7202 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 10461' ' 0 0 - Packers and SSSV (type and measured depth) NO PACKERS 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~; _._ _.. ~.- ~)~( w 4 ~d~f 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 72 401 542 271 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~' Development ~'' Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG ~' GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ne 564-4944 Date 11/9/2007 unn IV-4V4 neviseuivwicuw .~uu~nu viiyuini vn~y l Lt~l~ • MPL-06 • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE~ SUMMARY' - 10/30/2007;T/I/0=650/1260/40. (ESP acid treatment). Spear into tbg w/ 15 bbls crude for infectivity. Pump 7 bbls 15 % DAD acid down tbg followed by 3 bbls neat meth & '48 bbls crude to spot acid C~ ESP. Let soak for 20 minutes. Start ESP against 'closed choke forward for 5 minutes & reverse for 5 minutes, then forward for 5 ..minutes. Displace tbg w/ 136 bbls dead crude and 50 bbls diesel. FW H P=500/1580/0 FLUIDS PUMPED BBLS 3 NEAT METH 7 15% DAD ACID 151 DEAD CRUDE 50 DIESEL 211 TOTAL . STATE OF ALASKA .~ ALAYA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED ¡~UG 0 1 2007 Cons, Cammission 1. Operations Performed: {"~j ;,~;;'1 ~'Ü~ '~'~;v o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 190-010 / 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22003-00-00 / 7. KB Elevation (ft): 56' / 9. Well Name and Number: MPL-06 ( 8. Property Designation: 10. Field 1 Pool(s): . ADL 047434 ' Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 11091 ¡ feet true vertical 7313 feet Plugs (measured) None Effective depth: measured 10983 feet Junk (measured) None true vertical 7248 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' 1740 750 Surface 6279' 9-5/8" 6314' 4590' 3520 2020 Intermediate Production 11033' 7" 11068' 7299' 7240 5410 Liner sr~ED AUG ~. '1 20D7 Perforation Depth MD (ft): 10566' - 10904' Perforation Depth TVD (ft): 7001' - 7202' 2-7/8",6.5# L-80 10461' Tubing Size (size, grade, and measured depth): _ .~..."'_....~._~. . ~.--__IIIt.'.' Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 0 0 0 1740 0 Subsequent to operation: 19 339 993 290 278 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 N/A Printed Name Sondra Stewman Title Technical Assistant I -' Prepared By Name/Number: Si¡fuature ~À c--f/ ~ Phone 564-4750 DateOl-êl7-òl Sondra Stewman, 564-4750 . . Form 10-404 Revised 04/2006 ORIGINAL RBDMS BFl AUG 0 7 2007 ~ ~ Submit Onglnal Only ~¥p' Iree:WKM 2 9/16". Wellhead:11" 5M ~ 2.5" CIW BPV profile 20" Conductor Casing ~ Halliburton Has stage I 1885' I cementer .. 9-5/8" 36#, J-55 BTTS csgl 6314' I down squeezed 8/25/91 KOP @IOOO Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. (drift 10 = 2.347", cap. = 0.00592 bpf) 7", 26#, L-80 Buttress casing (drift 10 = 6.151", cap. = .0383 bpf) RA tag at 10303' Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I-Prop. 28,603# 12/18 I-Prop. screened out w/ 14,082# 12/18 I-Prop. above perfs. Perforation Summary: Ref log:SWS CCL log dated 3 May 90 Size SP Interval (TVD) 4.5" 5 10566'-10593' 7002'-7017' 4.5" 5 10632'-10662' 7042'-7058' 4.5" 5 10678'·10693' 7067'-7076' 4.5" 5 10714'·10724' 7089'-7094' 4.5" 5 10800'-10821' 7139'-7152' 4.5" 5 10834'-10878' 7166'-7186' 4.5" 5 10900'-10904' 7200'·7202' Mid-perf TVO - 7102' Mid-perf MO . 10735' PBTO TVO - 7255' DATE REV. 11/27190 9124/93 11/20/98 04/10/01 6116/05 07/07/07 MPL-06 COMMENTS ori. elev. = 55.0' (Pool Ori elev. = 21.0' (Pool OF to GL = 34' Cameo 27/8" x 1" sidepoeket KBMM GLM ID 2.38" I 130' I Cameo 27/8" x 1" sidepocket KBMM GLM I 10,236' I 102.38" 2-7/8" HES XN nipple ( 2.205" 10 ) 10,379'1 Centrilift Pumps 160P11 I 18P75 PMSSO 1:11 PMSX 1:1 10,393'1 Tandem Gas Separator 1 10,423'1 GRSXTBARH6 .. Centrilift tandem seal GSB3DBUT SB/SB PFSA GSB3DBL T SB/SB FSA CL5 10,423'1 Centrilift 562 series Motor 228 HP KMH 2306 v I 60 ( Re-rated H KME-1 2145 V I 52 A Centrilift PumpMate and I 10,451'1 Six Fin Centralizer . 8 - joints of tubing 2-7/8" Bull plug 10,702'1 Slickline tag 11/19/98 10956' 7" Float collar 10985' T' esg. shoe 11068' Milne Point Unit WELL L-06 API NO: 50-029-22003 MOO B. Hasebe L. Hulme MDO Orill Pool Arctic 102 7/20/91 Comp EWS RWO Rig 4 7/16/98 RWO Nabors 4-ES ESP RWO 1 Calvins Nabors 4-ES ESP RWO Nabors 4-ES ESP Replacement Nabors 4ES ESP Replacement Nabors 3S BP EXPLORATION (AK . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-06 MPL-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/3/2007 Rig Release: Rig Number: Spud Date: 3/7/1990 End: 7/3/2007 22:00 - 00:00 2.00 MOB P PRE Move rig from MPU E-30 to MPU L-06. 7/4/2007 00:00 - 09:00 9.00 RIGU P PRE MIRU from MPU E-30 to MPU L-06. Rig on location at 00:00 07/03/07. 09:00 - 10:30 1.50 RIGU P PRE Install additionallA Valve. Spot Tiger Tank and M/U Hardline. Rig Accept @ 0900-hrs. 10:30-11:00 0.50 DHB P DECOMP M/U Lubricator and pull BPV. T/I = 1500/1700 psi. UD Lubricator. 11 :00 - 14:30 3.50 KILL P DECOMP PJSM. PIT lines to 3500 psi. Vent gas from IA. Mud Pump down. Troubleshoot Mud Pump. Circulate 65 Bbls of 140 degree seawater at 3.5 BPM and 1200 psi while taking returns out the IA through the choke and to the Tiger Tank. Shut in IA and Bullhead 35 Bbls of seawater down the Tubing at 3.5 BPM and 1000 psi. 14:30 - 15:30 1.00 KILL P DECOMP Shut in and monitor well for 1-hr. T/I/O = 150/600/0 psi. Notify MI to make 9.16 ppg brine and deliver onsite. 15:30 - 20:00 4.50 KILL P DECOMP Circulate 580 Bbls of seawater at 4 BPM and 900 psi while taking returns out the IA through the choke and to the Tiger Tank. T/I/O =230/210/0 psi. During well bore displacement operations, tiger tank began to mist resulting in "speckels" of crude/seawater mixture on gravel pad (approx. area of coverage 10' x 20'). Called Environmental to report incident. ACS arrived on site @ 20:00 hrs and scrapped up small amount of gravel into bags using shovel. No additional clean-up required per ACS. 20:00 - 21 :30 1.50 KILL P DECOMP Monitor pressures. T/I/O = 230/200/0 psi. Hang ESP sheave & trunk while kill mud to arrives. 21 :30 - 22:00 0.50 KILL P DECOMP Load 9.16 ppg NaCI brine to pits. 22:00 - 23:00 1.00 KILL P DECOMP Circulate 65 bbls of 9.16 ppg NaCI brine at 3.5 bpm and 830 psi down tubing while taking returns through choke to tiger tank. Shut in IA and bullhead 35 bbls brine down tubing at 3.0 bpm and 1100 psi. 23:00 - 23:30 0.50 KILL P DECOMP Shut in and monitor well for 15 minutes. T/I/O = 100/320/0 psi. 23:30 - 00:00 0.50 KILL P DECOMP Continue to circulate 310 bbls of 9.16 ppg brine at 3.5 bpm down tubing with returns through choke to tiger tank. 7/5/2007 00:00 - 02:30 2.50 KILL P DECOMP Continue to circulate 9.16 ppg brine at 3.5 bpm down tubing I with returns through choke to tiger tank. 02:30 - 03:00 I 0.50 KILL P DECOMP Pumped calculated hole displacement of 375 bbls. Had clean returns with MW out = 9.16 ppg. Shut well in and monitor pressures for 15 minutes. T/I/OA = 0/0/0 psi. Open well to pits. Had slight flow to pits with oil contaminated brine. MW out = 9.14 ppg. Continue circulating additional 1 0 bbls. 03:00 - 03:30 0.50 KILL P DECOMP Shut well in and monitor pressure. T/I/OA = 0/0/0 psi. Open well to check for flow. Continued to have slight flow. Shut well in and adjust MW in pits to 9.2 ppg. 03:30 - 05:00 1.50 KILL P DECOMP Repeat well bore displacement with 365 bbl 9.2 ppg brine at 4 bpm and 980 psi. MW out = 9.2 ppg. Lost 29 bbls to formation during circulation. 05:00 - 05:30 0.50 KILL P DECOMP Shut down pump. Check for flow. T/I/O = 0/0/0 psi but there is still slight flow. 05:30 - 10:00 4.50 KILL P DECOMP Shut in well and adjust MW to 9.3 ppg. Circulate 380 Bbls and see 9.3 ppg returns. Shut in well and monitor for flow. No flow. Printed: 7/24/2007 5:05:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-06 MPL -06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 7/3/2007 Rig Release: Rig Number: Spud Date: 3/7/1990 End: DECOMP Shoot fluid level. T and IA on a slight vac. Fluid level at 100' MD on the Tubing and -100' MD on the IA. The FL on the IA was unclear. I DECOMP Dry Rod TWC per Cameron. Test TWC to 1000 psi from below I by pumping down IA. Unable to obtain 1000 psi, injection rate ,of 670 psi at 3 BPM. Test TWC from above to 3500 psi and chart. N/D Tree and Adapter Flange. N/U BOPE. Filled IA w/ 4 bbl 9.3 ppg brine @ 18:00 hrs. IA fluid level @ 132'. Called AOGCC @ 17:30 hrs to witness test. Test waived by Roger w/AOGCC. Test BOPE 250/3500 psi. Finish test BOPE 250/3500 psi - good test. LD test joint. Drain BOPE. FilllA w/ -5 bbls 9.3 ppg brine @ 01 :30 hrs. IA fluid level @ -165'. RU lubricator w/ Opso Lopso extension. Pull TWC. Monitor tubing - no pressure. Tubing & IA went on slight vacuum. TIIAlOA = 0/0/0. LD lubricator. Fill tubing w/ 5 bbls 9.3 ppg brine. Open IA and fluid u-tubed to surface while tubing fluid level dropped. PJSM. Close blind rams. RU to circulate 9.4 ppg brine down tubing through choke to pits. Test lines to 1000 psi. DECOMP Displace well w/ 375 bbls 9.4 ppg brine. Lost 32 Bbls during circulation. Start displacement and had clean returns to pits. Monitor well. DECOMP PJSM. P/U Landing Joint and XO and M/U to Hanger. BOLDS. Pull 65k-lbs to free Hanger. Once Hanger was free the P/U weight = 75k-lbs. Conduct ESP cable checks per Centrilift. Inspect Hanger which is in good condition. Break and UD Landing joint, XO, and Hanger. Hanger sent to Cameron shop to be redressed and inspected further. DECOMP Pull ESP cable through Sheave and to Spooler. POH w/2-7/8" 6.5" EUE 8rd Tubing while SIB doubles in the Derrick while double displacing. 15 stds OOH @ 1310-hrs. 35 stds OOH @ 1410-hrs. Losses at -12 Bbls/hr. Cut Cable at spliced section and remove reel. 55 stds OOH @ 1700-hrs. 105 stds OOH @ 20:00 hrs w/ -13 bph fluid loss. 140 stds OOH @ 20:00 hrs w/ -9 bph fluid loss. 233 jts out of 237 jts OOH @ 0000 hrs w/ -5-7 bph fluid loss. Finish POOH. Well continuing to take - 10 bph. Cut cable & tail to spooler. BD ESP assembly. Recovered 171 of 171 Lasalle clamps, 4 of 4 Protectolizers, 3 of 3 flat guards. Service GLM's. Well taking - 9 bph. Clean and clear floor. Prepare to run new completion. Exchange cable spools. Pull ESP cable over sheave. M/U and RIH w/ new ESP (Centralizer, PumpMate, Lower and Upper Tandem Seal Sections, Gas Separator, Pump, and Discharge Head). Well taking 5-6 BPH. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE 8rd Tubing from the Derrick. Continuosly filling hole as RIH. Check conductivity of cable and flush 10 Bbls of brine through ESP every 2000'. Losses at 5-6 BPH. 3 bad joints were replaced while RIH. 7/5/2007 05:30 - 10:00 4.50 KILL P 10:00 - 12:30 2.50 DHB P 12:30 - 14:30 2.00 WHSUR P DECOMP 14:30 - 20:00 5.50 WHSUR P DECOMP 20:00 - 00:00 4.00 WHSUR P DECOMP 7/6/2007 00:00 - 01 :00 1.00 BOPSU P DECOMP 01 :00 - 01 :30 0.50 BOPSU P DECOMP 01 :30 - 02:00 0.50 DHB P DECOMP 02:00 - 03:00 1.00 DHB P DECOMP 03:00 - 04:30 1.50 KILL P DECOMP 04:30 - 08:00 3.50 KILL P 08:00 - 09:30 1.50 PULL P 09:30 - 00:00 14.50 PULL P 7/7/2007 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 04:30 4.00 PULL DECOMP 04:30 - 06:00 1.50 RUNCO RUNCMP 06:00 - 10:00 4.00 RUNCO RUNCMP 10:00 - 14:30 4.50 RUNCO P RUNCMP Printed: 7/24/2007 5:05:47 PM .. . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . MPL-06 MPL-06 WORKOVER NABORS ALASKA DRILLING I NABORS 3S rs l~as~cod~' 4.50 I RUNCO~P 0.50 I RUNCOtp 2.50 'I RUNCOt 0.50. RUNCOt 5.001 RUNcot 1.00 I RUNCOMN 0.50 RUNcot 1.50 RUNCO~P I 2.00 RUNCOMP i 5.50 RUNCOMP I 2.00 RUNCOr..!1P 7/7/2007 10:00 - 14:30 14:30 - 15:00 15:00 - 17:30 17:30 - 18:00 18:00 - 23:00 23:00 - 00:00 7/8/2007 00:00 - 00:30 00:30 - 02:00 02:00 - 04:00 04:00 - 09:30 09:30 - 11 :30 11 :30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 22:00 22:00 - 00:00 7/9/2007 00:00 - 01 :00 01 :00 - 02:00 Start: Rig Release: Rig Number: Spud Date: 3/7/1990 End: 7/3/2007 I : I I I 0.50 RNTBH~ P 2.00 RUNCOftlP 1.00 I RNTBH~ P 1.00 WHSUR I P I 1.00 BOPSU~ P 5.00 BOPSU~ P 2.00 BOPSUR P I 1.00 WHSUR P 1.00 WHSUR P I RUNCMP RUNCMP OFAL RUNCMP OFAL RUNCMP OFAL RUNCMP OFAL RUNCMP I RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP TUBHGR RUNCMP TUBHGR RUNCMP RUNCMP POST POST POST POST LaSalle Clamps run on first 9-joints and every other joint thereafter. Ran 2-Flatgaurds and 6 Protectolizers. Fill tubing & flush ESP w/1 0 bbls brine. Checked conductivity w/66 stands in hole @ -4000'. ESP cable failed check. POOH w/ completion looking for pre-existing cable splice @ -2100'. Trouble-shoot and test ESP cable. Found bad pre-existing cable splice @ -2100'. Cut out 3' cable splice. Re-splice cable @ -2100' and test conductivity - good. Continue RIH w/ ESP completion. Continuous hole fill. Fluid loss = 3-6 bph. RIH w/ completion to -4000' @ 0030 hrs. Check conductivity, fill tubing and flush ESP. Fluid loss = 3-6 bph. RIH w/ completion 90 stands @ 0200 hrs. Check conductivity, fill tubing and flush ESP. Fluid loss = 2-5 bph. RIH w/ completion 125 stands @ 0400 hrs. Check conductivity, fill tubing and flush ESP. Fluid loss = 2-3.5 bph. Swap reels in spooler. Splice ESP cable reeHo-reel. Continuous hole fill. RIH w/ ESP on 2-7/8" 6.5# L-80 EUE 8rd Tubing from the Derrick. Continuosly filling hole as RIH. Check conductivity of cable and flush 10 Bbls of brine through ESP every 2000'. Losses at 10 BPH. 3 bad joints were replaced while RIH. LaSalle Clamps run on every other joint thereafter. ESP flushed with 10 Bbls of brine prior to landing. 171 LaSalle Clamps were run. PUMU Hanger per Cameron recommendations. Splice ESP cable at surface and MU to Hanger per Centrilift. ESP cable checked good on conductivity tests. PUMU Land Joint and land Tubing Hanger and Completion. RILOS. UO Landing Joint. P/U oo70k-lbs. S/O = 39k-lbs. Set TWC w/ dry rod. Test TWC from above to 1000 psi and chart. Attempt to test TWC from below to 1000 psi and chart. Unable to reach 1000 psi on test from below. Injection rate of 3 BPM at 570 psi. Flush stack and choke manifold with fresh water. Blow down mud lines & choke. NO BOPE to cradle. NU adaptor flange and tree. Make final ESP check (final readings: Pi-3357, Ti-170, Cz-1 0115, Cf-18379, Cla-0.014, Clp-O, Vib-O). Pressure test adaptor flange to 5000 psi for 30 charted minutes per Cameron. Fill tree with diesel. RU and pressure test tree to 5000 psi for 10 charted minutes. Pull TWC w/lubricator. Set BPV. Secure tree and cellar. Release rig @ 0200 hrs 07/09/07. Printed: 7/24/2007 5:05:47 PM RE: FW: MPL-06 (PTD #1900100) and MP4i (PTD #2040390)... Tom, The lAP on C-43 runs 240 - 340 psi and the lAP on L-06 runs 300 - 400 psi. Please let me know if you need anything else. Thanks, S(~NED MAY 0 7 2007 JRC From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, May 03, 2007 10:56 AM To: MPU, Well Operations Supervisor Subject: Re: FW: MPL-06 (PTD #1900100) and MPC-43 (PTD #2040390) ESP Completion with lAP> 2000 psi. Thanks John. What is the annulus pressure normally when everything is operating? Tom MPU, Well Operations Supervisor wrote, On 5/3/2007 10:28 AM: Hi Tom, Just an FYI, we did get the compressor back on line at Milne Point As a result the MPL-06 and MPC-43 are back on line and the IA pressures are back down to below 2000 psi. If you have any questions, please don't hesisitate to let me know. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 From: Thomas Maunder (mailto:tom maunder@admin.state.ak.us] Sent: Friday, April 06, 2007 8:24 AM To: MPU, Well Operations Supervisor Subject: Re: MPL-06 (PTD #1900100) ESP Completion with lAP> 2000 psi. John, It is up to you all how to manage the pressure. In this case the cause of the pressure is known, it is being observed and continued build up is the result of direct communication with the reservoir and lof3 5/3/2007 2:45 PM REo FWo MPL-06 (PTD #1900100) and MP4i(PTD #2040390)... . no production. This is a much different case than managing pressure in an annulus due to a communication problem or well start up. I looked at the Sustained Casing Pressure Order (CO 496) for Milne. It appears that the "action pressures" for an IA are 2000 psi or 45% of burst. You have notified me of the pressure at or over 2000 psi. It would seem that based on the pressure build up examination that the SICP would likely remain below the 45% threshold. Ifthe 7" casing is 26#, NIL-80 with 7240 published burst, 45% would be 3258 psi. If it 7" 29#, NIL-80 45% is 3672 psi. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 4/6/20077:57 AM: Hi Tom, Please see the attached. It does appear that the well could build-up to >2500 psi. if the pressure buildup doesn't begin to stabilize. If the surface pressure does exceed 2500 psi., our plan is to bullhead dead crude down the IA to knock down the pressure until we can bring the well back on line. Please let me know if you have any questions or if you would like to discuss in further detail. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 From: Thomas Maunder (mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, April 04, 2007 1:12 PM To: MPU, Well Operations Supervisor Subject: Re: MPL-06 (PTD #1900100) ESP Completion with lAP> 2000 psi. Hi John, I did get your message and got your call. Looking at the buildup, has anyone projected how high the pressure could build with another month SI? I look forward to your reply. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 3/31/2007 12:02 PM: Hi Tom, MPL-06 is a packerless, high GOR ESP completion that was shut-in on 3/12/07 due to reduced gas handling capacity at our Milne Point processing facility. Our reduced gas handling capacity is due to maintenance work on one of our large gas injection compressors. Due to the wells high GOR, when the well is SI for an extended period of time gas pressure on the IA builds due to 20f3 5/3/20072:45 PM RE: FW: MPL-06 (PTD #1900100) and MPC-43 (PTD #2040390)... gas breakout on top o! fluid in the IA. Once we bring the weilck on-line, the IA pressure will relieve through the orifice in the tubing. Current pressure on the IA is 2020 psi. Our plan is to have our compressor back on line in early May 2007. During the interm, we request permission to continue to monitor the IA pressure and to not pump a kill fluid into the IA unless the pressure increases to over 2500 psi. Please let me know if you have any questions or if you would like to discuss in further detail. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907 -670-3330 «MPL-06.ZIP» «MPL-06 TIO.ZIP» 3 of3 5/3/20072:45 PM Tree:WKM 2 9/16" Wellhead:11" 5M WKM 2.5" CIW BPV profile 20" Conductor Casing ~ Halliburton Has stage I 1885' I cementer .. 9-5/8" 36#, J-55 BTTS csg 6314'1 down squeezed 8/25/91 . KOP @1000 Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00592 bpf) 7", 26#, L-80 Buttress casing (drift 10 = 6.151", cap. = .0383 bpf) RA tag at 10303' Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I-Prop. 28,603# 12/18 I-Prop. screened out w/14,082# 12/18 I-Prop. above perfs. Perforation Summary: Ref 10g:SWS CCL log dated 3 May 90 Size SP Interval (TVD) 4.5" 5 10566'-10593' 7002'-7017' 4.5" 5 10632'-10662' 7042'-7058' 4.5" 5 10678'-10693' 7067'-7076' 4.5" 5 10714'-10724' 7089'-7094' 4.5" 5 10800'-10821' 7139'-7152' 4.5" 5 10834'-10878' 7166'-7186' 4.5" 5 10900'-10904' 7200'-7202' Mid-perf TVO - 7102' Mid-perf MO - 10735' PBTO TVO - 7255' DATE 11/27/90 9/24/93 REV. BY MPL-06 COMMENTS Orig. elev. = 55.0' (Pool Orig. GL elev. = 21.0' (Pool OF to GL = 34' Cameo 2 7/8" x 1" sidepocket KBMM GLM 10 2.38" [TIÐ Camco 2 7/8" x 1" I I side pocket KBMM GLM 10,235' 102.38" 2-7/8" HES XN nipple ( 2.205" 10 ) 10,378'1 Centrilift Pumps I 1 0 392'1 41GC1150,159GC1150,19GC8200 ' GPMTAR 1:1 Tandem Gas Separator I 10422' I GRSXTBARH6 .'. intake TVO 16919'1 Centrilift tandem seal section I GSB3DB UT/LT IL H6 HL PFSA 10,430' AFLAS/HSN Centrilift 562 series Motor 190 HP KMH 2415 V /48 A I 10,444'1 Centrilift PumpMate and 110,461'1 Six Fin Centralizer . Gauge TVD 6941' 8 - joints of tubing 2-7/8" Bull plug 10,702'1 Slickline tag 11/19/98 7" Float collar T' csg. shoe 10956' 10985' 11068' Milne Point Unit WELL L-06 API NO: 50-029-22003 04/10/01 6/16/05 RWO Rig 4 7/16/98 RWO Nabors 4-ES MOO ESP RWO / Calvins Nabors 4-ES B. Hasebe ESP RWO Nabors 4-ES L. Hulme ESP Replacement Nabors 4ES BP EXPLORATION (AK) RE: L-06 Pressure e e In answering the question, "what pressure will we see in a month's time", I did a back of the envelope calculation. This is a more aggressive assumption. The l-06 pressure data hasn't yet flattened out, so I assumed that it would continue along a linear trend. If this were the case, we could see the pressure rise very quickly and approach 2570 psi at the surface by the end of the month. Therefore, we need to watch this well and be prepared to bullhead kill fluid. Katharine. «Linear L-06 extrapolation.xls» From: McLeod, Jennifer D Sent: Thursday, April 05, 2007 5:32 PM To: Leonard, Nathan Cc: Chesher, James R; Nash, Katharine (Trafford); MPU, Well Operations Supervisor Subject: RE: L-06 Pressure Nathan, The connection between C-08i and l-06 is baffled as evidenced by the high pressure at C-08i (4600 psi) and the long interaction time for the gas slugs. This injector doesn't clearly support any other wells, so I would agree with shutting MPC-08i in and collecting PFO data until L-06 comes back on line. Jennifer From: Leonard, Nathan Sent: Thursday, April 05, 2007 1:54 PM To: Chesher, James R; MPU, Well Operations Supervisor Cc: Nash, Katharine (Trafford) Subject: RE: L-06 Pressure C-08i is the injector that provides support to the L-06 producer. It is currently injecting 407 BWIPD. Can't go much lower without shutting the well in. The bad news is that there is a gas slug from the C-08i that still needs to work through the L-06. This might cause the IA pressure to build again if we have to kill the well. Jennifer - This is more of your neighborhood. What are your thoughts on appropriate actions to take. Thanks Nathan 10f3 4/6/2007 11 :51 AM RE: L-06 Pressure e e From: Chesher, James R Sent: Thursday, April 05, 2007 1:44 PM To: Leonard, Nathan; MPU, Well Operations Supervisor Cc: Nash, Katharine (Trafford) Subject: RE: L-06 Pressure Katharine, Nathan, Thanks for looking at this and coming to a conclusion so quickly. Just so we're all clear, Tom Maunder (the AOGCC PE) asked how high the well could build with another month SI. The pressure you calculated of 2747psi at pump depth, 2305psi at surface - that was an ultimate pressure that the well could build to. Would we expect the pressure to have pretty much got there after a month? Also, do we have other injectors on in that hydraulic unit that might continue to fuel a build-up? Thanks again, James From: Leonard, Nathan Sent: Thursday, April 05, 2007 1:32 PM To: MPU, Well Operations Supervisor Cc: Chesher, James R; Nash, Katharine (Trafford) Subject: FW: L-06 Pressure Thanks Katherine. John, If the welllA hits 2500 psi I would have no problem bullheading kill fluid. The L-06 isn't a great oil producer so I wouldn't worry about harming the near well bore by pushing any trash into the formation. Would you blow down the IA before attempting to kill? If not you might have some high fA pressures starting the kill procedure. Let us know if we can do anything else to help. Nathan From: Nash, Katharine (Trafford) Sent: Thursday, April 05, 2007 11:48 AM To: Leonard, Nathan Cc: Chesher, James R Subject: L-06 Pressure 20f3 4/6/2007 11 :51 AM RE: L-06 Pressure e e Nathan, Using the IFIX data, I calculated a P* (approx. pressure at ESP) of 2747 psi which corresponds to a pressure at the surface 2305 psi. In calculating the surface pressure, I assumed that the wellbore is filled with gas. This offers the most conservative pressure determination. Katharine. Katharine Nash BP EXPLORATION ALASKA Milne Point ACT Business Unit (Office 436D) 900 East Benson Blvd. Anchorage, AK 99508 'Ielephone: (+I) 907 5644748 Fax: 907 564 4440 Katharinc.Nash@BP.com L-06 Pressure.eml Linear L-06 extrapolation.xls 30f3 4/6/2007 11 :51 AM 3/9/2007 3/19/2007 3/29/2007 4/8/2007 4/18/2007 , STATE OF ALASKA) ALASKA v}L AND GAS CONSERVATION COlvlN1ISSION"", 'I, ,I', :,1 "" REPORT OF SUNDRY WELL OPERATION1S\,i 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program Change:Qut E$P" ' o Suspend 0 Operation Shutdown 0 Perforate aD Other aD Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well aD Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 190-010 6. API Number: 50-029-22003-00-00 99519-6612 56' 9. Well Name and Number: MPL-06 8. Property Designation: ADL 047434 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11091 feet true vertical 7313 feet Plugs (measured) None Effective depth: measured 10983 feet Junk (measured) None true vertical 7248 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' 1740 750 Surface 6279' 9-5/8" 6314' 4590' 3520 2020 Intermediate Production 11033' 7" 11068' 7299' 7240 5410 Liner SC~ANNED JUL 0 7 2.0Œj Perforation Depth MD (ft): Perforation Depth TVD (ft): 10566' - 10904' 7001' - 7202' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8",6.5# L-80 10466' None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFt JUL 072005 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 561 14. Attachments: 0 Copies of Logs and Surveys run aD Daily Report of Well Operations 181 Well Schematic Diagram 178 299 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 333 306 Printed Name Sondra Stewman Sign~"'ý)·Å.£Jr--- Form 1 0-404 Revised 04/2004- Title Technical Assistant Phone ,5644 7RO U 1"< I G ! ¡~ 1-\ L I",,'" , Prepared By Name/Number: DateU L -0 lôCF)Sondra Stewman, 564-4750 Submit Original Only Tree:WKM 2 9/16" 1 Wellhead:11" 5M V'-J,..Ñ1 2.5" CIW BPV profile 20" Conductor Casing I 112'1 A Halliburton Hos stage I 1885' I ( cementer 9-5/8" 36#, J-55 BTTS csgl 6314' I ~ down squeezed 8/25/91 KOP @1 000 Max Hole Angle: 56.60° @ 4457' Hole angle through perfs. = 55 deg. 2 7/8" 6.5 ppf, l-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf) 7", 26#, l-80 Buttress casing (drift ID = 6.151 ", cap. = .0383 bpf) RA tag at 1 0303' ~ Stimulation Summary: 6/15/91 Frac, All zones 169,139# of 16/20 I-Prop. 28,603# 12/18 I-Prop. screened out w/ 14,082# 12/18 I-Prop. above perfs. Perforation Summary: Ref 10g:SWS CCl log dated 3 May 90 Size SPF Interval (TVD) 4.5" 5 10566'-10593' 7002'-7017' - 4.5" 5 10632'-10662' 7042'-7058' 4.5" 5 10678'-10693' 7067'-7076' 4.5" 5 10714'-10724' 7089'-7094' 4.5" 5 10800'-10821' 7139'-7152' 4.5" 5 10834'-10878' 7166'-7186' - 4.5" 5 10900'-10904' 7200'-7202' Mid-perf TVD - 7102' J Mid-perf MD - 10735' PBTD TVD - 7255' DATE MPL-06 ~ ~ ~ ~ , , ~ ~ ~ ~ ~ ~ , I r , ~ ~ I , í ~i f,:;;:,:,IIJ,(I'!¡,IM,! ~,',',:.j1"" r ;¡:¡~~+: ~~@ ~:!; . ·,',',·,'.',·.'.',W.,',',',· Or; '\>F elev. = 55.0' (Pool) On~.Gl elev. = 21.0' (Pool~ D F to Gl = 34' .. t. ~: I ~ 2005 Cameo 2 7/8" x 1" sidepocket KBMM GlM ID 2.38" I 138' I ~ Camco 27/8" x 1" sidepocket KBMM GlM I 10,235' I 102.38" 2-7/8" HES XN nipple I 10,378'1 ( 2.205" ID ) Centrilift Pumps I 1 0 392' I 41 GC1150, 159GC1150, 19GC8200 ' GPMTAR 1:1 Tandem Gas Separator I 10 422' I GRSXTBARH6 ' intake TVD I 6919' I Centrilift tandem seal section GSB3DB UT/L T IL H6 HL PFSA 10,430' I AFLAS/HSN Centrilift 562 series Motor 190 HP KMH 2415 V 148 A I 10,444' I Centrilift PumpMate and I 10,461' I Six Fin Centralizer Gauge TVD 6941' 8 - joints of tubing 2-7/8" Bull plug 10,702'1 Slickline tag 11/19/98 10956' 7" Float collar 10985' .. 7" csg. shoe 11068' 11/27/90 9/24/93 11/20/98 04/10101 6/16/05 REV. BY COMMENTS Drill Pool Arctic 10217/20/91 Comp EWS RWO Rig 417/16/98 RWO Nabors 4-ES MOO ESP RWO I Calvins Nabors 4-ES B. Hasebe ESP RWO Nabors 4-ES L. Hulme ESP Replacement Nabors 4ES Milne Point Unit WElll-06 API NO: 50-029-22003 BP EXPLORATION (AK) ) ) BP EXPLORATION ,Operations .Summary, Repor'1,~u,::J'i::l'i zoo~) Paget of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-06 MPL-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/14/2005 Rig Release: 6/17/2005 Rig Number: 4ES Spud Date: 3/7/1990 End: 6/17/2005 Date From- To Hours Task Code NPT Phase Description of Operations 6/14/2005 15:00 - 16:00 1.00 RIGD P PRE RID Rig & equip. Scope down & Lower derrick 16:00 - 17:00 1.00 RIGD P PRE Move rig & equip off MPF-53 well. 17:00 - 18:30 1.50 MOB P PRE Move rig sub, pits & pipe shed from MPF-53 to MPL-06. 18:30 - 19:30 1.00 MOB P PRE Layout Herculite & matting boards. Spot in Rig sub over MPL-06 well. Spot in pits & pipe shed. 19:30 - 21 :00 1.50 MOB P PRE Rig equip. Raise & scope up derrick. 21 :00 - 22:30 1.50 PULL P DECOMP ACCEPTED RIG @ 2100 hrs. R/U lines to tiger tank & tree. Take on seawater. 22:30 - 23:00 0.50 PULL P DECOMP Hold PJSM & Pre-spud meeting wi all hands. Pressure test lines to 3500 psi. 23:00 - 00:00 1.00 KILL P DECOMP Open well. SITP 1560 psi, SICP 1590 psi. Begin circulating hot seawater. Pump @ 2.5 BPM, 1500 psi. 6/15/2005 00:00 - 03:00 3.00 KILL P DECOMP Con't to circulate well wi 8.5 ppg seawater. Pumped @ 2.5 BPM , then increased to 3 BPM. Pressure went from 1500 to 1850 psi. Pumped total of 470 bbls. SID. Had oil & gas returns, no seawater to surface. Recovered 275 bbls of oil in tiger tank. Monitor pressure. 03:00 - 06:00 3.00 KILL P DECOMP ,Monitor well. SITP 1080 psi. SITP dropped to 950 psi. EST kill wt fluid would be 11.4 ppg. Discuss with MPU Well Ops Supv about shutting in MPL-16ai 'nj Well. 06:00 - 12:00 6.00 KILL P DECOMP Continue to monitor Well. Pressure stabilize at 930 psi. Pad Operator SI L-16ai in at 07:00 hrs. Saw a SITP drop of 30 psi in 20 minutes. Continue to monitor. Discuss shutting in C-19i with MPU. SITP now at 890 psi with just L-06i shut in. SI C-19i at 08:30 hrs. Truck heavy Brine from MPU storage to Pits to mix into KWB. At 12:00 hrs SITP is at 840 psi with L-16ai and C-19i SI. Total loss in BHP for 5 hrs was 90 psi. 12:00 - 15:00 3.00 KILL P DECOMP Bring Pit volume up to 11.1 Iblgal. Circulate and kill Well with 11.1 Iblgal Brine at 3 bpm/1300 psi. End at 3 bpm/800 psi. Route returns to Pits. Returns weight 11.1 Iblgal. Shut down pump. Monitor Well Dead. 15:00 - 16:00 1.00 WHSUR P DECOMP Set and test TWC. Blow down Lines. Cameron Service rep re-pack all Lock-down Nuts. 16:00 - 17:00 1.00 WHSUR P DECOMP Nipple down Production Tree. 17:00 - 18:00 1.00 BOPSUF P DECOMP N/U DSA & test spool.. 18:00 - 19:30 1.50 BOPSUP P DECOMP N/U BOPE. 19:30 - 22:30 3.00 BOPSUP P DECOMP Pressure test BOPE as per AOGCC I BP requirements. LP 250 psi, HP 3500 psi. BOP test witnessed by John Crisp wi AOGCC. No failures, all equip tested Good. 22:30 - 23:00 0.50 BOPSUR P DECOMP NID test equip. Drain BOP stack. P/U lubricator. 23:00 - 23:30 0.50 WHSUR P DECOMP Pull TWC. monitor well, well dead. M/U landing jt. BOLDS. Pull hanger to floor. P/U wqt 78K. UD hanger & landing jt. 23:30 - 00:00 0.50 PULL P DECOMP POOH wi 27/811 ESP completion. 6/16/2005 00:00 - 01 :00 1.00 PULL P DECOMP Can't to POOH & stand back 2 7/811 ESP completion. 01 :00 - 02:00 1.00 PULL DECOMP Change out reels in spooling unit. 02:00 - 05:30 3.50 PULL DECOMP Con't to POOH & stand back 2 7/811 ESP completion. 05:30 - 07:00 1 .50 PULL P DECOMP Break out inspect & UD ESP. Pump was locked up. 07:00 - 09:00 2.00 PULL P DECOMP Clear and Clean Rig floor. Put used ESP sections in shipping boxes. Remove new ESP sections from shipping boxes and stage in proper running order in Pipe shed. 09:00 - 09:30 0.50 RUNCOIVP RUNCMP Service Rig. Finish rigging up to handle ESP Assembly. 09:30 - 12:00 2.50 RUNCOIVP RUNCMP Pick-up and service new ESP Assembly. 12:00 - 17:30 5.50 RUNCOIVP RUNCMP Start RIH with ESP Assembly on 2 7/8" Tubing. Pump thru Printed: 6/20/2005 11 :09:52 AM ') ) BP EXPLORATI.ON Operations Sljm mé1ryR~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/16/2005 6/17/2005 MPL-06 M PL -06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 12:00 - 17:30 5.50 RUNCOMP RUNCMP 17:30 - 20:00 2.50 RUNCOMP RUNCMP 20:00 - 21 :30 1.50 RUNCOMP RUNCMP 21 :30 - 22:00 0.50 RUNCOMP RUNCMP 22:00 - 00:00 2.00 RUNCOMP RUNCMP 00:00 - 01 :00 1.00 RUNCOMP RUNCMP 01 :00 - 03:00 2.00 BOPSUP P RUNCMP 03:00 - 04:30 1.50 WHSUR P RUNCMP 04:30 - 06:00 1.50 WHSUR P RUNCMP Start: 6/14/2005 Rig Release: 6/17/2005 Rig Number: 4ES Spud Date: 3/7/1990 End: 6/17/2005 'Description of Operations ESP & test cable every 2000'. Change out spools. Make reel to reel splice. Can't to RIH wi ESP on 2 7/8" tubing. Pump thru ESP & test cable every 2000'. M/U landing jt & tubing hanger. Install penetrator. Make field splice. Plug into penetrator. Test same. Land hanger. RILDS. Test hanger seals. LID landing jt. Set & test TWC. N/D BOPE. N/U & test tree & hanger void to 5000 psi, OK. P/U lubricator & pull TWC. Install BPV. UD lubricator. Secure tree & cellar. RELEASE RIG @ 0600 hrs. RDMO to MPL-28a. Printed: 6/20/2005 11 :09:52 AM .... STATE OF ALASKA ...... ALASKA ,.,,L AND GAS CONSERVATION COMM,,.,,¢ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: r"lOperation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development 56' KDB [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2119' SNL, 318' EWL, SEC. 08, T13N, R10E, UM MPL-06 At top of productive interval 9. Permit Number / Approval No. 190-010 2127' NSL, 318' EWL, SEC. 04, T13N, R10E, UM 10. APl 'Number At effective depth 50-029-22003-00 2319' NSL, 551' EWL, SEC. 04, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2356' NSL, 605' EWL, SEC. 04, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 11068 feet Plugs (measured) true vertical 7299 feet Effective depth: measured 10983 feet Junk (measured) true vertical 7248 feet Casing Length Size Cemented MD TVD Structural Conductor 82' 13-3/8" 485 sx Permafrost 'C' 115' 115' Surface 6281' 9-5/8" 1569 sx PF 'E', 410 sx Class 'G' 6314' 4589' Intermediate Production 11035' 7" 328 sx Class 'G' 11068' 7302' Liner Perforation depth: measured 10566'- 10593', 10632'- 10662', 10678'- 10693', 10714'- 10724', 10800' o 10821', 10834' - 10878', 10900' - 10904' true vertical 7001' - 7018', 7041' - 7058', 7067' - 7076', 7088' o 7094', 7139' - 7152', 7160' - 7186', 7199' - 7202' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 10448' RECEIVED Packers and SSSV (type and measured depth) None MAY 0 i ~uu ~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Alaska Oil & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data Oil. Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service _ 17. I hereby certify that the fore_.going is true and c(~rrect to the best of my knowledge ' Signed Sondr~~~.~x-~ ¢- T,tle' Technical Assistant Date/~'~..)-C,/ -- L.~l Prepared By Name/Number: Sondra Stewman. 564-4750 Form 10-404 Rev. 06/15/88 Submit In Du i i i i:OperatiOns SUmmary Report Legal Well Name: MPL-06 Common Well Name: MPL-06 Spud Date: 3/7/1990 Event Name: WORKOVER Start: 4/6/2001 End: 4/9/2001 Contractor Name: NABORS Rig Release: 4/9/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES :: :Oate~: Fr°m;~To iH°urs :TaSk - Phase Description of Operations 4/6/2001 06:00 - 17:00 11.00 RIGU PRE MOVE RIG FROM MPI-02 & RIG UP & SAFE OUT EQUIPMENT. !RAISE DERRICK & LEVEL ALL EQUIPMENT BERMED. 17:00 - 22:00 5.00 KILL DECOMP !SET TIGER TANK & RIG LINES TO SAME & TEST LINES TO 3500 PSI. & PULL BPV. TBG. =1320 PSI. ANNULUS = 1320 PSI. 22:00 - 00:00 2.00i KILL DECOMP CIRC. 8.7 PPG. BRINE 4/7/2001 00:00 - 06:00 6.00 KILL DECOMP CONT. CIRC. 8.7 BRINE & MONITOR WELL CONT. TO CIRC TO WORK INFLUX & SHUT DOWN AND MONITOR & WELL FLOWING & RAISING WT. TO 8.9 PPG. 106:00 - 07:00 1.001 KILL DECOMP MONITOR WELL WITH 8.9 PPG FLUID WEIGHT 07:00 - 07:30 0.50 WHSUR DECOMP SET 'rwc VALVE AND TEST TO 3500 PSI 07:30 - 09:00 1.50 WHSUR DECOMP NIPPLE DOWN BOP AND CHECK LOCK DOWN SCREWS 09:00 - 15:00 6.00 WHSUR [DECOMP NIPPLE UP BOP EGUIPMENT. CHANGE OUT BLIND RAMS TO SHEAR/BLIND RAMS. 15:00 - 17:30 2.50 WHSUR I DECOMP TEST BOPE TO 250/3500 PSI AND ANNULAR TO 250/2500 PSI. FUNCTION TEST BOPE AND ACCUMMULATOR TEST. BOPE TEST WITNESS WAIVED BY JOHN SPAULDING OF AOGCC 17:30 - 18:30 1.00 WHSUR DECOMP PU LUBRICATOR/PULL TWCV / LD LUBRICATOR 18:30 - 19:30 1.00 PULL DECOMP PU LANDING JT.AND MU IN HANGER/BOLDS AND PULL HANGER TO THE FLOOR/LD HANGER. PU WT 78 K 19:30 - 21:30 2.00 PULL DECOMP ATTACH ESP CABLE TO SPOOL AND POH TO 2800' W/ESP COMPLETION 21:30 - 22:00 0.50 PULL DECOMP CHANGE OUT SPOOL IN SPOOLING UNIT 22:00 - 00:00 2.00 PULL DECOMP !POH with ESP COMPLETION 4/8/2001 00:00 - 01:30 1.50 PULL DECOMP POH with ESP COMPLETION 01:30 - 05:00 3.50 PULL DECOMP LD PUMP & MOTOR/CHANGE OUT SPOOL IN UNIT/LD TAIL ASSEMBLY 05:00 - 06:00 1.00 PULL DECOMP R/D FLOOR & RU TO RUN NEW PUMP !06:00 - 08:30 2.50 RUNCOr COMP MAKE UP AND SERVICE ESP '08:30 - 13:30 5.00 RUNCO~ COMP TIH WITH ESP COMPLETION ASSEMBLY TO 7,900' 13:30 - 16:00 2.50 RUNCO~ COMP MAKE MID RUN SPLICE & CHANGE OUT SPOOL 16:00 - 19:30 3.50 RUNCOI~4 COMP TIH WITH ESP COMPLETION ASSEMBLY 19:30 - 22:30 3.00 RUNCOI~I COMP PICK UP LANDING JOINT / MU HANGER AND INSTALL PEN. / ATTACH FIELD CONN & TEST / LAND HANGER. RILDS PICK UP WT. 75 K AND DOWN WT. 44 K. 22:30 - 23:00 0.50 WHSUR COMP SET TWCVALVE & TEST TO 3,500 PSI 23:00 - 00:00 1.00 WHSUR COMP NIPPLE DOWN BOP i4/9/2001 00:00 - 02:00 2.00 WHSUR COMP nu tree & test same to 5000 psi. & pull twc & set bpv. 02:00 - 03:00 1.00 WHSUR COMP secure tree & celllar area & Release rig @ 0300 Hrs. 41912001 Printed: 5/1/2001 10:04:58 AM !?oo[o0 MEMORANDUM TO: THRU' Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 22, 2000 FROM: John Crisp, ~ SUBJECT: Petroleum InspeCtor Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BP×'s Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe wOrking conditions & minimal SVS failures. Wellhouses are clean~& in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report. Attachments' SVS MPU L pad 12-22-00jc CC; NON-CONFIDENTIAL SVS MPU L Pad 12-22-OOjc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator psi: LPS 140 Date: 12/22/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorC¥CLE L-01 1840050i L-02 1900060 140 100 90 P P OIL L-03 1900070 'L'04 1900380' 1401 100 105 P P OIL L-05 1900390 140 100 100~ P P OIL L-06 1900100 1401 100 100 P P OIL L-07 1900370 140 100 100 P P OIL L-08 1901000 4000 2000 1950 P P WAG L-09 1901010 L-11 1930130 140 100 115 P P OIL L-12 i 1930110 140 100 100 P P OIL L-13 1930120 140 100 100 P P OIL L-14 1940680 140 100 95 P P OIL L-15 1940620 L-16A 1990900 L-17 1941690 L-20 1971360 140 100 100 P P OIL L-25 1951800 140 100 105 P P OIL L-28A 1982470 140 100 110 P P OIL L-29 1950090 140 100 95 P P OIL L-32 1970650 140 100 100 P P OIL L'33 1971050 · L-35 1970920 140 100 105 P P OIL L-36 1971480 140 100 105 P P OIL L-37A 1980560 L-40 1980100 140 100 100 P P g-~\~~ -k~ ~-~ \'~ OIL L-45 1981690 140 100 105 P ' P ~' OIL L-34 1970800 4000 2000 1900 P 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% Remarks: 12/26/00 Page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLr~ 12/26/00 Page 2 of 2 SVS MPU L Pad 12-22-OOjc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 E E PL E W M A T E R IA 1~ U N D ER ,THIS MARKER STATE OF ALASKA ALASKA O,_ AND GAS CONSERVATION COMIv,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I~ Operation Shutdown [~Stimulate [] Plugging [~ Perforate ~] Pull Tubing E~Alter Casing ~:] Repair Well [~ Other Change Out ESP 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2119' SNL, 318' EWL, SEC. 08, T13N, R10E, UM At top of productive interval 2127' NSL, 318' EWL, SEC. 04, T13N, R10E, UM At effective depth 2319' NSL, 551' EWL, SEC. 04, T13N, R10E, UM At total depth 2356' NSL, 605' EWL, SEC. 04, T13N, R10E, UM Type of well: [~ Development r-~ Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) 56' KDB 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-06 9. Permit Number / Approval No. 90-10 029-22003 10. APl Number 50-029-22003 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 11068 feet true vertical 7302 feet Effective depth: measured 10983 feet true vertical 7250 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 82' 13-3/8" 6281' 9-5/8" Plugs (measured) Junk (measured) Cemented:._ v..; '"'- '- MD 485 sx Permafrost 'C' 115' 1569 sx PF 'E', 410 sx Class 'G' 6314' 11035' 7" 328 sx Class 'G' 11068' TVD 115' 4589' 7302' Perforation depth: measured true vertical 10566'-10593', 10632'-10662', 10678'-10693', 10714'-10724', 10800'-10821', 10834'-10878', 10900'-10904' 7002'-7017', 7041'-7058', 7067'-7076', 7088'-7094', 7139'-7152', 7166'-7186', 7199'-7201' Tubing (size, grade, and measured depth) 2-7/8", 26#, L-80, 8rd EUE tubing to 10702' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments E~ Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [~Oil []Gas [~Suspended Service 17. I hereby certify that the fo/regoing J~rrect to the best of my knowledge Terrie Hubble 'j . . .. Title Technical Assistant III Prepared By Name/Number: ...... Form 10-404 Rev. 06/15/88 Terrie Hubble, 564-4628 ,, Submit In Duplicate Progress Report Facility M Pt L Pad Well MPL-06 Page 1 Rig ~ ,M~ q~;~' Date 10 February 99 Date/Time 12 Jul 98 13 Jul 98 14 Jul 98 15 Jul 98 00:00-06:00 06:00-08:00 08:00-10:00 10:00-15:00 15:00-15:30 15:30-17:30 17:30-18:00 18:00-19:00 19:00-21:00 21:00-23:30 23:30-02:00 02:00-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-21:30 21:30-03:30 03:30-06:00 06:00-06:30 06:30-09:30 09:30-11:00 11:00-12:30 12:30-17:00 17:00-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:30 09:30-10:30 10:30-12:00 12:00-13:00 Duration 6hr 2hr 2hr 5hr 1/2 hr 2hr 1/2 hr lhr 2hr 2-1/2 hr 2-1/2 hr 4hr 1/2 hr 2hr 2hr llhr 6hr 2-1/2 hr 1/2 hr 3hr 1-1/2 hr 1-1/2 hr 4-1/2 hr llhr 2hr 1/2 hr 1/2hr 1-1/2 hr lhr lhr 1-1/2 hr lhr Activity Rig moved 100.00 % Fill pits with Seawater Bullhead well Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Retrival run Circulated at 10566.0 ft Conducted slickline operations on Slickline equipment - Setting run Bullhead well Removed Xmas tree Installed BOP stack Tested BOP stack Retrieved Tubing hanger Functioned Retrievable packer Packer worked at 609.0 ft Laid down 632.0 ft of Tubing Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Ran Tubing in stands to 5106.0 ft Held safety meeting Ran Tubing in stands to 10858.0 ft Reverse circulated at 10962.0 ft Reverse circulated at 10962.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 10444.0 ft Installed Tubing hanger Held safety meeting Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 75.000 bbl of Diesel Rigged down High pressure lines Progress Report Facility M Pt L Pad Well MPL-06 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 18 Nov 98 19 Nov 98 20 Nov 98 21 Nov 98 06:00-06:15 06:15-07:00 07:00-08:30 08:30-13:30 13:30-15:00 15:00-16:00 16:00-16:30 16:30-18:30 18:30-18:45 18:45-19:00 19:00-19:30 19:30-20:00 20:00-20:30 20:30-22:15 22:15-22:30 22:30-22:45 22:45-23:30 23:30-01:00 01:00-03:00 03:00-04:00 04:00-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-13:00 13:00-14:30 14:30-16:30 16:30-18:30 18:30-19:00 19:00-20:00 20:00-23:00 23:00-00:00 00:00-00:45 00:45-01:00 01:00-01:30 01:30-02:00 02:00-02:30 02:30-02:45 02:45-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-11:30 11:30-16:00 16:00-18:30 18:30-21:00 21:00-21:30 21:30-23:30 23:30-00:00 00:00-01:30 Duration 1/4 hr 3/4 hr 1-1/2 hr 5hr 1-1/2 hr lhr 1/2 hr 2hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1-3/4 hr 1/4 hr 1/4hr 3/4 hr 1-1/2 hr 2hr lhr 1/2hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 6-1/2 hr 1-1/2 hr 2hr 2hr 1/2 hr lhr 3hr lhr 3/4 hr 1/4 hr 1/2 hr 1/2hr 1/2 hr 1/4 hr 3-1/4 hr 1/4 hr 1/4 hr lhr lhr lhr 2hr 4-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr Activity Held safety meeting Rigged down Fluid system Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Installed High pressure lines Retrieved Hanger plug Fill pits with Seawater Held safety meeting Tested High pressure lines Bleed down well Circulated closed in well at 10308.0 fi Bullhead well Circulated closed in well at 10308.0 ft Flow check Installed Hanger plug Removed Xmas tree Installed BOP stack Tested BOP stack Retrieved Hanger plug Installed Tubing retrieval string Retrieved Tubing hanger Rigged up Completion string handling equipment Pulled Tubing in stands to 10330.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 58.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rig waited: Orders Ran Tubing in stands to 10290.0 ft Singled in drill pipe to 10972.0 ft Circulated at 10948.0 ft Laid down 31.5 fi of 3-1/2in OD drill pipe Rig waited: Assessed situation Laid down 364.0 ft of 3~1/2in OD drill pipe Reverse circulated at 10543.0 ft Laid down 94.5 ft of 3-1/2in OD drill pipe Pulled Tubing in stands to 2889.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 0.0 ft Rigged up Completion string handling equipment Serviced Completion string sub-assemblies Serviced Electrical submersible pumps Ran Tubing in stands to 7500.0 ft Serviced Electric cable Ran Tubing in stands to 10682.0 ft Installed Tubing hanger Serviced Electric cable Ran Tubing on landing string to 10702.0 ft Removed BOP stack Progress Report Facility M Pt L Pad Well MPL-06 Rig Nabors 4ES Page 2 Date 10 February 99 Date]Time 01:30-02:30 02:30-03:30 03:30-03:45 03:45-04:00 04:00-04:30 04:30-05:00 05:00-06:00 Duration lhr lhr 1/4 hr 1/4 hr 1/2 hr 1/2 hr lhr Activity Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Installed High pressure lines Freeze protect well - 14.000 bbl of Diesel Removed High pressure lines Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 October 18, 1993 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU L-6; REPORT OF SUNDRY WELL OPERATIONS Dear Mr. Johnston, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for replacing the electrical submersible pump in Milne Point Unit Well L-6, Approval No. 93-221. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Att: cc: TJY Chevron Occidental L-6 Well File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Replace 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate __ Other ._X_X 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 305 Anchorage, AK 99503 4. Location of well at surface 2119' FNL, 318' FWL, Sec 8, T13N, At top of productive interval 2127' FSL, 318' FWL, Sec 4, T13N, At effective depth 2319' FSL, 551' FWL, Sec 4, T13N, At total depth 2356' FSL, 605' FWL, Sec 4, T13N, R10E, R10E, R10E, R10E, 5. Type of Well: Development Exploratory Stratigraphic Service Umiat Meridian Umiat Meridian 12. Present well cOndition summary Total depth: measured true vertical 11068 7302 Umiat Meridian Umiat Meridian feet Plugs (measured) feet 6. Datum elevation (DF or KB) 56' KDB ~eet 7. Unit or Properly name Milne Point Unit 8. Well number L-6 9. Permit number/approval number 90-10/93-221 10. APl number 50-- 029-22003 11. Field/Pool Kuparuk River Field Effective depth: measured 10983 true vertical 7250 feet Junk (measured) feet Casing Length Structural Conductor 82 ' Surface 6281 ' Intermediate Production 11035 ' Liner Perforation depth: measured true vertical Size Cemented Measureddepth ~ueverticaldepth 13-3/8" 485 sx Permf C 115' 115' 9-5/8" 1469 sx Permf E 6314' 4589' 410 sx Class G 7" 328 sx Class G 11068' 7302' 10632-10662'; 10678-10693'; 10714-10724'; 10800-10821' 10834-10878'; 10900-10904' 7041-7058'; 7067-7076'; 7088-7094'; 7139-7152' 7166-7186'; 7199-7201 Tubing (size, grade, and measured depth) 2-7/8" L-80 10497' , , Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 576', Otis DHR 13. Stimulation or cement squeeze summary Pkr. @ 609' Intervals treated (measured) None 0 CT 2 0 1993 Treatment description including volumes used and final pressure .~.iaska 0il & Gas Cons, O0rnl-nissio~ ...... Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _.X. 763 ~ 178 23 0 511 692 1 28 0 386 16. Status of well classification as: Oil X Gas __ Suspended Service 17. I hereby ¢.~.rtify_that the foregoing is true and correct to the best of my knowledge. __S_iDned fL(~- Title SHEAR Specialist Form 10-404 Rev 06/15/88 O Date SUBMIT IN DUPLICATE WELL No. L-6 co P zT o MILNE POINT UNIT (P) APl No.: 50-029--2200,3 PERMIT No.: 90-10 COMPLETED: 11/'27,/90 LAST WORKOVER: 9-24-95 NOTES: 1. ALL DEPTHS MEASURED KDB = 35' GL NABORS 27E - 2' TO HANGER ABOVE GL 2. MAX. ANGLE = 57'29' @ 4600' 3. K.O.P. = 600' 4. SLANT HOLE: YES 5. MIN. ANGLE = 51'37' @ 5100' 6. TREE TYPE: WKM 2 9/16", 5000// W/2 7/8" 8rd TREETOP CONNECTION 7. MIN. ID = 2.31.3" @ 576' 8. COMPLETION FLUID: OIL 9. STIMULATION: 6/15/91 FRAC ALL ZONES 169, 139 #'s 16/20 I-PROP 28, 603# !2/18 I-PROP SCREENED OUT ~/14, 082# 12/18 I-PROP ABOVE PERFS- CLEANED OUT WKM TBG HANGER W/2 1/2 .... ti" PROFILE BPV PUPS 1.66, 0.71, 2.1, 6.1.3, 10.2, 12.08' 16 JTS 2 7/8", 6.5//, L-80, 8rd EUE TBG 503.68' 1/4" S.S. CONTROL LINE ELECTRIC SUBMERSIBLE PUMP CABLE: PUP 2 7/8", 6.5#, L-80, 8rd EUE TBG 6.10' 576' 2 7/8" OTIS "FMX TRSV (2.315" ID) 2.72' PUP 2 7/8", 6.5#, L-80, 8rd EUE TBO 6.10' PUP 2 7/8", 6.5, L-80, 8rd EU[ PIN x VAM SOX 20.05`// 609' OTIS 7 .... DHR" PACKER (2.374" ID) 2.72' PUP 2 7/8", 6,.5//, L-80, 8rd EUE BOX x VAM PIN 9.00 621' OTIS "X" LANDING NIPPLE (2.515" ID) 1.28' 636' 2 7/8" CAMCO KBMG GLM W/ 5/16" ORIFICE (2,347" ID) 10,50.3' CSG RA TAG LOG @ 10,296' 10,533' 2 7/8" CAMCO KBMG GLM W/ DUMMY (2.347" ID) 10,575' 2 7/8" CHECK VALVE 10,445' TOP OF ESP: CENTRILIFT FC-925, TANDEM 142 STAGE TOP, 160 STAGE BOTTOM, 100 HP, 2145/27 MOTOR OSBT, KRYTOX, FPINT. 1:5 AR INSERTS 10,497' BOTTOM OF ESP PERFORATION DATA M__~_D TVD DEPTH: LZ 10,566' 10,593' (7002'-7017') LZ 10,652'-10,662' (7042'-7058') LZ 10,678'-10,693' (7067'-7076') LZ 10,714'-10,724' (7089'-7094') LK-1 10,800'-10,821' (7139'- 7t52') LK-2 10,8.34'-10,878' (7166'-7t86') LK-3 10,900'-I0,904' (7200'-7202') DENDTY: 14 SPF, 4 1/2" CSG GUN Oil & Gas Cons. C0mm. issim~ Anchorage ~" 2~~,~ ~ FO.. '-~::'", .: .... r%~': Ol?Ai-l[{O E":': O!'.,i (.'./-E: :!:f: OCT 18 '93 7:23 .... : PAGE 008 .. .~'M.Conoco 'Il ..... ~ ..... I I~lt I I II ..I Il Ifil ' Illllll Ilk II I · . ~ '~.~,'~.~ . "~ . "' -' .':-' .'?:':':':'.':',~:~m::~ ~ :,.:,:. · .:: ~:.'::::: ;::;: ;..'..'.':... '...?.':.:.:'~:::':::?.::::..::x.>:.~.:::.<:::::::::.:::.:::.:.' ;f:.: ::;:.:,;....;.:;c:.x.':: ~.:,:.::x.::.:::..~: . . ' .:";'~:~'.'.. ~.~:::.:.:~;:::.' ~ .~ .~.': '?~..:~ ~?:~ :e~ ~:A.~;;~: :;. ;,~f..,x. · .c.:,~.~.:..,~. ...... ,,~....~ ....... ' "'" ~"~"~':"~:':'~"~"<-~.~'~..~.:':.:4,~.:.~-F-',~,~,' ,'~":'-'":'""'"' ' ~,~....,:.:,:~.:.~.:.:c.:,.c. ......... ~...'.-../. .- -,.~.,-.-.:.'.:.:.~.~.:.:.>:c...:_.~, D~Y~ ~ ND/TVD; O.O /D.O DRILLS CONDITION ~ ACT.' 0 PROGRESS: 0.0 PI T; N TE#PERATURE; :~8.0 ~PL~; 0 DRL~ HRS: TRIP: N WIND ($P£ED/DIR): 40..0 FTGE: O Pi~f~3$ED TD: ( ) FIRE/ABANDON.* N gAVE (HEIGHT/DIR); O,O AFE: 5 SECTION TD: 0.0 POLLUTIO~: N RIG: 4 PLANNED OD: FORMAT II~i; ACC~DENTS~ ~ NO ACCIOENT$, NO SPILLS BAFETYI~EETINGS ( # ~ m{n ): 0 ~ ~.0 08 0,0 O~ 0.0 I P1B lA 3.00 00:00 03:00 1 PIB lC 4,00 0-5~00 07:00 11 PtO 14C g.C~3 07~00 16:00 11 PlO 14A 1,00 16:00 17=00 1! PlO 15A 3.00 17:00 20:00 11 pqO 14c 0.50 20=00 20=30 11 PlO 19 3.50 20:30 00:00 0,0 RIG IN TRANSIT 0.0 POSITION RIG 0.0 NO TREE, CUT CONTROL LINE AND PLUG, NU BOP, CHANGE CXJT i{YDRIL RUBBER, CHANGE RAHS TO 2 7/8" AND INSTALLED NEW ~ RUBBERS, 0.0 BLEED OFF BPV AND ~NSTALL TWO ~AY CHECK 0.0 TEST BOP~S TO ~O0/3000~t TEST CHOKE MANIFOLD A#D FLOOR VALVES, PULL TI/O ~AY CHECK, INSTALL LPG JT 0.0 RACE OUT TUBING HAgGER HOLD DO~ SCREWS 0,0 PULLED ON PKR TO 115,000, WOULDN'T SHEAR, PULL TO 120,000 UOULDN'T SHEAR, pULLEO 125,000 kK~JLON~T 8HEAR, ALL ~/ 5DO~toN BACKSIOE, CALLED OTIS, PU 125~000ft, BLED PRESSURE OF BACKSIDE, PKR SNEAREO, CAME UP HOLE 3~, COULDN'T GO OOlal OR UP~ COULD#~T PLMP BY PER SOURCE~ DAILY MUD: 0.00 L-'U~IULATIVE I~UIO; 0.00 SURVEY ~:~~'t'."~='~_l""'m~ =~:~t~.~,,-~.c'"';'"". ......... ; 7..'!~'=.i!'~'~! ! u !?!:~.-:~.:?~=M .............................. b:.~.~.~.;'~';?'~7"=~' '='r:"= r"~'"='~'~=~'~= =m ................... ~=.==~.==~C:~Q~:'~;%=.::u~:=~:?=.~.~e ........ ~=<~;~;~'~z;'~:~ ~': =.~: ~ ~==~=~ ~= ~ ~.~.~= C:k.~T f'=:~;;c:= ;;:.:~;~:.~'.~:~'~:~'?? ~= "..:.~:~....x.~..~.x.+., ~, ;-K~. ~ ......... ~.' ........ :.:-. ............................ ;.j ...... ~ .................................. .................. ~ .... ~" · ....... "*" ......... ~"<" ""~ .... <"~', ...... ~ .~ ~,~'~ ">' ~'~ <~ < <> -x> .<~'~ '~ <'""<-'~'-~<:~>~<. >~ ~ ~ < ;~.:'. .... x x~< { ' ~'- ~'~.~', ~ ~ ~' '<' '.~. · '.'-'.' .'..'.'.' ' * '. .......... ~' · '- '~.'~.'~.'~.'.'-'.'---- ---.-.'.-...-~.-.-... ....... ' ...... · '"" "' "+'"' '~ ' ':" ":' '>:'>:" ' -. · .... .... ,'~ "' ~' '> · '>:';- ' ..... "'* '" '~' + <'> '~'> ~* ' *, x >: '~ '~' ~ ', .......... '"'""'".-:<.:<*~:<<~'. ,".',.~',.~.'.:. {.x.~+ +:<..e., :,> 4..'.'.' ~.2.'4.*.2 ; :: ?.<*.".','.',',:':~',:':':':'.:*'.r.:.:.'-'.'<*',.: ....... ;,:......-..,......'.'-'.'.' q':'" ';' '~" '""-':'-"':"': :':':'.".~'<.'<.:.',.: · .:- <.>......'... ' .2.:.>:>. ' ?'<' <'"" ':<' ':<":' '.~',-',.-%-:+:c-~:+ ~.. <. ~.* · · ~.: ";" '; ~.'~.%?~q+'+ ~<<. - + -, ? · > > :~::; ~ :~ ~'%%''"~'*'<+:+>>+>~:~,~<. ~. c- .......... ~'~:"' ' ~'~'~ ~= ............................................. ~ ........ ':' .... < .................. ' ................ " "" ~ ..................... ~ ............. "'~ ....... ~ .... < .................... '*,' '" T~ ~..'-.~:.'.:<.~:.~:~..-~ .iU ;~; ~ f~.~ ~',%+~'" ~'. <':~'. +--'.':'.%<'.':'>:'., % ~-.'...:.:.-.r~.?-...:.-.:.,> .,...~ ...>>j.;.:.:~:.:.:.;~' ?'~'~'?'>~':':<':-:':':'? ~.<..-.....,.., ~....- -.. ->X-X ;-;.; ~;-;.::"' ~':+"?":' '":' '.':'.~'~.'~.>..:-> ~:..~.-X.:-:.~5~:.~:' ~'" ~""'.'~....' . ...--x. ,..,..,....-,.-.,...,,.,,.,.,.,.,.,.......,....... SERV{CE PERSONNEL 1 C'ONOCO, 1 $. LO~ISTI, 14 EWS, 2 HOT OIL, 4 PEA[ A. ias~<a Oii& Gas Cons, PE(N~LE AT LOCATION 2Z Anchora.c~e I~TERIAL~ BARITE EENTON{TE BLEND NEAT H~L~FUEL DIESEL DRILL WATER POT ~ATER BASE O~L ~RINE 0,0 0,0 0,0 0.0 0.0 0,0 0,0 0.0 0.0 AFE# 10-61-1529 AFE 0.00 AFE 8UPPL 0.00 AFE TOTAL ~ ~0o~ 0.00 DAILY DRILLING 0.00 TROUBLE 0.00 LOST TIME 0.00 0.00} ~)OITIONAL 0.00 000{ TOTAL 0.00 .___ II · I II I OCT i ~ ~ 98 BOTTOM HOLE ASSEMBLY iii ¢IRCULATZNG SYSTEM SLO~ PUHP RATES FLOt,/P, ATE DC · PRESSURE HW STROY..E~ 0 DP M~NUTEs O,O RSR DEPTH 0.0 DEPTH 0.0 Pt.q~P 1: 0.~0 Im.~P 1; I~P Z: O.GaO I~P 2: O,Q~O CEMENT= 0.~0 CEMENT~ O.l~lO LENGTH HRS ON JARS 0 RTG kit 0.0 TORQUE ON BNA ~,i~OHT M~N ID P/U 0.0 TO~OUE OFF DP FTG£ 0,0 TYPE (MIN ID) $/0 0.0 TORQUE NAX CASING ...'...;.:.:.:.-~.~:~..~-,~., . !. , :?F::~¥F::~:~:~:~rF::?:'T~:?~'~;;::~ ~ ~ ~ ~:~ ~:'~ ~'~ ~ :C :~: ~: ::: . ~_.. ~ ..... ' ~:~:~.:.~:~:~. ~. ~:~:~.~:~]~:. ==========================================~:::::::::::::::::::::::::::::: ............. :':':'~ A / PLqqPED 60 BBLS HOT ~ATER BY PKR, iT CANE FREE, AGLE TO HoVE UP HOLE, BUT NOT DOWN~ STILL UNABLE TO PU~P BY Oil & Gas Cons, Commiss~o,-~ OCT ACT., SPU~; FTG~; AFE; RIG: CURRENT PROGRESs: 0.0 PiT: DRLG HAS= TRIP~ PROPOSED TD: ¢ ) FIRE/ABANDOH~ SECTION TO: 0,0 POLLUTION: TEMPERATURE: 25,0 WIND ($PEED/I)IR): 10.0 WAVE (HEIGHT/DtR)~ LAYING DO~N OLD PUHP PLANNED (:ko: FORMAT ACCIDE#T$: NO BPILLS~ NO ACC[DENTS .'L~,FETY NEETINGS ( # ~ min ): 0 g OgO.O oa o.o 11 PlO 19 1,00 00:00 01:00 O.O UORK TUBING STRING IdNILE PRESSURING UP TRYING TO UORK PKR FREE AND GET CIRCULATION AROUND PK'R 11 PlO 19 2.50 Ol:O0 03~30 0.0 PUHPED 5& BBLS 140 DEGREE WATER DONN TBG~ PKR CANE FREEr BLED GAS OFF ANNULU$~ TRIED TO PUNP BY PER UNABLE TO PU~P DOll BY PKR 11 PlO 29A 2,00 0~:30 0~:30 0.0 WAIT ON 8LICKLINE 11 PlO 35A 1,50 05:30 OT:OO 0.0 RU $LICKLINE, 11 PlO 28 1.00 07=00 08:00 0.0 TRY TO STRAIGHTEN BEHT PUP AT FLOOR LEVEL~ S'O SSSV ~SOLATION SLEEVE COULD BE RUN~ UNABLE TO STRA]GHTE#, OROERED SHIFTING TOOL FOR FNX SSSV 11 PlO Z9A 4.00 08:00 1g=O0 0.0 WAIT ON SHIFTING TOOL, tdo~g PICA AND PRESSURE ANNULUS 11 PlO 35A 6.00 1~:00 16:00 0.0 RIH W/ SHIFTING SLEEVE, PRESSURE UP ON TBG TO ~000# dAR ~lTdN 3 TIMES FI4X SHIFTEO OPEN, POOH, RIN RETREIVE SHIFTING TOOL, RIH AND POOH W/ CHECE FRON GL HANDREL, RO SLICKLINE 11 pi0 16c 2.00 16:00 18:00 0.0 BLEED 100# GAS PRESSURE OFF OF k~LL 11 PlO 6F 6.00 18=00 OOtO0 0.0 PUOfl TBG, HANGER HANGING UP IN BOP, FOUND SNAP RING HAO F'OPPEO OFF TOP OF HANGER AND k~S ALLOWING TOP RING TO FLOAT AND SL]P INTO TOP RAN THEREFORE STOPPING UP TRAVEL, THLMPED RING BACK LEVEL WIT~ PiPE AND PKR CANE UP HOLE SNOOTHLY AND FLUID LEVEL NAS DROPPING, POOH LD 16 JT SSSV, P~, GL#,'FOUN~ I~0 CABLE 1ST JT BELC~d PKR 11 PlO 5 O.O0 O0:O0 00:00 0.0 P[~ H/LO ROLLED THE N~DDLE AND LOUER ~~E~'~ ~' ~ '~F D RUBBER~, HAD LOST THE #IDOLE ~= HOLE~ IT EVIDENTLY WAS AROUND THE .. · .. ~ BODY NOT ALLO~ING CIA:. AND THE HANGER WAS BINDING IT THE RAIl BOOY THE BOP NOT ALLOWING US TO PICKUP FAR ENOUGH TO , OFF-HANP_~ IT la:~ILDN~T HAVE BEEN Alaska Oil & Gas Cons. Commissior, HANGING UP IN THE BOP AND ~ MiOHT ~n-h--~rn HAVE BEEN ABLE TO GET RUR~ER GELOg PIC~ '?':'"'!"J-:'t=~:'"'"-~-"-;~:!~'F~':'~:%~:-¥:':~:~;:;'::::::" ......... ~ ...... ~ ...... ~'~-"~'~--~-:-:"~-':": .............. ~:-':":' ~'.:-:..:~':*:.:':-:.:~-.:-.~:~.:.:~.~.':-:..:~-:...: .... ~.:': ................ :.~.: ~-:.~..-:-~ .......... ~:~:~-~4.4..~-;:~ ,"~ '~ ~; ;~';-~ .......... ""'-';:'~' , ~.. ~ ........... ..:......,~....-..~:.v~ ~., . '~';.' .' , .., .~.a.-.,.~ . -~ · .-~~..x~-~ ........,x.,.~ ~ .. ~ ............. ~ ........ .......... ×~.c...~.×...x..c. ,~:~ . ~:~:' .<~::; '::.:.: ::.x. ,' ~: '. '-,,.: .... . .... .~ ...... .:,.~.. ' ........... .~,' .... ...;c :c-~ ..... c.>:~' · :-'- :c-.. :':' .~ '.' '." '.~ L ...... L' """' "~: ""'*' ~'"' ' ,.-,.x...,..~.'.'.t...<-×-,..;.::.:~:~.:-:;.-,.-×.:.:c.~× ! SOURCE; DAILY MUD: 0.00 CUf4ULATIVE t4UO: O.O0 I SURVEY Daily Driltin~ Report I .rll' J..[.' II'llnll I IIII ...I..,I. II J_l. II ' Il , I' ' I ...~ . ~. .~ .<~.:o~ ~.. ~' · ;~.: ~' ~...'-~'~---~-.--'.'-%..~..:.-~.~.~.~ ...~ ...............~.~.~ '..'... ~ ~'.... · .~-~:.:.:~.~:. ~ ..~.....v/.....~....' '.. .~ '; .~:~.~:~. . . v ;~...: .::~.. . ::.:.~:~.:~ ~ .~..' '.'~-'~, .... :~. ,~.~ ~-' >'~"'- :;:::::~ ~ . . ~.N.~.~..~..~.~ ..... ~,.4 .......... · ....... :~ · ~:%.'~.~.:~.~-:~.~:.~.~..~..~ .............. ' .' · *~,:~.~:~.~.~.:.~.~.:%.~:,~.~. · .'. ~'~.'.'~.'.'-:.~.~.%'<<~<.:~.;.:~.~.~:-.~..~,v.-.v.... [ ' ' "~'~'~" ':~'~"~"~"~"~"~'~" ...... il" '~<'>"~ .............. ¢~' ' ' ' ' ~'~'~'~e~ $ERV3~ PER~NEL HATER ;ALS AFE. 10-61 - I 3 ~, 1 $. LOG~ST~, t6 E~, 3 CAHCO, 1 AFE 0.~ ~IS, 2 CENT BARITE 0.0 AFE $UPPL 0,~ BE~T~ITE 0.0 AFE TOTAL 0,00 BLEND NEAT- 0.0 DALLY gELI ~EL 0.0 DIESEL ~.0 DRILLING 0.~ 0,~ DRILL ~TER 0.0 TR~BL~ 0,00 0,00 ~T ~ATER 0.0 L~T TIHE 0.00 0,~ BASE OIL 0.0 ~DITI~AL 0,00 0,~ ~LE AT L~ATI~ ~4 BRINE 0.0 TOTAL ~ 0,00 ~ 0,~ .... ~'~:'. :'~:~'~:<.:,.,~.~.:.:-:.:.:~.:...~.:J:..: :~.:2:~?:~.:~.:.?~:.~...~.~.:~.:~.~:.:~.:~:~:~:~:.:.:~.~:~.~:..~...~....~.:~:.:.:.:.:.~:~.~:~:~:¥~¥::.:~:.:~:.:.~.:~:.¥~:~.~:~:.~.~:~.~..:~..~.~.....:~.:~::~.~::~¥?~?~:~:~:~:..:~*~:~:~.~ ......... .~:~:.~:~:~??~.~:~:~.~:~:~:+:~:.~:~.:...~.~.¥~?~:~.~.~:~.~.:*~:.~.:.~:~2~ , ,,, ~ , ,, ,. ,, .... ~:.:~-: :::::::::::::::::::::::: .>:.*.:.. ~:~. ~.>:.> .~. ,~, ... ~ % - ..... . .:.......................%.,.....%..:.~..:.:<.:.:'.......... ~>: ~.e, ~- ; '.: -.:~...-..??? .:..:.:.:.:.:.:...........~..:~..... ...... ..~..,., ,. : .;./.;.......: :....~ .~ .............. >, · , , ~:: *' .: :..... .... .....~...........¥....~... > . .- ... :.~., ..:..... ...... , e.%,~..e.:..~ ~::~:.~.~:.~:.~_._.~ ..... '-'-' ....... %~'"-'~.'~'~.'-'-'-':'.'.'-'-':'-'~.':'-':'-':*,=--'-:::~.~:.>:t.:<.~.>~:-=.~ ......... '-'.'.'"'"'"' '"'""%'<'~:~:<'~:':':':<'~:':-~:<.%:<-x<.:.:.~:<.>: ..... ~.';':':"'"" ~.~..~.:<~:~:~:~.~:~.~:~./~:~:.:?N~:~>%>t~<~:<.~>;~<~:~:~:.~:~:.~.~:.~ _ . ~ ~P$ CIRmLATING $YSTE~ SL~ ~P MTE~ ........ ' ............................... :~:';'"; ;'"' ";'; :;:;;~;:';;;:;::'~:;':~?':;": ............ :7%'~' .............. ;::';';~:::'~:~:~'~:~ PRES~E H~ P~ 1 ~ 0.~ O P~P 1 ~ 0,~ 0 ' STR~5 0 DP ~P Z: O,~ 0 ~P Z: 0,~ 0 MINUTE~ 0.0 RSR CEMENT: 0.~ 0 CEMENT: 0.~ 0 . . m , m ,,.. . .,, ... .. BOTT~ HOLE ASSE~LY ~ mm, ' ~ .,,..,.. m ~. , · -. · LENGTH HRS ~ JARS 0 RTG ~T 0.0 TO~UE ~ ', BHA ~IGHT MIN ID P/U 0.0 T~E OFF OP ~T~ 0.0 TYPE (MIN ID) S/O 0.0 )~E ' ' ' "'" "' ,-, , CASXN~ ~,-..~....~...K.~.~.;~...'..~..,.. .................................. . ......... ... ? ,, ... ....... ~, · ~:::::~:~:~):~:~:):~ ....... :::::::::::::::::::::::::::::::::::::::~.::..:.:.:.:.::.:m.: ........ : ~:F~:~::~;~::.;:.~;~;~:~:::~:~:~:::::~: ~:~ F~ ~ ~??;~:::)!'~????':':'~;:;~':'~ :: ~: ~: ~: ::~ ~:~J~C~:-~:~.~j~)~):':L;~?~'~ ':.'~':'<m: ,~: ?~: ~:::¥?¥~ :~ :~:~;~.~.~.:~:~:.~:.F~ ............... ~ ~)~)~ ~.~.:? ~'~ '<'~')~'~.<.~.~.¥:~::~;:L: ¥ : '"L : ':':':"::: ....... "':': ..... ."-'.'.:-:.'.:.'-:.~.:.:.'-:-:<.,"' .:.:-:-~:.~:~-:.:.:-r,.-:-...~ ..... -.. .. ~...~:~:~:~.~x.~.~x~<~::~.~:~.:.:.:.:.:.:~../...~..;<.~.~.:~..~:., ~;~; ':~ L~" >~'~'~'~' '~'~":F:~;;:~:':':':':::~¥r::':::'::"< ..... :~ ,:~::~:: :~::~:~::~ :~:~ ~ ~: ~ ~:~ ~;: ~; ~: ;~ ............ :: :~: ;. :: .:.:.:.:.~.~.~..~..~...~.....~. ):~j~..~..)¥~:~.::~.~.~:: ....... ~)~:~.~ ;. :~: ~ .S~:..~?:..~.~ ...... ~.~ ~.~ ............... ~:j ~ ~ ~ :~:; ~; ~: .;.. :: ~: ~: ....... ~:~':'~": ............................... : ........... :': :':;':':': :':':':':':':':':':':-::::J:::v::.:" :::: L'?": ~:.j::~::~:.::::::::~:~.:,~.~:~::F:¥~:~...~?))~?~:~:::~?".~.~`:x``"<.:<.¥?~:~:*~ .:.:.:~,:~ ~ ~ ~F~ ~ ~ ~.;:x....'.:~:x::.:~.:.:.:...:.::~?~:~?~!'~:~ ~ ~6:)~'~:~.~:-~:~.::::;::¥:'~::'<::~:.:~.L. :.; . ,. , . ....... , .......... , - '"' ' '" L-..v ..... L::.~ ~';=:m"":~:~:~j~::L~;::~:~ ........ L.~:~:::~:::):~:):t~.~.~?~ ........... ::.:?. :(: :~:~ ........ ~. ::~. ........ ~ .......... ::..:..m..j:.:.:::.:<.:.;.~:~;.::.:~'. ~r....: ................... ::.~ ............. '. :...... :.... ~.'=~': ................ : ........................................ '~;..r:m'~:.' ................... .': m .' ?:::~::: .................................. : ................ ..................................... -..................,........................................... ...... .......~ ...... :- . ....:.:.::-...:...;. ~ ...... < ......... ~ ..... ..-.-.-~.,.:...:~...:...:...;c:f?..;.,.,.......;..~.. :: ? ;' ;,,;.::::::..,:F:::;:f::::.:~:~:~?..~>.-...-~.:.:.:..,c,:~:~:~?~ ,:.: ~NT~: ~ILL GET HANGER ~CHINED TO A~CEPT SPIRAL L~K $NA~ ~ING INSTE~ OF ~ND AND IT SH~LD ELIMINATE HAN~ ~ROBLEMS ~ask~ Oil & Gas Co~}s. Commissio~ Anchorage OCT 18''98 7:17 ~ PRGE.004 _ . . CURRENT OP; spAcING OUT HANGER FOR ESP CAGLE COHHECT~OH PLANNED OP; " FORMAT ] OH: ACC [DENTS,.t ~ :0 :0 :0 NO ACC:]DEWTS, NO SPILLS . SAFETY HEET]:NG$ ( # g m~n ): 0 ;a 0.0 0 Gt 0.0 0 g O.O ' ,,. ..... <,, :-...: ................................ - ....................................... , ., ' .*'.':;,:: .......................................... :.:.,.: ...... x ........ ~ '~'::: ~ ';'"'~ ~: 5::: ~: :';~ :::::::::::::::::::::::::::: ....... ~.:,:.: :.:q;~ :;.~:~F.!~'!~:.i:::F;~;:~;~'~:~ 2? !T? ~'::./i:~.i;i:~;~;i;~i!J~:!.'.ii:~!.."~'?' ...... =:-"'"~' ...... ~ ......... .~ ............ ~ .... ~o .......... · ..... ~E.P..~-. ~ t~t'~ ~ .............. ~ ....... op. ~q~ .......... ~ ~ ................................. <~!.. ...... ~.::...,~ .................. ~:~.~:~;..'.~.~.~.~;~:?~-~ ............... · ~ ~ ~ . · ~`~:~!..:~?~:~.~.~:~:~:~:<.×~:~:~:~>:~.:~:~.::.:<.~.:.::~.:~.~:~:.:.~.>:.~.:..-:.~.~.~:~.:.:.:~.:~.~..~.:::.~.:..:-.> · · '" "" d-~'"? ' ........ -'-'~-' ...<---x-~ ................... ..... ,... ~<.......~..........................~;.;.,...?...:.:.,.....~ ......... '.' '. ........... ........ . ...... .~.. ..... ~ <.,~.,,~ ~ ~. .... ..%.,~ ~.,.,. ................ ,~ ,, ~ , ...,..,.. ................ · ,, . ~ ~,~.....~..............,.... .... : ........ ....~ 11 PlO 6F 5.00 00:00 0~;00 11 PlO 6¢ $.00 05:00 08:00 1I P9 13A 2.50 08:00 11 1=9 13~ I3.50 10:30 0.0 FINISHED POOH W/ TBG, TOTAL ~29 JTS 0.0 LD OLD PUNP, CHANGE CABLE SP'OGL$ CLEAN OFF FLOOR, TAKE OIL SAHPLES 0.0 PU AND SERVICE NE~ PI.MP 0.0 RIH N! PUMP, CHECK VALVE, GL HANDEL AND 311JT$ 2 ?/8" TBG, GL 14ANDEL~ X NIPPLE AND PK'R~ ~ NIPPLE GALLED WHZLE HAKZNG UP~ HANGER PK'R AND CUT ESP CABLE ~HiL~ ~AITINGON NE~ X NIPPLE / ~OIJRCE; DALLY MUD: 0,00 CUMULAT : · ': 'j SERVICE PERSONNEL 2 CONOCO., I S. LO~IST[, 14 EW'S, 2 CENT, 1 OTIS, I ~ PEOPLE AT LOCATION r~ C~,T ~ ~- & Gas Cons, Commissio~ Anchorage MATER[ALS BARITE 0.0 BENTONITE 0,0 BLEND 0.0 NEAT 0.0 HEL[FUEL 0.0 DIESEL 0.0 DRILL ~ATER O.O POT ~ATER 0.0 BASE OIL 0.0 BRINE O.O AFE# AFE AFE SUPPL AFE TOTAL DAILY 10-61-15Z9I o.ool o.ooI O. 110 I I CU~. DRILLING 0.00 0.00 TROUBLE 0.00 0.00I LO~T TIME 0.00 0.00 ADDITIONAL O,O0 0,00 TOTAL 0,00 0.00 FLO~flU~TE DC 'PRE~"~JRE HW STROllS 0 DP NINUTE~ 0.0 RSR DEPTH 0,0 DEPTH 0,0 PUNp 1: 0, I~i 0 PLrHP 1 .' 0. ~ 0 PLMP 2: 0.~ 0 PLI~P 2; O.Qi) 0 CEI4ENT: o.~ 0 CEMENT; O.Q;) 0 i i i ii .... .. ?: 19 I)ai l,y Dr~ tLir~ PAGE.005 BO'rTI)F! HOLE ASSEHBLY # LENGTH HRS ON ,JARS (2 RTG VT 0.0 TORQUE ON BHA dIGHT ldlN AT) P/U 0.0 TORg~E OFF DP FTGE 0,0 TYPE (HIN ID) S/O 0.0 TORQUE MAX . CC~IMENT$= USED NE~ C~NT~OL LINE THAT I FOU~I~ ON D-PAD, SO W1~ DIDN'T I~EEO TO BUY ANY i i ,1 mi i , iii .. . -. OCT 18 '93 7:14 -~. PAGE.00£ Cof'lO~O oa~ty DriLLin9 Report ir i..'l i ii I I i'll i ilrl I ill iiiiii iiiii _1_.. II iii I ii i DAYS ,t NO/TVI:); O.O/0.0 DRILLS CONDITION. · ACT; .'~ PROGRESS; 0.0 P] T .' N TEMPERATURE.' . SPUD: ~I~ DRLG HR$: TRIP; ' N I~INO (SPEED/DIR): FTGE: 0 PROPOSED TD~ ( ) FIRE/ABANDON: N ~IAVE (HEIGHT/DIN): AFE; 5 SECT[ON TD: 0.0 POLLUTION.' N CURRENT PLANNED FORNATION; O~ 0.0 :0 0~) 0.0 RELEASED R~G MOVING TO I-4A AGC~D£NTB~ ~ NO ACCIDENTS, NO SPILLS SAFETY MEETINGS ¢ # ~ min ): 0 g 0.0 0.0 HALTING ON NE~ X ~]PPLE 0.0 I~AKE UP X NIPPLE AND PKR, NAKE ESP CABLE SPLICE 0.0 HU SSSV, TIH ~/ CONTROL LINE, ESP CABLE, AND TBG O.O ~PACE OUT HANGER FOR ESP CABLE~ O.O LAND HANGER, TEST HANGER SEALS TO 5000#, PRESb"URE UP ON TUBING TO 1900g B/ & PLU~ BBLS OF DIESEL, SET PKR, PRESSURE UP ON ~AGK$~DE TO SO0~ ~/ 15 BBLS OF DIESEL, CLOSE SSSV 0.0 BREAK OUT PUI'4P LINES~ LAYDOWN LANDING JT, SET TWO WAY CHECK 0.0 ND 0.0 NU TREE, AND TEST TREE TO 5000#~ PULL 2 ~AY CHECK, INSTALL BACK'PRES~R.IRE VALVE NOTE XN PLUG V/ UNSHEARED SEAT SET IN X NIPPLE AT 6~.1' RELEASE~ RIG AND NOVZNG TO I-4A 11 1~ 29A 1,00 00:00 0t;00 11 1~ 6F 3,~0 01~00 04=30 11 P9 15A 1,50 04:30 06;00 11 i:'9 t$A 2.00 06;00 o8:00 11 i~ 13A 1.50 08~00 09:SO 11 P~ 14A 0.50 0~:30 10:00 11 t~ 14A ~.00 1o:00 12too il I~ 14c 2.50 12=00 14~30 SURVEY NATERIAL$ AFE# 10-61-15~ AFE 0.00 AFE SUPPL 0.09 AFE TOTAL DALLY L'LM. BARITE 0.0 BENTONITE 0.o BLENO 0,0 NEAT 0,0 HELIFUEL 0,0 DIESEL 0.0 DRILL ~ATER 0.0 POT WATER 0.0 BASE OIL O.O BRIN~ 0.0 DRILLING 0.00 O.Cq3r TR(~JGLE 0.00 O.OO LOST TIME 0,00 0.00 / ADDITIONAL 0.00 0.00 TOTAL ~_ 0.00 ~ O.O0] O~T 18~'9°~ ~?:15 PAGE.003 I~O~O~O Dai(y DriIL~r~ Report itOTTOM HOLE ASSEMBLY # :IRC, ULATING SYSTEM FLITd~AT~ DC PRES.~4JRE HW STROKES 0 DP #I NLITES 0.0 RSR SLO~ PU~P RATES DEPTH 0.0 OEPTH PUMP 1= 0.i~80 PLI~P PUMP 2: O,l~l;lO PUMP CEMENT= 0.~0 CEMENT: , 0.o o.~0 0.~0 0.~0 LENGTH BHA b'EIGHT DP FTGE 0,0 HR$ ON JARS 0 RTG WT 0o0 TORGLIE ON MIN ]P P/U 0.0 TORIaUE OFF TYPE (MIN iD) $/0 0,0 TOROUE ~ SHOYS / l COI~ENT$: Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 August 18, 1993 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU L-6; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston' Attached are three copies of our Application for Sundry Approval, Form 10-403, for replacing the electrical submersible pump in Milne Point Unit well L-6. Please direct any questions or concerns regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachment CC: JHA, TJY Chevron Occidental L-11 Well File RECEIVED AU G 1 9 t99 .Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well ~ Alter casing. Repair well ~ Plugging m Time extention ~ Stimulate ~ Change approved program ~ Pull tubing. X Variance Perforate. Other X Replace ESP. ' <~ Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development X Exploratory ~ Stratigraphic . Service Location of well at surface 2119,.FNL, 318' FWL, Sec. 8, T13N, R10E, Umiat Meridian At top of productive interval 2127' FSL, 318' FWL, Sec. 4, T13N, R10E, Umiat Meridian At effective depth 2319' FSL, 551' FWL, Sec. 4, T13N, R10E, Umiat Meridian At total depth 2356' FSL, 605' FWL, Sec. 4, T13N, R10E, Umiat Meridian Datum elevation (DF or KB) 55 KDB Unit or Property name Milne Point Unit Well number L-6 9. Permit number 90-10 10, APl number 50-029-22003 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 11068' feet Plugs (measured) 7302' feet Effective depth: measured 10983' feet Junk (measured) true vertical 7250' feet Casing Length Size Cemented Measured depth Structural Conductor 82' 13-3/8" 485 SX Permf C 115' Surface 6281' 9-5/8" 1469 sx Permf E 6314' Intermediate 410 SX Class G Production 11035' 7" 328 sx Class G 11068' Uner Perforation Depth: measured10632-62' 10678-93' 10714-24' 10800-21' 10834'-78' 10900-04' true vertical7041-58' 7067-76' 7088-94' 7139-52' 7166-8~ 7199-201' Tubing (size, grade, and measured depth) 2-7/8", L-80, 10451' Packers and SSSV (type and measured depth) True vertical depth 115' 4589' 7302' RECEIVED AU G 1 9 t9g Alaska Oil & Gas Cons, OommiSSi¢ Otis FMX SCSSV @ 540'; Otis DHR Pkr. @ 567' Anchorage 13. Attachments Description summaryof proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation September 7, 1993 16. If proposal was verballyappro~;ed Oil X Name of al~prover j~ Date approved Service 17. ! hereby clrtifythape foregoing is true and correct to the best of my knowledge. Signed ( ~//~ /~1~ J.H. Andrew Title Sr. Production Engineer 15. Status of well classification as: Gas Suspended . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity'Test ~ Subsequent form required 10-~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original $~.3ned By David W. Johnston commissioner Date August 17, 1993 Approval No. ADDrOVed !;:- _ SUBMIT IN TRIPLICATE Milne Point Unit L-6 Well ESP Replacement Procedure S~3_mmary 1. MIRU workover rig. 2. Kill well by displacing hole with 8.4 ppg source water. 3. ND tree. NU and test BOP's. ~ MU landing joint to tubing hanger. PU 25,000# above pipe weight to release Otis DHR retrievable packer at 567'° 5. Circulate hole with 8.4 ppg source water. 6. POOH with 2-7/8" production tubing and ESP. 7. MU new ESP assembly and TIH on 2-7/8" production tubing. MU redressed DHR dual packer with side penetrator. Install gas lift mandrel with gutted check valve one joint below. Install redressed 2-7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. 9. Land production tubing hanger. 10. Freeze protect tubing and annulus. 11. Set packer by pressuring up against a ball dropped into an otis RHC ball catcher sub run below the packer. 12. Pressure test packer by pressuring up on annulus to 1800 psig. 13. ND BOP's, NU and test tree. 14. RDMO rig. RU and test flowline. Return well to ESP lift production. WELL No. L-6 CO MPLETIO N S KETCH MILNE POINT UNIT (P~) APl No.: 50-029-22003 PERMIT No.: 90-10 COMPLETED: 11/27/90 LAST WORKOVER: 7/20/91 NOTES: 1. ALL DEPTHS MEASURED KDB = 28' EWS //4 2. MAX. ANGLE = 57'29' @ 4600' 5. K.O.P. =' 600' 4. SLANT HOLE: YES 5. MIN. ANGLE = 51'37' @ 5100' 6. TREE TYPE: WKM 2 9/16", 5000// W/2 7/8" 8rd TREETOP CONNECTION 7. MIN. ID = 1.875" @ 10,348' 8. COMPLETION FLUID: 8.4 PPG SOURCE WATER 9. STIMULATION: 6/15/91 FRAC ^LL ZONES 169, 139 #'s 16/20 I-PROP 28, 603# 12/18 I-PROP SCREENED OUT 1///14,082# 12/18 I-PROP ABOVE PERFS - CLEANED OUT WI<M TBG HANGER W/2 1/2" "H" PROFILE BPV 16 JTS 2 7/8", 6.5#, L-80, 8rd EUE T86 1/4" S.S. CONTROL LINE ELECTRIC SUBMERSIBLE PUMP CABLE: NO. 4 AWG CL 350 TO PKR NO. 2 AWG CL .350 FROM PKR TO ESP 540' 2 7/8" OTIS "FMX" TRSV (2..31,3" ID) 547' "XO" PUP EUE 8rd x VAM (2.441" ID) 567' OTIS 7" "DHR" PACKER (2.574" ID) 570' "XO" YAM x EUE 8rd (2.441" ID) 612' 2 7/8" CAMCO KBMG GLM W/ ,5/16" ORIFICE (2.347" ID) 650' OTIS "X" LANDING NIPPLE (2.313" ID) 10,503' 10,548' 10,382' 10,450' 10,451' CSG RA TAG LOG @ 10,296' OTIS "XA" SLIDING SLEEVE (ID=1.875") 2 7/8" CHECK VALVE "XO" 2 7/8" x 2 3/8" (1.995" ID) TOP OF ESP: CENTRILIFT FC 1200, 227 STAGE, 150 HP, ROTARY INTAKE, FRSX PHD W/CENTRALIZER 10,500' BOTTOM OF ESP PERFORATION DATA MD TVD DEPTH: LZ 10,632'-10,662' (7042'-7058') LZ 10,678'-10,693' (7067'-7076') .: LZ 10,714'-10,724' (7089'-7094') LK-1 10,800'-10,821' (71.39'-7152') LK-2 10,8`34'~.1~,878' (7166'-7186') LK-`3 10,900'-10,904' (7200'-7202') ~-_ DENSITY: 14 SPF, 4 1/2" CSG GUN RE:¢£1VEI AU 6 1 9.199 Alaska Oil & Gas 6ohs, Anchorage 10,985' PBTD 11,068' 7", 26/t, L-80, BTRC CS(; CONOCO INC. ANCHORAGE DIVISION JAPPROVED Btf: JHA/HDS DRAFTED BY: CFP/SJN DATE: 7/50/92 CAD FILE: WCOL6 Alaska Oil Gas ~uno~rv.uon Commission 30u: Horcupine Drive Anchorage: The following data is hereby acknowledged as being received' P.¢ ceiYed by: Da~ed: RECEIVED dAN 1 g 1BBb N.o ~Alaska Oil & Gas Cons. commission Anchorage ,.,onoco Inc. Anchorage Division ..ecord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 December 22, 1992 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Milne Point Well Log Magnetic Tapes L-6, L-5, and L-2. Quantity Contents 1 each L-6 Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-22003, Log Date: 03-May-90, Ref #73866. Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-22030~'Log Date: 02-May-90, Ref #73865. Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-21998, Log Date: 08-Nov-90, Ref #74189. f By (---..;.~,C_~:i ~ ./'~~~"' Date ~-De'Ce'~-~r 22, 1992 Transmittal Approved Instructions: Please acknowledge r-~c-~-ip~-p~?b~ signing and returning second ReceivedBy ~ ~" ' copy.Date RECEIVED Remarks DEC 2 2 199~ Transmittal Copy Only To Alaska 011 & Gas Cons. Commission Anchorage STATE OFALASKA ,~-~ rm ""~ ALAOKA OIL AND GAS CONSERVATION COMMISb~ON ' ,' ~'"' " "' ' REPORT OF SUNDRY WELL OPERATIONS ~ !. ©Derattons performed: CDerat~on shutdown __ Stimulate__ Plugging Pull tubing X__ Alter casing __ Repair well Perforate __ Other R__EPAIR PACKER 2. ,,Name of Ooerator CONOCO INC. 3 .Address POB 340045, Prudhoe Bay, AK 99734 5. Type bt Well: Oevelooment Exploratory Stratmgraomc Serwce Locatton of well at surface 2119' FNL, 318' FWL, SEC 8, T13N, R10E, bqM qt top of proouc,dve mtervai 2127' FSL, 318' FWL, SEC 4, T13N, R10E, L,TM 'qt effect,ye Oeptl~ 2319' FSL, 551' FWL, SEC 4, T13N, R10E, UM At total dept, 2356' FSL, 605' FWL, SEC 4, T13N, R10E, UM 6. Datum elevation (DF or KB) 59' KB feet 7. Unit or Property name Milne Point Unit 8. Well number L-6 9. Permit number/approval number 90-10 10. APl number 50-- 029-22003 11. F~eld/Pool Kuparuk River Field !2. Present well condition summary Total depth: measured true vemcai Effecuve depth' measured true vertical 11,068 ' feet Plugs (measured) 7,302 ' feet 10,985 ' feet Junk(measured) 7,251 ' feet N/A N/A Casing Structural Conductor Surface intermediate Production L~ner ~erforat~on deptn: Length -- 82' 6,281' 11,035' -- measured Size Cemented _ -- 13-3/8" 485 sxs PERMAF 'E' 9-5/8" 1469 sxs PERMAF 'E' 410 sxs CLASS 'G' 7" 328 sxs CLASS 'G' -- -- 10,566' - 10,904' Measured depth 115' 6,314' 11,068' -- ~ue vemcal depth 115' 4,589' 7,302' ,RE E VEp trueve~lcal 7,003' - 7,201' -Lb~ng(s:ze, graOe, anameasureodepm) 2-7/8", 6.4¢~/ft, L-80, 10,500' DEC 1 4 199g alaska Oil & Gas Cons. Commissior~ gnchora§o '~.3cxersanoSSSV(typeanOmeasureddepth) Otis 'RDH' 7" 26-32¢J/ft @ 567' - Otis 'FMS' SCSSV @ 540' 13. Stimulation or cement squeeze summary ;;tervals treated (measured) FRAC KUPARUK PERFS WITH DRILL PIPE USING YF 150D IN PAP AND YF 140D IN SLURRY STAGES. ~eatmentdescriptionincludingvolumesusedandfinalpressure 2307 BBL FRAC CONTAINING 169139# 16-20 PLUS 28603# 12-18 I-PROP TREATED @ 8000 PSI ISIP = 6299PSI 14. °dor to well ooeratlon Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations X__ Oil X Gas Suspended X 17. ! hereby cemfy that the foregoing is true and correct to the best of my knowledge. i S,g eo Title SENIOR FOREMAN Form 10-404 Rev 06/15188 Service Date SUBMIT IN DUPLICATE co.oco ,.c. o^,.~ w~.. ^c~v,~,~.om ~,.~. ~~_< ,,~s~ ACT~ AT REPORT TIME: ~ ' ~ ~ CURRENT DEPTH: -- ~ MD ACTMTY SERVICE PERSONNEL- NO. -.--.- -'" FLUID TYPE/DENSITY:~,:~ ~, - ~ ~,L 7_.PPG I LOSSES TODAY/CUM RIG SAFETY PERFORMANCE ALL DAILY COSTS DAYS WITHOUT YEAR TO DATE ENVIRONMENTAL INCIDENTS DAYS WITHOUT C~ YEAR TO DATE Oo LAST BOPE TEST _ BOPE TEST DUE __ 41aska 0ii & Gas A ' ~ r~cnorage / -- BBLSI CUM. FLUID COST: $ i PILLS $ PLUG DESC. $ COST SUMMARY DAILY CUMULATIVE $ PREVIOUS TOTAL $ $ PLANNED $ .....- $ TROUBLE $ -- TOTAL AFE COST $ ,,~ AOGCC VISIT? ,~.'.'.¥o $ EST. FINAL COST ENGINEER ~-\ w,,. IN~j ¢,,..~-~ J SUPERVISOR STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCAT1'ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Change approved program Plugging Pull tubing Time extention Variance Perforate Stimulate X Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development X Exploratory Sl~atigraphic Service Location of well at surface 2119' FNL, 318' FWL, Sec. 8, T13N, R10E, Umiat Meridian At top of productive interval 2127' FSL, 318' FWL, Sec. 4, T13N, R10E, Umiat Meridian At effective depth 2319' FSL, 551' FWL, Sec. 4, T13N, R10E, Umiat Meridian At total depth 2356' FSL, 605' FWL, Sec. 4, T13N, R10E, Umiat Meridian Datum elevation (DF or KB) 56' KDB unit or Property name Milne Point Unit Well number L-6 9. Permit number 90-10 10. APl number 50- 029-22003 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 11068' feet Plugs (measured) 7302' feet Effective depth: measured true vertical 10985' feet Junk (measured) 7251' feet Casing Length Structural Conductor 82' Surface 6281' Intermediate Production 11035' Liner Perforation Depth: Size Cemented Measured depth 13-3/8" 485 SX Permf C 115' 9-5/8" 1469 sx Permf E 6314' 410 sx Class G 7" 328 sx Class G 11068' measured lO566-93' 10632-62' 10678-93' 10714-24' 10800-21' 10834'-64' 10900-04' true vertical7003-18' 7041-58' 7067-76' 7088-94' 7139-52' 7159-77' 7199-201' True vedical depth 115' 4589' 7302' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-7/8", L-80, 10478' Otis FMX SCSSV @ 509'; 13. Attachments Description summary of proposal X Detailed operations program . BOP sketch 14. Estimated date for commencing operation May 10, 1991 16. If proposal was verbally approved Oil X Name of approverj Date approved Service 17. I hereby c,~. rtify th~ the foregoing is true and correct to the best of my knowledge. Si~]ned ~-'~ /~)~ J.H. Andrew Title Production Engineer 15. Status of well classification as: Gas m Suspended Date April 2, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance · Mechanical Integrity Test Approved by order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10- /-/~'_) ~ ORIGINAL SIGNED BY LONNtE O. SMITH Commissioner IAppr°val N°'~l,/, _ / ~ _~ Approved C,opy Returne~ Date -fi-l~-?/ SUBMIT IN TRIPLICATE Milne Point Unit L-6 Well Fracture Stimulation Procedure Summary 1. MIRU workover rig. ~ Shear open annular vent valve by pressuring up on the 2-7/8" tubing x 7" casing annulus to 3500 psig with the valve closed. · Kill well by circulating hole full with 10.2 ppg NaBr/NaCl brine. Spot salt-based LCM pills, if necessary. 4. ND tree. NU and test BOP's. · MU landing joint to tubing hanger. PU 20,000# above pipe weight to release Otis RDH retrievable packer at 600'. 6. POOH with 2-7/8" production tubing and ESP. · TIH with bit and scraper and tag PBTD to confirm perf interval is clear of fill. POOH. · PU a Champ IV treating packer and TIH above perforated interval. Set packer and apply pressure to 4" DP x 7" annulus. 9. RU and test fracturing equipment. 10. Establish injection and pump fracture stimulation treatment at 25 BPM. Displace with 11.0 ppg brine. 11. Allow pressure to dissipate into the formation. Release packer, circulate hole full of 11.0 ppg brine, and POOH. 12. Determine top of proppant fill in casing. Wash/bail proppant to clear perforations. 13. MU ESP assembly and TIH on 2-7/8" production tubing. 14. MU reconditioned Otis RDH packer with annular vent valve. Install a 2-7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. 15. Land production tubing hanger and freeze protect annulus. 16. RU wireline and set a plug in an Otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. 17. Pressure test packer and annular vent valve by pressuring up on annulus to 500 psig. 18. Freeze protect tubing. ND BOP's, NU and test tree. 19. RDMO workover rig. RU and test flowline. Return to production. STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLF. TION REPORT AND 1. Status of Well Classification of Serwce Well -- ~ ~SERVICE OIL. -- GAS ~__ SUSPENDED. _ ABANDONED CO~OCO 3. A~ress ~ Z(/~~ r'~;;'L ' 8 APl Number 0 ~ t. so- 029-22003 4. Locat,on of well at surface L f'~'-'-~ ~--~.~ 9. Un,t or Lease Name 2119' FNL, 318' FWL, SECTION 8, T13N,R10E, UM A~ Too Prociuc~ng Interval 2120' FSL, 913' FWL, SECTION 4, T13N, R10E, UM At Total Depth 2368~ FSL, 1257' FWL, SECTION 4, T13N, R10E, UM 5. Elevation ~n feet lincllcate KB, DF, etc.) 56 ' RKB MSL i 6. Lease Designation and Serial No. ADL47434 12. Date ,%ouctcled I 13. Date T.D. Reacneo 03/07/90 i 03/19/90 MILNE POINT UNIT 10. Well Numoer L-6 and Poor KUPARUK RIVER FIELD 14. Date Comp., Susp. or AOanct. J 15. Water Depth, ~f offshore [ 16 Nc of Completions COMP. ~I N/A feet MSL i 17. Total Depth (MD+TVDI !18.PlugBackDeothIMD+'rVD) 19. D,rect~onal Survey I 20. DeotnwnereSSSV set I 2! Tn,cKnessot Permatros: 11,091/7268'1 10,983'/7336' YES~ NO-- ~ 516 ~ee~ Mb +1800' 2'). Type E~ectrm or Other Logs Run DITE/CNL/LDT/NGT/CYBERLOOK/GYRO/GR/CCL 2~. CASING SIZEIWT. PER FT. l, · 9-5/s., 36 7" i 26 24. Perforations GRADE H-40 J-SS L-80 CASING, LINER AND CEMENTING RECORD TOP I BOTTOM }HOLE SIZE CEMENTING RECORD [AMOUNT PULLED i35' RI~8 I 115' RK~ 30 ! 4808KS PERMAFROST C N/A i35'RKB 16314'RK~12 1/4" 526BBLS PERMAFROST E N/A ! ~ ' 84]~BLS CLASS G i35'RZ~J~ 111,068 8 1/~" 65"_~_Ls CLASS G; ~/a open to Proouction (MD+TVD of Top and Bottom and interval, size ancl number) 10,566~ TO 93' 10~632' TO 62' 10,678' TO 93~ 10,714' TO 24' 10,800' TO 21' 10,834' TO 78' t27. TVD'S 7002'- 17' 5BPF 7040'- 57' 5SPF 7067'- 76" 5SPF 7089'- 94' 5SPF 7139'- 52' 5SPF 7160'- 86' 5SPF 25. SIZE TUBING RECORD DEPTH SET (MD' I PACKER SET (MD~ 2 7/8" 6.5: 10~.521' I 537' 26. ACID, FRACTURE, CEtvlENT SQUEEZE. ETC DEPTH INTERVAL (MD} I AMOUNT & KIND OF MATERIAL USE-' NOT APPLICAB!E PRODUCTION TEST Date F~rst Proouctlon Date of Test t Hours Testec~ 3.2/1/90[ 12 Flow Tubing ! Casing Pressure Press288 ! 288 I Method of Operation (Flowing, gas lift, etc.) [ ELECTRIC SUBMERSIBLE PUMP ITEST PERIOD [~ 290 77 4.5 , N/A; 0.266 iCALCULATED OIL-BBL ] GAS.MCF t WATER-BBL lOlL GRAVITY-APl Icorr) 124-HOUR RATE I~ 580 ' 154 9 22 : . 28. CORE DATA Brief clescriDt~on of titholog¥, porosity, fractures, apparent O~DS ann Presence of oil, gas or water. SulDm~t core Ch~DS. RECEIVED NO COP~S CUT .0il & Gas Cons. Form 10-407 CONTINUED ON REVE~SCSIDE ,~UDmlt in (]UDIICa!~ NAME GEOLOGIC M '~ -~ 'iMEAS' DEPTH,~i; TRUE VERT. DEPTH RKB 10,864 10,800 10,5667 ,, ;- Lower Kuparu~ Lower Kuparug 31. LIST OF ATTACHMENTS 32. #2 '-ORMATION TESTS : Include interval tested, pressure oata, ali fluids recovere~ ancl g~av~ty, GOR, an~ t~rne of each phase. RKB 71787 7139t 70027 ~T/A I.' Directional Survey II: /Well History III Cementing details I hereby cert,fy that the forego,ng ,s true and correct to the best of my knowl~d~ AS -- Built Survey INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam, injection, air iniection, salt water disposal, water supply for injection, observation, injection for in-s~tu combustion. Item 5' Indicate which elevation is used as reference (where not otherwisesnown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only tine interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from uround level (GL) or other eievation (DF, KB, etc.). item .23' Attached supplemental records for this well should show the ~.eta.~ of ar~v ,m, uiti~)!e stac~e cement- in~ and the location of the cementinc~ tool. item 27' Method of Operation' Flowing, Gas Lift. Rod Pump, Hydraulic Pump, Sui:mersiD!e, Water In- jection, Gas injection, Shut-in, Other-explain. Item 28' if no cores taken, indicate "none", 10-40' Primary Cement 13 3/8 Conductor Csg: 9 5/8 Surface Csg: 7" Production Csg: Attachment No. III MPU L-6 Cemented to Surface Stage 1 3/6 Bbls of 12.3 ppg. Perma frost type E w/5 lb/sk gilsonite 67 Bbls of 15.8ppg Class Gu/3% salt 102.% CFR-3 & 1% Gel Stage 2 203 Bbls of 12.3 ppg. Permafrost Type E w/5 lb/sk gilsonite 16 Bbls of 15.8 ppg Class Gu/3% salt & 0.2% CFR-3 & 1% Gel 65 Bbls of 15.8 Class G "Premium" w/0.2% Halad 344, 0.2% CFR-3 & 0.1% Diacel LWL Milne Point L No. 6 Kuparuk River Field - North Slope Borough, Alaska W.I. 0.7214934 Milne Point L No. 6 CONFIDENTIAL AFE 10-61-1194 Location: 2119~ FNL, 318' FWL, Sec 8, T13N, R10E U.M. NSB AK Location: Bottom Hole 2460' FSL, 1291' FWL, Sec 4, T13N, R10E, U.M. COMPLETION HISTORY 11-16-90: Lay Herculite. MIRU. Accepted rig @ 2300 hrs. N/D Tree. Mud wt. 6.9/10.2 ppg Viscosity: N/A Cum. Cost: $ 1,637,998 POOL 102 (0-17-0) Drillinu Foreman: KOTARA 11-17-90: N/U BOPE's. Test pipe & blind rams to 250/4000 psi. Test hydril to 350/3500 psi. M/U 6" cement mill & TIH to 2004'. Circ diesel out & displace w/ 10.2 ppg NaBrC1. 11-18-90: TIH to 10,947'. Taking some weight. Wash & ream to 10,972'. Tagged float collar. Pump 10 bbl high vis pill. Circ B/U. Test 7" csg to 3000 psi for 30 min, OK. Change out pop off valve on mud pump. POOH. L/D cement mill. P/U bit & 7" csg, scraper, TIH. 11-19-90: TIH to 10,912' Pump 25 bbls lead pad, 50 bbls chemical pad (dirt magnet), 25 bbls ta~l pad. Reverse circ, filtering brine in hole. Make 2 circulations thru 100 micron filter, i circulation thru 50 micron, & 2 circulations thru 10 micron. R/D filter unit. POOH w/ bit & scraper. Mud wt. 10.0 ppg Viscosity: N/A Cum. Cost: $ 1,720,346 POOL 102 (0-17-3) Drillinq Foreman: KOTARA 11-20-90: Finish POOH w/ bit & scraper. R/U Schlumberger. P/U & wire guns for first run. M/U & GIH w/ GR-CCL & 14' SSPF, 4-1/2" guns. Tag bottom @ 10,952'. Perf. LK-2 sand @ 10,864'-78'. POOH & L/D spent guns. M/U 4' gulls. GIH & perf. LK-3 @ 10,900'-04'. POOH. M/U 30' guns & GIH. Perf. LK-2 sand @ 10,834'-64'. POOH. M/U 21' guns. GIH, Perf. LK-1 @ 10,800'-21'. POOH. M/U 10' guns. GIH. Perf. LZ sand @ 10,714'-24'. POOH. M/U 15' guns. GIH, Perf. LZ @ 10,678-93'. POOH. M/U 30' guns. GIH to shoot LZ @ 10,632'-62'. Gun misfired. POOH. Found shorted out collar locator. M/U new collar locator. GIH. Perf. LZ sand @ 10,632'-62'. POOH. L/D spent guns. Mud wt. 10.1 ppg Viscosity: N/A Cum. Cost: $ 1,738,918 POOL 102 (0-17-4) Drillinq Foreman: KOTARA/LINEBERGER 11-21-90: M/U guns. GIH. Perf. LZ sand @ 10,566'-93'. POOH. R/D Schlumberger. Haul H20 for frac job & heat same to 105°F (± 2200 bbls) Heat 600 bbls 11.0 ppg NaBrC1 to 105°F. Well started flowing @ 0400. Close blind rams. Pressure 50 psi. Monitor well. Pressures @ 0600 - 280 psi, @ 0800 - 380 psi, @ 0900 - 390 psi. Bleed pressure to 0 psi @ 0930. Well flowed ± 1/4 bbl oil. Close blind rams & monitor well. Pressure @ 1200 - 120 psi., @ 1400 - 240 psi. R/U Dowel. Mix 2250 bbl Gel. Well pressure @ 1600 hfs - 300 psi. @ 1800 hfs -300 psi. Bleed well to 0 psi. Well flowed ± i bbl oil. Open blind rams. Fluid level out of sight. RIH w/ 3 its DP for BOP saver. Close pipe rams. Pull Milne Point L No. 6 - ComDletion History Paqe 2 ~ooi j= up against pipe ram~. Close annular preventer. Doweli valve closed on top of 3-1/2" DP. Monitor well. Prime pumps, turbo engines. Test lines to 6000 psi - OK. Pump 200 bbls PAD @ 40 bpm @ ± 3800 psi. Stop to get ISIP - 2200 psi. After 15 minutes, SIP - 1520. Mud wt. 10.0 ppg Viscosity: N/A Cum. Cost: $ 1,815,984 POOL 102 (0-17-5) Drillinq Foreman: KOTARA/LINEBERGER 11-22-90: Puznp 335 bbls cross-linked pad. Initial pump-in rate 40.5 bpm @ 4500 psi. Injection pressure rose steadily to 4800 psi. Back rate to ± 30 bpm. Injection pressure staying @ ± 4800 psi. Continue dropping rate down to 2 bpm. Shut down frac job. R/U to 11.0 ppg NaBr/Cl tank. Pump 400 bbls 11.0 ppg NaBr/Cl kill weight fluid down hole. Final shut-in pressure - 1500 psi. Monitor well pressures. Wellhead pressure 400 psi. Bleed off to 0 psi. R/U slickline unit. · 818' Bail on fill. POOH. Found GIH w/ bailer Tag hard bottom @ 10, frac sand in bailer. R/D wireline uni~. Shut well in and monitor pressure. 11-23-90: Pressure @ 0230 hrs - 0 psi. Open well and observe. Small flow trickling out. Close blind rams & monitor for pressure. 5 psi on well. Open well. Well stable. P/U bailer BHA and TIH. BHA - saw- tooth collar, XO, flapper valve, 30 Jts 3-1/2" DP, shear safety jr, XO, bailer pump, XO, 3-1/2" DP to surface. Tag PBTD @ 10,970'. No fill. POOH. L/D DC & DP. 11-24-90: POOH. L/D 3-1/2" DP. L/D bailer. No fill in pipe. TIH w/ 4-3/4" DC. L/D same. P/U ESP equipment & M/U. 11-25-90: Finish M/U ESP & service. Purge pump w/ oil, install cable & band to pump. P/U check valve & sliding sleeve. RIH w/ 315 jts of 2- 7/8" 6.5#, L-80 8rd EUE TBG. Rabbit each jt to 2.347" GIH. Pick up packer· 11-26-90: Splice E-line @ PKR. M/U & test SSV & control line. Run remaining 15 its of 2-7/8" TBG & M/U TBG HGR. Make E-line splice @ TBG HGR. Land TBG HGR. Pump 60 bbls of diesel into csg & TBG annulus Install 2-way check. N/D BOP. Mud wt. 11.0 ppg Viscosity: N/A Cum. Cost: $ 2,288,961 POOL 102 (0-17-10) DFilliDq Foreman: BRADY 11-27-90: ND BOP, N/U Tree. Test tree to 5000 psi, pull 2-way check. R/U to set PKR. Pressure up on TBG. PKR set @ 2100 psi, continue to 3000 Psi. Close SCSSV & test annulus to 500 psi, observed for 10 min. - no leaks. Run 100' of test hose in TBG & displace w/ diesel. Freeze protect csg & csg annulus w/ 55 bbls of diesel. Install BPV. Remove rig flanges f/ tree. Rig released @ 0830 hrs. Operations suspended. Mud wt. 11.0 ppg Viscosity: N/A Cum. Cost: $ 2,461,045 POOL 102 (0-17-11) Drillinq Foreman: BRADY TOTAL PAGE . 003 ~)~ PAD L SECTION 8, TI3N, RIO~, VICINITY MAP AS-BUILT UMIAT h'£RIDIAN RECEIVED DEC 2 6 ~,taska 011 & Gas Cor~. commissio, Anchorage LOCATION IN SECTION WELL ! FROM NORTH LINE. ! FPOM WEST LINE ooo ........ ,, ................ ooo, I 1970' I / STATE PLANE COORDINATES WELL NORTHiNGS j EASTINGS ..,. ............................. , ........ . ...~ ........ . ...................... . I 6, O~ I, 4S9.2 ~ 544, 758.7 ZONE 4 ...... ....~......, ..................... : ........................... GEODETIC ~OSIIIONS WELL LAI ITUD[ LONGITUDE ............................................. ~ I 70° 29' 49" 149° 38' aZ I i CERTiFiCATE 3240 A,ctic Boulevard, Su,'re 201, Anchorage, Alaska $9505 SC.~L[ I" : ~:00' ii_JOe No. e4ooz $ U ,r-,, V F" y OF{: I HEREBY CERTIFY T~AT I AM P~OPERLY REGISTERED AND LICENSED TO THAT ALL DIMENSIONS AND OTHER DETAILS 'SURVEYEO FOR: CONOCO DATE 7-Z4-84 OR~',VN JTH CONOCO ~N ~o-/o SURVE~Y: 3-MAY-90 M~LNE PO~ UNIT L-6 ' ---~m~e~~~~LLY BUSHING ELEVATZ[IN: 56.00 FT MZLNE POINT NORTH SLOPEe ~L~K~ ~~~/~/~J~ ENG[NE~R: SCHWARTZ ~NTERPOLATEO VALUES FOR EVEN ~O~~SURED DEPTH TRUE SUB-SEA COURSE VERTZCAL DOGLEG RECTANGULAR COORDINATES HOR~Z. OEPARTURE lEiSURED VERTICAL VERTICAL D~VI~TZON ~ZIMUTH SECTZON SEVERITY NORTH/SOUTH E~ST/~EST OZSV. AZZMUTH OEPTH DEPTH DEPTH DEG M~N DEG M~N FEET OEG/IO0 FE~T FEET FEET DEG MIN 0.00 0.00 -56.00 0 0 N 0 0 E 0.00 0.00 0.00 N 0.00 E 100.00 100.00 44.00 0 21 S 1 6 W -0.11 0.04 0.20 S 0.01 E ZO0.O0 200.00 144.00 0 17 S 3 25 E -0.43 0.00 0.76 S 0.02 E 300.00 300.00 244.00 0 18 S 13 56 W -0.74 0.00 1.24 S 0.01 W 400.00 400.00 344.00 0 14 S 13 25 W -1.11 0.27 1.73 S 0.13 N 500.00 500.00 444.00 0 9 S 29 19 ~ -1.40 0.00 2.01 S 0.27 ~ 600.00 599.99 543.99 0 8 S 57 45 E -1.59 1.45 2.20 S 0.37 W 700.00 699.96 643.96 2 46 N 42 42 5 0.59 2.42 0.67 S 1.21 E 800.00 799.72 743.72 4 49 N 43 16 E 7.27 1.13 4.29 N 5.86 E 900..00 899.19 !3/+3.19 7 23 N 42 27 E 17.27 4.26 11.82 N 12.77 E 1000.00 998.15 942.15 9 7 1100.00 1096.49 1040.49 11 57 1200.00 1193.88 1137.88 13 51 1300.00 1290.58 1234.58 15 51 1400.00 1385.7Z 1329.72 20 32 1500.00 1478.98 1422.98 20 47 1600.00 1572.41 1516.41 21 40 1700.00 1664.07 1608.07 25 20 1800.00 1753.94 1697.94 26 37 1900.00 1842.79 1786.79 27 58 2000.00 1930.52 1874.52 30 22 Z100.00 2014.36 1958.36 35 6 2200.00 2094.96 2038.96 37 11 2300.00 2173.06 2117.06 39 48 2~00.00 2248.69 2192.69 42 6 2500.00 2321.04 2265.04 44 54 2600.00 2390.41 2334.41 47 7 2700.00 2456.98 2400.98 49 10 2800.00 2520.96 2464.96 51 16 2900.00 2581.73 2525.73 53 40 3000.00 2640.86 2584.86 53 19 3100.00 2701.31 2645.31 52 32 3200.00 2762.45 2706.45 52 18 3300.00 2822.92 2766.92 53 12 3400.00 2882.81 2826.81 53 16 3500.00 2942.21 2886.21 53 48 3600.00 3001.45 2945.45 53 28 3700-00 3060.89 3004.89 53 36 3800.00 3120.36 3064.36 53 27 3900.00 3179.30 3123.30 54 26 N 45 40 E 31.38 2.11 N 47 37 E 49.34 3.62 N 48 15 E 71.89 1.18 N 49 33 E 97.23 2.98 N 51 4 E 127.86 4.99 N 52 13 E 163.89 1.18 N 52 12 E 199.52 3.22 N 50 13 E 239.40 2.16 N 50 40 E 283.15 0.85 N 50 50 5 328.95 0.38 N 50 20 E 376.83 6.32 N 50 29 E 431.14 4.05 N 51 42 E 490.24 2.39 N 51 54 E 552.62 1.35 N 52 9 E 617.98 3.38 N 51 6 E 686.93 2.93 N 50 38 E 758.83 2.87 N 50 46 E 833.30 2.33 N 51 11 E 910.03 3.02 N 51 21 E 989.33 1.51 N 52 9 E 1069.90 N 52 51 E 1149.52 N 53 44 E 1228.65 N 54 31 E 1308.29 N 55 21 E 1388.37 N 56 ¢ E 1468.78 N 56 28 E 1549.28 N 54 55 E 1629.67 N 55 23 E 1710.05 N 55 46 5 1790.81 1.98 0.70 1.03 0.93 0.75 0.60 0.31 0.53 0.83 I .02 0.{10 N 0 0 E 0.20 S 3 13 E O. 76 S I 38 E 1.24 S 0 33 W 1.73 S 4 14 W 2.03 S 7 47 W 2.23 S 9 36 W 1.38 S 60 51 E 7.27 N 53 49 E 17.~+0 N 47 11 E 22.11 N 22.75 E 31.i,'2 N 45 49 E 34.50 N 35.95 E 49.83 N 46 10 E 49.66 N 52.81 E 72.~9 N 46 45 E 66.44 N 71.96 E 97.94 N 47 17 5 86.07 N 95.56 E 128.60 N 48 0 E 108.36 N 123.90 E 164.60 N 48 50 E 130.13 N 152.13 E 200.20 N 49 27 E 155.18 N 183.23 E 240.1.1 N 49 44 E 183.19 N 216.97 E 283.97 N 49 49 E 212.19 N 252.51 E 329.83 N 49 58 E 242.59 N 289.62 E 377.Ii0 N 50 3 E 277.47 N 331.43 E 432.;!4 N 50 4 E 314.53 N 377.56 E 491.~1 N 50 12 E 353.11 N 426.65 E 553.112 N 50 23 E 393.33 N 478.23 E 619.20 N 50 34 E 436.23 N 532.30 E 688.21 N 50 40 E 481.75 N 598.11 E 760.23 N 50 41 E 529.07 N 645.79 E 834.84 N 50 40 E 577.43 N 705.51 E 911.69 N 50 42 E 627.10 N 767.46 E 991.09 N 50 45 E 677.13 N 830.72 E 1071.73 N 50 49 E 725.61 N 893.92 E 1151.35 N 50 56 E 772.91 N 957.36 E 1230.42 N 51 5 E 819.59 N 1021.89 E 1309.96 N 51 16 E 865.58 N 1087.45 E 1389.119 N 51 29 E 910.88 N 1153.93 E 1470.:~2 N 5t 43 E 955.56 N 1220.96 E 1550.~ N 51 57 E 1000.76 N 1287.48 E 1630.68 N 52 9 E 1046.80 N 1353.39 E 1710.98 N 52 17 E 1092.41 N 1420.05 E 1791.62 N 52 26 E COMPUTATION DATE: Z AY-gO GE Z CONOCO INC. MILNE POINT UNIT L-6 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 3-MAY-gO KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEE'[ DEG MIN 4000.00 3237.14 3181.14 54 30 4100.00 3294.79 3238.79 55 17 4Z00.00 3351.52 3295.52 55 16 4300.00 3408.49 3352.49 55 27 4400.00 3464.88 3408.88 56 5 &500.O0 3519.77 3463.77 57 17 4600.00 3573.30 3517.30 57 29 4700.00 3630.27 3574.27 53 14 4800.00 3690.82 3634.82 52 33 4900.00 3751.74 3695.74 52 28 N 53 27 E 1872.37 N 52 34 E [954.05 N 53 12 E 2036.38 N 54 Z E 2118.55 N 54 32 E 2201.14 N 54 48 E 2284.72 N 55 33 E 2369.18 N 56 38 E 2451.27 N 56 58 E 2530.77 N 57 27 E 2609.96 3.37 1.02 I .05 0.83 1.22 1.12 2.38 2.44 0.19 0.58 1139.13 N 1486.92 E 1873.11 N 52 33 E 1188.64 N 1551.92 E 1954.82 N 52 33 E 1238.40 N 1617.54 E 2037. t7 N 52 34 E 1287.08 N 1683.74 E 2119.33 N 52 36 E 1335.24 N 1750.84 E 2201.88 N 52 40 E 1383.52 N 1819.02 E 2285.,~2 N 52 45 E 1431.97 N 1888.26 E 2369.82 N 52 49 E 1477.74 N 1956.47 E 2451.83 N 52 56 E 1521.24 N 2023.11 E 2531.,24 N 53 4 E 1564.24 N 2089.75 E 2610.3.4 N 53 11 E 5000.00 3812.70 3756.70 52 19 5100.00 3874.20 3818.20 51 37 5200.00 3935.62 3879.62 52 43 5300.00 3996.83 3940.83 51 42 5400.00 4057.33 4001.33 54 49 5500.00 4113.67 4057.67 55 42 5600.00 4171.10 4115.10 54 11 5700.00 4229.38 4173.38 55 4 5800.00 ~286.26 4230.26 55 18 5gO0.O0 4343.60 4287.60 54 39 N 58 8 E 2689.07 N 59 I E 2767.70 N 58 40 E 2846.35 N 59 33 E 2925.11 N 54 38 E 3004.54 N 53 48 E 3087.16 N 54 21 E 3169.02 N 54 16 E 3250.28 N 54 27 E 3332.52 N 55 27 E 3414.44 0.80 0.85 1.33 1.34 5.75 1.45 1.25 1.8Z 0.68 I .07 1606.50 N 2156.81 E 2689.:36 N 53 19 E 1647.64 N 2224.09 E 2767.')0 N 53 28 E 1688.50 N 2291.59 E 2846.47 N 53 37 E 1728.91 N Z359.56 E 2925. t7 N 53 46 E 1771.71 N 2426.64 E 3004.58 N 53 52 E 1820.48 N 2493.33 E 3087.20 N 53 52 E 1868.45 N 2559.66 E 3169.:36 N 53 52 E 1915.77 N 2625.7Z E 3250.32 N 53 53 E 1963.81 N 2692.47 E 3332.56 N 53 54 E 2010.88 N 2759.52 E 3414.47 N 53 55 E 6000.00 ~40Z.09 4346.09 53 45 6100.00 4461.75 4405.75 52 53 6200.00 ~522.14 4466.14 53 25 6300.00 4580.88 4524.88 54 12 6400.00 4639.25 4583.25 54 41 6500.00 4696.76 4640.76 55 6 6600.00 4753.77 4697.77 55 17 6700.00 4810.35 4754.35 55 45 6800°00 ~866o65 4810.65 55 36 6900.00 4924.46 4868.46 54 8 N 56 11 E 3495.52 N 56 49 E 3575.70 N 56 53 E 3655.31 N 56 40 E 3736.16 N 56 33 E 3817.28 N 56 36 E 3899.02 N 56 2T E 3981.10 N 56 18 E 4063.49 N 55 57 E 4146.09 N 55 46 E 4227.65 0.73 1.90 1.93 1.29 0.53 0.60 0.56 0.19 1.67 0.20 2056.44 N 2826.63 E 3495.54 N 53 58 E 2100.71 N 2893.57 E 3575.71 N 54 I E 2144.25 N 2960.33 E 3655.32 N 54 5 E 2188.59 N 3028.04 E 3736. t6 N 54 9 E 2233.30 N 3095.80 E 3817.28 N 54 12 E 2278.37 N 3164.08 E 3899.32 N 54 15 E 2323.64 N 3232.64 E 3981.t1 N 54 17 E 2369.29 N 3301.30 E 4063.51 N 54 ZO E 2415.35 N 3369.92 E 4146.12 N 54 ZZ E 2461.18 N 3437.43 E 4227.,59 N 54 24 E 7000.00 4982.77 4926.77 54 35 TtO0.O0 5040.31 4984.31 55 10 7200.00 5096.97 5040.97 55 46 T300.O0 5152.79 5096.79 56 17 7400.00 5209.36 5153.36 54 41 7500.00 5266.88 5210.88 55 14 7600.00 5323.42 5267.42 55 52 7700.00 5379.26 5323.26 56 16 7800.00 5435.26 5379.26 55 25 7900.00 5492.05 5436.05 55 33 N 55 39 E 4308.86 N 55 38 E 4390.62 N 55 31 E 4472.99 N 55 28 E 4555.94 N 55 11 E 4638.38 N 55 6 E 4720.16 N 55 7 E 4802.64 N 55 3 E 4885.59 N 54 58 5 4968.42 N 54 54 E 5050.72 0.59 ' 2506.96 N 3504.54 E 4308.')0 N 54 25 E 0.79 0.89 0.08 0.52 0.71 0.43 0.44 0.57 0.27 2553.11 N 3572.06 E 4390.67 N 54 27 E 2599.69 N 3640.03 E 4473.06 N 54 28 E 2646.69 N 3708.41 E 4556.01 N 54 29 E 2693.62 N 3776.20 E 4638..~6 N 54 30 E 2740.39 N 3843.32 E ¢720.25 N 54 31 E 2787.57 N 3910.97 E ~802.73 N 54 31 E 2835.06 N 3978.99 E 4885.69 N 54 32 E 2882.56 N 4046.87 E 4968.53 N 54 32 E 2929.82 N 4114.25 E 5050.84 N 54 33 E COHPUTATION DATE: 1" AY-90 ;E 3 CONOCO INC. MILNE POINT UNII' L-6 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 3-HAY'90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE '4EASURED VERTICAL. VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 8000.00 5548.26 5492.26 56 0 8100.00 5603.90 5547.90 56 21 8200.00 5659.05 5603.05 56 8300.00 5714.17 5658.17 56 6 8400.00 5769.81 5713.81 56 25 8500.00 5825.99 5769.99 54 46 8600.00 5883.51 5827.51 55 6 8700.00 5940.25 5884.25 55 44 8800.00 5996.30 5940.30 56 7 8900.00 6051.58 5995.58 56 36 N 54 50 E 5133.42 N 54 41 E 5216.51 N 54 31 E 5299.92 N 53 25 E 5383.36 N 53 9 E 5466.44 N 53 9 E 5549.15 N 53 4 E 5630.94 N 53 12 E 5713.27 N 53 16 E 5796.08 N 53 12 E 5879.39 9000.00 6107.73 6051.73 55 21 9100.00 6164.14 6108.14 56 0 9200.00 6219.61 6163.61 56 35 9300.00 6274.23 6218.23 56 52 9400.00 6330.16 6274.16 55, 50 9500.00 6386.52 6330.52 54 37 9600.00 6444.90 6388.90 54 26 9700.00 6502.84 6446.84 54 49 9800.00 6559.96 6503.96 55 32 9900.00 6615.86 6559.86 56 30 N 53 29 E 5962.13 N 53 28 E 6044.69 N 53 23 E 6127.89 N 53 15 E 621!.65 N 53 23 E 6294.53 N 53 18 E 6377.12 N 53 23 E 6458.31 N 51 15 E 6539.76 N 51 7 E 6621.73 N 51 0 E 6704.53 tO000.O0 6672.40 6616.40 53 57 [0100.00 6731.61 6675.61 53 54 LOZO0.O0 6790.53 6734.53 53 38 t0300.O0 6849.95 6793.95 53 43 [0400.00 6908.51 6852.51 54 51 [0500.00 6965.27 6909.27 55 36 [0600.00 7021.99 6965.99 55 19 tO700.O0 7079.67 7023.67 54 15 10800.O0 7138.90 7082.90 53 10 t0900.00 7199.36 7143.34 52 47 [0985.00 ~----250.74 719~.74 52 47 ._~' ,- N 51 32 E 6786.88 N 51 50 E 6867.39 N 52 14 E 6948.13 N 52 SZ E 7028.53 N 53 54 E 7109.58 N 54 46 E 7191.91 N 55 44 E 7274.25 N 55 16 E 7355.91 N 55 11 E 7436.47 N 55 14 E 7516.07 N 55 16 E 7583.76 0.33 0.34 0.52 1.09 0.36 1.26 0.34 0.38 0.93 1.15 2977.43 N 4181.89 E 5133.54 N 54 33 E 3025.37 N 4249.76 E 5216.63 N 54 33 E 3073.70 N 4317.74 E 5300.t)5 N 54 33 E 3122.58 N 4385.36 E 5383.48 N 54 33 E 3172.34 N 4451.91 E 5466.55 N 54 32 E 3221.94 N 4518.10 E 5549.25 N 54 30 E 3271.05 N 4583.53 E 5631.03 N 54 29 E 3320.,46 N 4649,,40 E 5713.35 N 54 28 E 3370.02 N 4715.75 E 5796.]L5 N 54 27 E 3419.90 N 4782.50 E 5879.~6 N 54 26 E 0.69 0.59 0.29 I .96 1.09 3.01 0.85 1.07 1.25 1.28 3469.30 N 4868.88 E 5962.19 N 54 25 E 3518.41 N 4915.26 E 6044.75 N 54 24 E 3567.97 N 4982.09 E 6127.94 N 54 23 E 3617.98 N 5049.29 E 6211.69 N 54 23 E 3667.53 N 5115.75 E 6294.57 N 54 22 E 3716.88 N 5181.98 E 6377.16 N 54 Zl E 3765.29 N 5267.16 E 6458.34 N 56 ZO E 3815.12 N 5311.65 E 6539.'r9 N 54 19 E 3866.61 N 5375.57 E 6621.74 N 54 16 E 3918.68 N 5~60.10 E 6704.!~3 N 54 14 E 2.79 0.57 0.83 I .ZO 1.87 0.97 0.89 0.88 1 0.00 3970.42 N 5504.32 E 6786.138 N 54 12 E 4020-30 N 5567.60 E 6867.39 N 54~ 10 E 4070.03 N 5631.29 E 6948.13 N 54 9 E ~118.97 N 5695.11 E 7028. f~3 N 54 7 E 4167.37 N 5760.14 E 7109.!5B N 54 7 E 4215.35 N 5827.03 E 7191.91 N 54 7 E 4262.21 N 5894.76 E 7274.25 N 54 8 E 4308.50 N 5962.07 E 7355.91 N 54 9 E 4354.54 N 6028.19 E 7436.47 N 54 9 E 4399.86 N 6093.65 E 7516.07 N 54 10 E 0.00 4438.46 N 6149.26 E 7583.76 N 54 11 E COMPUTATION DATE: 1i }.Y-90 ;E 4 CONOCO HILNE POINT'UNIT L-6 MILNE POINT NORTH SLOPEr ALASKA DATE OF SURVE!Y: 3-MAY~90 KELLY BUSHING ELEVATION: 56.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE 4EASURED VERTICAL VERTICAL DEV[ATZON AZIMUTH DEPTH DEPTH DEPTH DEG 0.00 0.00 -56.00 0 0 1000.00 998.15 942.15 9 7 2000.00 1930.52 1874.52 30 22 3000.00 2640.86 2584.86 53 19 4000.00 3237.14 3181.14 54 30 5000.00 3812.70 3756.70 52 19 6000.00 ~402.09 4346.09 53 45 7000.00 ~982.77 4926.77 54. 35 8000.00 5548.26 5492.26 56 0 9000.00 6107.73 6051.73 55 21 ENGINEER: SCHWARTZ tO000.O0 6672.40 6616.40 53 57 t0985.00 7250.7~ 7194.74 52 47 VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIS1'. AZIMUTH FEET DEG/IO0 FEET FEET FEEl' DEG MIN N 0 0 E 0.00 N 45 4.0 E 31.38 N 50 20 E 376.83 N 52 9 E 1069.90 N 53 27 E 1872.37 N 58 8 E 2689.07 N 56 11 E 3495.52 N 55 39 E 4308.86 N 54 50 E 5133.42 N 53 29 E 5962.13 N 51 32 E 6786.88 N 55 14 E 7583.76 0.00 2.11 6.32 1.98 3.37 0.80 0.73 0.59 0.33 0.69 2.79 0.00 0.00 N 0.00 E O.DO N 0 0 E 22.11 N 22.75 E 31.1'2 N 45 49 E 242.59 N 289.62 E 377.~I0 N 50 3 E 677.13 N 830.72 E 1071.1'3 N 50 49 E 1139.13 N 1686.92 E 1873.],1 N 52 33 E 1606.50 N 2156.81 E 2689.36 N 53 19 E 2056.44 N 2826.63 E 3495.54 N 53 58 E 2506.96 N 3504.54 E 4308.90 N 54 25 E 2977.43 N 4181.89 E 5133.54 N 54 33 E 3469.30 N 4848.88 E 5962.1.9 N 54 25 E 3970.42 N 5504.32 E 6786.E~8 N 54 12 E 6438.46 N 6169.26 E 7583.1'6 N 54 11 E COMPUTATION DATE: 1i ~Y-90 3E 5 CONOCO INC. MILNE POINT UNIT L-6 MILNE POINT NORTH SLOPE~ ALASKA TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DIG MIN DATE OF SURVEY: 3-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET 0.00 0-00 -56.00 0 0 N 0 0 E 0.00 0.00 0.00 N 0.00 E 56.00 56.00 0.00 0 11 S 19 47 E 0.00 0.00 0.00 N 0.00 E 156.00 156.00 100.00 0 19 S 2 1 E -0.31 0.09 0.54 S 0.01 E 256.00 256.00 200.00 0 16 S 3 12 W -0.59 0.00 1.02 S 0.01 E 356.00 356.00 300.00 0 18 S 12 44 W -0.97 0.00 1.52 S 0.09 W 456.00 456.00 400.00 0 10 S 34 45 W -1.29 0.25 1.91 S 0.21 W 556.01 556.00 500.00 0 9 S 35 Z W -1.53 0.12 2.13 S 0.35 W 656.01 656.00 600.00 1 ZO N 46 20 E -0.98 3.21 1.83 S 0.12 E 756.14 756.00 700.00 4 9 N 43 18 E 3.87 1.89 1.77 N 3.49 E 856.52 856.00 800.00 5 57 N 42 10 E 12.40 2.58 8.14 N 9.41 E 957.36 956.00 900.00 8 16 1058.71 1056.00 1000.00 10 35 1161.02 1156.00 1100.00 13 24 1264.12 1256.00 1200.00 14 59 1368.43 1356.00 1300.00 18 40 1475.39 1456-00 1400.00 21 7 1582.36 1556.00 1500.00 Z1 10 1691.07 1656.00 1600.00 Z5 B 1802.31 1756.00 1700.00 26 38 1914.96 1856.00 1800.00 Z8 0 N 44 25 E 25.05 1.17 N 46 56 E 41.33 2.90 N 48 11 E 62.76 1.14 N 48 54 E 87.71 1.55 N 50 22 E 117o24 6.74 N 52 3 E 155.10 1.65 N 52 22 E 193.07 2.61 N 50 18 E 235.59 3.11 N 50 4I E 184.18 0.83 N 50 50 E 335.96 0-I8 Z029.80 1956.00 1900.00 32 12 2151.3, Z056.00 2000.00 36 27 2177.83 2156.00 2100.00 39 30 1409.91 1256.00 2200.00 42 27 1549.94 2356.00 Z30O.OO 46 5 2698.50 2456.00 2400.00 49 8 Z857.00 2556.00 2500.00 51 50 3025.22 1656.00 2600.00 52 57 3189.45 2756.00 2700.00 52 13 3355.23 2856.00 2800.00 53 12 N 50 Z E 39Z.Z5 N 51 Z1 E 461.1Z N 51 53 E 538.47 N 52 3 E 624.67 N 50 46 E 722.54 N 50 46 E 832.16 N 51 17 E 954.92 N 52 21 5 1090.06 N 53 39 E 1220.29 N 55 1 E 1352.51 3523.35 2956.00 2900.00 53 49 3691.76 3056.00 3000.00 53 36 3860.17 3156.00 3100.00 53 59 4032.49 3256.00 3200.00 54 33 4207.86 3356.00 3300.00 55 13 ~384.10 3456.00 3400.00 55 55 4567.64 3556.00 3500.00 57 48 4742.67 3656.00 3600.00 52 40 ~906.99 3756.00 3700.00 52 28 5070.59 3856.00 3800.00 51 56 N 56 1Z E 1487.61 N 55 1 E 1623.04 N 55 41 E 1758.52 N 52 36 E 1898.81 N 53 17 E 2042.83 N 54 29 E 2187.95 N 55 8 E 2341.84 N 56 54 E 2485.28 N 57 30 E 2615.50 N 58 45 E 2744.67 6.05 1 o00 1.28 3.63 ! .67 2.26 2.23 1.29 0.86 0.61 0.52 1.01 1.22 1.54 1 .OB 0.91 1.06 0.50 0.55 1.55 17.57 N 18.20 E 29.03 N 30.01 E 43.55 N 45.96 E 60.20 N 64.72 E 79.34 N FEEl' DEG MIN 0.00 N 0 0 E O. C" 0 N 0 0 E 0.54 S I 15 E 1.02 S 0 47 E 1.53 S 3 22 W 1.92 S 6 11 W 2.1.6 S 9 22 W 1. fi3 S 3 39 E 3.91 N 63 7 E 12.4,5 N 49 11 E 25.~I0 N 46 0 E 41.1'6 N 45 57 E 63.32 N 46 33 E 88.*q9 N 47 4 E 87.32 E 117.98 N 47 45 E 102.96 N 116.96 E 155.82 N 48 38 E 126.18 N 147.03 E 193.1'5 N 49 22 E 152.T4 N 180.29 E 236.2.9 N 49 44 E 183.85 N 217.77 E 285.CtO' N 49 50 E 216.63 N 257.96 E 336.fI5 N 49 59 E 252.49 N 301.50 E 393.26 N 50 3 E 296.41 N 354.74 E 462.27 N 50 7 E 344.37 N 415.51 E 539.66 N 50 21 E 397.45 N 483.50 E 625.89 N 50 35 E 458.71 N 559.98 E 723.87 N 50 41 E 528.35 N 644.91 E 833.1'1 N 50 40 E 605.57 N 740.57 E 956.64 N 50 44 E 689.48 N 846.67 E 1091.89 N 50 51 E 767.97 N 950.63 E 1222.07 N 51 4 E 845.10 N 1058.02 E 1354.1.0 N 51 23 E 921.38 N 1169.57 E 1488.S1 N 51 46 E 996.96 N 1282.04 E 1624.~6 N 52 8 E 1074.22 N 1393.37 E 1759.38 N 52 22 E 1155.03 N 1508.06 E 1899.56 N 52 33 E 12~2.25 N 1622.71 E 2063.62 N 52 34 E 1317.58 N 1740.10 E 2188.70 N 52 40 E 1416.41 N 1865.77 E 23~2.50 N 52 48 E 1496.39 N 1984.95 E 2485.80 N 52 59 E 1567.22 N 2094.42 E 2615.87 N 53 12 E 1635.70 N 2204.31 E 2744.90 N 53 25 E COMPUTATION DATE: 1'1 AY-90 ,;E 6 gONOCO INC. qILNE POINT UNIT L-6 qILNE POINT qORTH SLOPE~ ALAS':~CA DATE OF SURVeY!Y: 3-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ~ASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES H0~:IZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEE'1' DEG MIN 5233.59 3956.00 3900.00 52 31 ~397.66 4056.00 4000.00 54 44 ~574.08 4156.00 4100.00 54 34 ~746.76 4256.00 4200.00 55 26 ~921.38 4356.00 4300.00 54 27 5090.44 4456.00 4400.00 53 1 5257.39 4556.00 4500.00 54 14 ~429.02 4656.00 4600.00 54 49 ~603.91 4756.00 4700.00 55 18 5781.10 4856.00 4800.00 55 46 N 59 7 E 2872.96 N 54 42 E 3002.63 N 54 16 E 3147.96 N 54 11 E 3288.72 N 55 38 E 3431.86 N 56 46 E 3568.07 N 56 47 E 3701.60 N 56 34 E 3840.96 N 56 27 E 3984.31 N 56 I E 4130.48 2.06 6.04 1.80 0.16 1.39 1.53 1.11 0.38 0.65 0.70 1702.31 N 2314.44 E 2873.06 N 53 40 E 1770.59 N 2425.08 E 3002.67 N 53 52 E 1856.16 N 2542.55 E 3148.00 N 53 52 E 1938.25 N 2656.90 E 3288.76 N 53 53 E 2020.75 N 2773.88 E 3431.E19 N 53 56 E 2096.52 N 2887.18 E 3568.08 N 54 I E 2169.60 N 2999.12 E 3701.60 N 54 7 E 2246.36 N 3115.58 E 3840.96 N 54 12 E 2325.41 N 3235.32 E 3984.33 N 54 18 E 2406.62 N 3356.98 E 4130-51 N 54 22 E 5953.94 4956.00 4900.00 54 20 r127.53 5056°00 5000.00 55 21 r305.78 5156.00 5100.00 56 17 r480.93 5256.00 5200.00 55 6 r658.22 5356°00 5300.00 56 r836.48 5456.00 5400.00 55 18 !013.85 5556.00 5500.00 56 ~194.45 5656.00 5600.00 56 40 3375.08 5756.00 5700.00 56 18 ~552-05 5856.00 5800.00 54 54 N 55 42 E 4271.39 N 55 36 E 4413.23 N 55 28 E 4560.74 N 55 6 E 4704.51 N 55 4 E 4850.89 N 54 59 E 4998.44 N 54 49 E 5144.91 N 54 31 E 5295.28 N 53 10 E 5445.70 N 53 6 E 5591.67 0.69 0.63 0.09 0.65 0.08 0.27 0.45 0.43 0.65 0.39 2485.82 N 3473.59 E 4271.4,3 N 54 25 E 2565.88 N 3590.73 E 4413.29 N 54 27 E 2649.41 N 3712.37 E 4560.~2 N 54 29 E 2731.43 N 3830.48 E 4704.60 N 54 30 E 2815.18 N 3950.54 E 4850.99 N 54 32 E 2899.78 N 4071.45 E 4998.55 N 54 32 E 2984.05 N 4191.28 E 5145.,03 N 54 33 E 3071.01 N 4313.96 E 5295.~,1 N 54 33 E 3159.90 N 4~35.30 E 5445.81 N 54 32 E 3247.45 N 4552.12 E 5591.76 N 54 30 E 3728.02 5956.00 5900.00 55 52 8908.03 6056.00 6000.00 56 34 ~085.46 6156.00 6100.00 55 55 ~266.53 6256.00 6200.00 57 5 ~446. Z2 6356.00 6300.00 56 5 ~619.11 6456.00 6400.00 54 31 ~793.02 6556.00 6500.00 55 28 9971.80 6656.00 6600.00 54 57 D1~,1.45 6756.00 6700.00 53 59 D310.22 6856.00 6800.00 53 48 N 53 14 E 5736.43 N 53 13 5 5886.10 N 53 29 E 6032.65 N 53 19 E 6183.58 N 53 18 E 6332.85 N 53 7 E 6473.86 N 51 7 E 6615.98 N 51 14 E 6763.96 N 51 58 E 6900.88 N 52 58 E 7036.77 0.56 1.37 0.51 0.51 0.68 1.93 1.19 4.28 0.38 1.12 3334.33 N 4667.95 E 5736.51 N 54 28 E 3~23.92 N 4787-87 E 5886-k6 N 54 26 E 3511.24 N 4905.58 E 6032.1r0 N 54 24 E 3601.20 N 5026.79 E 6183.63 N 54 23 E 3690.41 N 5146.49 E 6332.119 N 54 Z1 E 3774.60 N 5259.62 E 6473.119 N 54 20 5 3863.00 N 5371.09 E 6616.1) 0 N 54 17 E 3956.10 N 5486.39 E 6763.96 N 54 12 E 40&0.98 N 5593.97 E 6900.118 N 54 9 E 4123.95 N 5701.69 E 7036.77 N 54 7 E 0483.58 6956.00 6900.00 55 38~,.-~,-N 54 36 E 7178.36 ~659.30 7056.00 7000.00 54 40:~"-i'oN 55 23 E 7322.81 3828.34 7156.00 7100.00 52 44~.~'~:?N 55 15 E 7459.06 D985.00 7250.74 7194.74 52 47"' N 55 14 E 7583.76 0.79 0.85 4.94 0.00 4207.52 N 5815.98 E 7178.36 N 54 7 E 4289.66 N 5934.84 E 7322.111 N 54 8 E 4367.43 N 6046.75 E 7459.06 N 54 10 E 4438.46 N 6169.26 E 7583.76 N 54 11 E COMPUTATION DATE: 1T '~Y--90 ~E 7 CONOCO INC. MILNE POINT UNIT L-6 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVE:Y: 3-MAY-90 KELLY BUSHING ELEVAT[E~N: 56°00 FT ENGINE,!R: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS MARKER GCT LAST READING DRILLEReS DEPTH SURFACE LOCATION = 2119' FNL g 318" FHL, SEC8 T13N RIOE MEASURED DEPTH TVD RECTANGULAR C:OORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10832.10 ?158.Z8 ?~OZ.Z8 4369o13 N 6049.21 E ~0985.00 7Z50.74 7194.74 4438.46 N 6149.Z6 E COMPUTATION DATE: 1; .A¥-90 : GE 8 :ONOCO INC. IILNE POINT UNIT L-6 qILNE POINT 40RTH SLOPE~ ALASKA MARKER DRILLER ·S DEPTH DATE OF SURVEY: 3-MAy-90 KELLY BUSHING ELEVATIt)N: 56.00 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 2119" FNL E 318" FWL~ SEC8 TI!IN RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FRON KB SUB-SEA NORTH/SOUTH EAST/WEST 10985.00 7250.74 7194.74 4438.46 N 6149.26 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10985.00 7250°74 7194.74 7583.76 N 54 ll E COMPLETION DATE ............... MATERIALS iNVENTOFiY LiST AUL'~{.,I~ L'~ 17_. U LU L~. ! I_,AL /~ WELL NAME /~/~ L2 /-:.. ~- -0 ~ ch~ck off or list data as it is recciv~d.*list re~ived date for 407. if not reauired list as NR drillina histo~' survev well tests core dcscri core analysis diaitai data I AIU,g cored intervals dry ditch intervals I n~ TVnC i nl Ikl Ik!TIErltl4 I ~UU I , rL ~ R~II I,tILRI~LO SCALE NO. [to thc nearest fsot~ linch/100'} ~. " I " I ....... I/ I - ;, ° '/ d~ I I I ! 10! ! ' I 11] I I ~l I ! 131 I ............. ~l "'I-' I ~6i ! I I ' ~ '"i ' ~81 I , I I ! SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 NOV ~ I 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~$E REPLY TO $CHLUMBEROER WELL SER¥1CESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2__BL_prints of the Perf, Run 1, 11/19/90 Compony CONOCO, Inc .... Well Milne Point Field MJlne pQJnt Additionol prints are being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 At,n: George Lamb - OF 20!8 PER . on: .Counly North Sl_mpa~State _l_BL_prints, 1 RF Sepia CONOCO; Tn_c; 1000 South Pine Alaska Ponca City, OK 74603 Attn: Log Library 1 BL prints, 1RF Sepia OXY U.S.A., Inc. .6 Desta Drive Midland, TX 79710 _Attn: John Carrol *(915/685-5600) _l_jtL_prints, 1 RF Sepia Chevron U.S.A, _11111 South Wjlcre.~t_ ~Houst~ Towag 7713qq · Attn: Priscilla MacLeroy ,7713/561-3652 1 BL.od~ts, I RF Sepia Al~a'sk~ Oil & Gas Conservatfo~n Commission /- 3001 Porcupine Drive ,' Anchorage, AK 99501 ~i Attn: John Boyle .: ~ ~ ~ :-- - .~ The film is returned to Conoco, Log Library. prints prints prints Alaska Oil & Oas Co~k';. [;orumisslo~. Ar~chorage Received by; Date: We oppreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES D~vid M, Saalwaechter SW,~-- 13274~ Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 November 12, 1990 Mr. Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Milne Point Unit, Well No. L-6 Dear Mr. Smith' Please find enclosed an Application for Sundry Approvals for the above referenced well. Jim H. Andrew Production Engineer ' - STATE OF ALASKA _J-,SK, LAND GAS CONSERVATION COMk,,,.,¥1ON APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon __ Suspend __ Alter C2slnq __ Repair well Change approved program __ Opera,on shutdown __ Re-enter suspended well __ P!uggmg __ Time exlenmon __ ~imulale ~ Pull tubing __ Variance __ Perforate __ O(her __ 2. Name of Operator Conoco Inc. 3. Address 3201 C St., Suite 200 4. Location of well at surface 2119' FNL, 318' FWL, At top of productive interval 99503 Anchorage, AK At effective depth Gyro Survey not At total deptl~ 5. Type of Well: Development Exploratory Stratlgraomc Ser,,nce Sec. 8, T13N, RiOE, U.M. presently available 6. Datum e~eva,on (DF or KB) KB = 56' msl 7. Unit or Property name Milne Point Unit 8. Well numOer L-6 9. Permit number 90-10 10. APl numoer 5O-- 029-22003 11. Field/Pool Kuparuk River Field feet 12. Present well conc, tion summary Total depth: measured true vemcai 11,091 ' feet Plugs (measured) PBTD 7,344' * feet 10,983' Effective depth: measured true vertical 10,566 ' feet Junk(measured) 6,743 ' * feet Casing Length Structural Conductor 8 0" Sudace 6,2 77 ' Intermediate Production 11,036 ' Liner Perforation depth: measured N/A true vertical N/A Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Size - Cemented Measured depth 13-3/8" 480 5X PERMF C 115' 9-5/8" 526 bbl PERMF E ' 6,314' 84 bbl PERMF E 7" 66 bbl CLASS G 11,068' ~ueve~caldepth * 115' 4,587' 7,321' N/A * Note: TVD depths based R EC E JVE irectional, not NOV 1 5 1990 on MWD from gyro _0j! .& 6as Cons. C mmiss . Oescnp,on summa~ ot proposal __ ~tm~e~perat~ons program BOP sketcn __ survey 14. Es,mated date for commencing operation 11/15/9o 16. Il proposal was verbally approved 15. Sla[us of well classdicat~on as: Name of aoorovej' 17'. I hereoy cen~ty Oate approved [ Oil _~ Gas ._.= Suspended __ Service Da:e 11/12/90 ;]ping ~s [rue ara correc[ to [ne pest Ol my Knowledge. Title Product-[ on En§ineer F-OR CCMMISSIChl tJ~E Conditions of 3coroval: No[fly Commission so represenJa,ve may w,ness Plug mteqnty __ BOP Test __ Loop.on clearance Mechanical In[egnty Test __ Subsequent iorm required {'~"-. /?l~:¢ I ORIGINAL SIGNED BY L, LONNIE C. SMITH ooroved by order of the Ccmmmsion Commmsloner Form 10-403 Rev 06115/88 - 43 - Approved Copy RCurne¢ SUBMI [ l;'J fRIPLIC,\[E Proposed RU, Rathole Deepeninq, and Wellbore Cleanup Procedure- NOTE: Hold frequent on site safety meetings prior to all potentially hazardous tasks. · Skid rig to the L-6 well and RU on well. ND tree and tubing hanger. NU BOP's. Install pipe rams for 3-1/2" ,-~ drill pipe. Test rams to 250/4000 psi and test Hydril to 350/3500 psi. Record tests on AOGCC and Conoco daily reports. · MU bit w/o jets and full gauge nominal rotatable casing scrapers on drill pipe. · e PU drill pipe and GIH to PBTD @ 10,875'. f~-,~)-a~ t ~ s( -' ~ .......... , ........ ~,jj Deepen rathole to + 10,975' (70 rathole). PU to 10,~4'. Reverse circulate the following cleansing pill at maximum pump rates· Ce Lead pad - 25 bbls of 3.5 #'s HEC/bbl of brine Chemical pad - 50 bbl s of brine + 1 drum of surfactant/dispersant(Safe-Kleen, Dirt Magnet, etc..) Tail pad - 25 bbls of 3.5 #'s HEC/bbl of brine Post flush - circulate with filtered brine (10 microns) at maximum rates until less than 50 NTU NOTE: 1. Safety and environmental precautions must be taken when handling brine and chemicals. Review MSDS sheets prior to handling. 5~ 2. Chemicals must be mixed and maintained above 70 deg F. 3. Monitor brine clarity every 50 bbls during post flush with a Turbidity Meter. Submit results to engineering. POOH and L/D drill pipe. RECEIVED NOV 1 5 1990 .Oil & Gas Cons. Cgmmiss].O , -. Proposed LK-3~ LK-2~ LK-I~ and LZ Perforatinq Procedure' RU Schlumberger electric line. Hook up down-joint w/ pack-off and place in Hydril for pressure control. 2. Hold safety meeting and discuss hazards and required precautions associated with wireline perforating. Pressure test lubricator. NOTE: All Conoco and Schlumberger (see attached) perforating safety procedures must be strictly adhered to. These procedures and safety meetings shall be repeated with each subsequent gun run. e MU 4'+ 14' (w/ switch) x 4.5" OD gun assembly (5 SPF, 37gm, 51B deep penetrating charges) with GR/CCL for depth control. GIH and correlate w/ open hole logs. Place guns on depth and shoot LK-3 @ 10,900'-04' PU and place guns on depth and shoot LK-2 @ 10,864'-78'. POOH and monitor hole. L/D spent guns. NOTE: Measure OD and length of all tools to be run in the hole. Measure and record distance from top shot on gun assembly to GR/CCL. . Repeat step 3. five additional times as follows w/ CCL as depth control, if first run proves CCL correlation feasible. Run No. Length Interval Sand 2 30' 10,834'-64' LK-2 3 21' 10,800'-21' LK-1 4 10' 10,714'-24' LZ (w/ switch) 15' 10,678'-93' LZ 5 30' 10,632'-62' LZ 6 26' 10,566'-93' LZ ~ RD electric line. Monitor fluid level. Do not attempt to keep the hole full to surface. This may result in large volumes of fluid lost to the formation. MPU L-6 WELL Milne Point Unit PROPOSED COMPLETION PROCEDURE AFE No. 10-61-1194 10/9/90 - CVL Objective: Deepen rathole; clean the wellbore fluids; perforate the LK-3, LK-2, LK-1, and LZ sands; fracture stimulate; run an ESP and postpone start-up until surface equipment hook-up is completed. Surface Location: 2119' FNL & 318' FWL of Sec. 8, T13N, RIOE Depths: All depths are measured from original RKB (49.0') and open hole logs dated 3/20/90. Casing: Surface: 9-5/8", 36 #/ft, J-55, btrs. set @ 6314' Production: 7", 26 #/ft, L-80, btrs. set @ 11,068'. Capacity = 0.0382 bbl/ft Drift ID : 6. 276" Burst Pressure = 7240 psi Tubing/workstr: Misc: 2-7/8", 6.5 #/ft, L-80, EUE 8rd (approx. 10,500' required). Capacity = 0.00579 bbl/ft tubing; 0.0302 bbl/ft annulus ID : 2.441"; Drift ID = 2.347" Burst Pressure : 10,570 psi Torque (ft-lb): Min = 1730; Optimum-- 2300; Max : 2880 3-1/2"i~~tdrill__~ pipe for deepening rathole PBTD = 10,875' (from CCL/GR 5-3-90) TD : 11,078' RA Tag @ 10,297' Pore pressure = 9.6 ppg equivalent (3550 psi) Fluid in well = 10.2 ppg NaBr/Cl Proposed completion-fluid : 11.0 ppg NaBr/Cl (10 deg F TCT) Max Angle : 57 deg; Angle through pay = 54 deg REcE)VED NOV 1 1990 Alaska, Oil & Gas Oo~,s, G~.'B~J-~ Proposed Hydraulic Fracturinq Procedure: · Spot seven 500 bbl frac tanks on location. Elevate the rear of the tanks approximately 8". Visually inspect the interior of the tanks for cleanliness. DO NOT ENTER THE TANKS. Fill five tanks wi th 450 bbls clean injection water. Check pH of injection water in each tank and neutralize if necessary. Fill the sixth and seventh with 275 bbls filtered 11.0 ppg NaBr/C1 completion fluid w/ 4 gal/lO0 bbl Unitreat 3900 biocide/inhibitor for flush. The water/brine should be heated and filtered to 10 microns absolute with a hot oil truck and maintained at 75 to 80 degrees F to insure proper hydration of the gelling agent. Water from the central facility, carried in clean transports is acceptable. 2. Rig up Dowell Schlumberger to perform the frac treatment. NOTE: a. Use of threaded connections, crossovers, swedges, etc. in the treating line is not acceptable. b. Use two in-line densitometers. c. Use two shut-off valves on the wellhead. d. Set the backup pumps for the crosslinker and diesel. e· Standby pumps (50%) are required. These pumps must be manned and primed to come on line immediately if needed. A standby blender should be hooked up and ready to come on line in case of primary blender failure. fe BOP saver installation shall be coordinated by Conoco and DS personnel on-site prior to frac RU. Insure that "donut" is butted against 4" pipe rams prior to pumping. ge Tank bottoms are included in the volumes listed. Plan for 75 bbl tank bottoms. h · Use the in-line densitometer during the treatment. rate, pressure, and density on a chart. Record i · Take samples of the crosslinked gel during the treatment. Place these samples in a bath at 162 deg F. Note the actual break time. Note the pre-pad is not crosslinked and does,~w contain diesel. j · Shut down after pre-pad for meter to tank verification and 15 '- minute pre-job ISIP. k. DO NOT OVERDISPLACE THE TREATHENT UNDER ANY CIRCUHSTANCES. , Batch mix 2250 bbl gelling agent at 50 lb/lO00 gal ~ith additives. The pre-pad consist of non-crosslinked gel (no diesel). Particulate Fluid loss additive (40#/1000 ga]) should be added in the pre-pad and pad fluids Page 4 only. Diesel (5%) and crosslinker activator are the only additives that should be mixed on the fly. Sand (Carbo-Lite) will be added in the prescribed stages through the blender. 4. Hold on-site safety meeting with rig personnel and frac crew to communicate hazards of the operation. 5. Pump the frac job as follows at 40 BPM: Stage Name Stage Barrels Cumulative Treat Pump Proppant Gel Pumped Barrels Press Time (Lbs) (Ea. stage/ Slurry Pumped (psi/ (Min1 Pre-Pad 0 200 200 3100 5.0 PAD 0 1100 1100 4100 27.5 2 PPG Slurry 4790 57 1160 4000 1.6 4 PPG Slurry 10400 62 1240 3800 1.8 ' 6 PPG Slurry 21900 87 1350 3500 2.8 8 PPG Slurry 34800 104 1490 3200 3.5 10 PPG Slurry 49000 117 1650 2900 4.2 12 PPG Slurry 59300 118 1830 2700 4.5 FLUSH 0 400 2230 2500 10.0 6. 7. Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, and pressure for 30 minutes (5, 10, 15, and 30 minute readings). Close all surface valves and leave the well shut in. Insure well is dead. Monitor the break time of the last sample collected. Rig down pumping equipment. ~i.o'~J- ~ HCO~L, After the~~~at~nt there ~s a possibility of proppant ~n the i~~t-oF p~'uppa~L ii~ne~~. If the~t~gs proppant in the perforation interval then GIH with bailer to remove proppant from the well to clear the perforation interval. Use the tubin9 bailer with sufficient barrel length based on fill. ~[ retrieva5~ ~ge ~ ove ,mp 1~~~i~ ~ prepa~ ~. Insure completion fluid is adequately protected against freezin9 and corrosion. Page 5 Proposed ESP and Tubinq Runninq Procedure' · MU ESP assembly on 2-7/8" tubing as illustrated on the attached Otis completion guide. Strap and record the length of each component. Run a standard Centrilift motor centralizer for 562 Series motors and 7", 26 #/ft casing on the bottom of the motor. e RIH w/ ESP no faster than 30' per minute. RIH w/ sliding sleeve in open position. Maintain sufficient hydraulic pressure on the control line while RIH to maintain valves in the open position. Attach two cable bands per joint. Attach additional bands above and below each cable splice. Set the bottom of the motor at 10,535'. · Locate packer and safety valves such that the tubing retrievable SCSSV is at a depth of 500' or greater. Packers should be pinned to begin setting at approximately 1100 psi. Pump 55 bbl of diesel down annulus for 1800' of freeze protection prior to setting packer. . RU slickline and RIH w/ plug and set in "X" nipple located below packer. Pressure up to 1000 psi. Set packer by gradually increasing pressure from 1000 psi to 2500 psi in 500 psi increments. Retrieve plug and POOH. RD slickline. e Pump 11 bbl of diesel down tubing for 1800' of freeze protection prior to closing SSSV' s. e Bleed off control line pressure to close the annular vent valve and SCSSV. Pressure test the packer and vent valve system w/ 500 psi of annular pressure for 10 minutes. Bleed off pressure. e ND BOP's. NU tree. RD and move to next well. Await surface facilities connection for production. Prepared by- Van Li neDerger Sr. Prod. Engineer Reviewed by' Approved by' Marc Shannon Supervising Prod. Engr. D. E. Howell Production Supt. CC' DEH, PMS, MPU Sr. Fm. (2), CVL, Original to File' L-6 ~ell File Page 6 FTE~D NAME: M/lne Point WELL NAME: L Pad "ESP" Ccm~pletio~ CASING: 7" 29 LB L-80 BTC · /3BING: 2-7/8" 6.4 LB EU 8RD x 2-3/8" 4.6 LB EU 8RD 1~: 432/1001/01/90 E~: SeptengDer 17, 1990 PREPAR~D BY: Ray ~havers - Anchorage, Alaska (907) 261-7780 io 4. 2-7/8" 6.4 lb EUE Tubing Conoco Supplied Electric Cable - Size #2 1/4" Stainless Steel Control Line. 0.049" Wall ~ickness x 600' I~ 316 Material (P/N22 SXX 31060) 2-7/8" 2.313" Otis "FM)U' Series iO Tubing Retrievable "Non-Equalizing,, SCSSV, Flapper Closure. H2S Service. Meets NACE MR-01-75, 2-7/8" 6.4 lb EU 8Rd Setting Depths 1000 ' (P/N 778 FMX 23111-E) 2-7/8" 6.4 LB EU 8R~ P~p Joint W/Coupling L-80 Co~binationCoupl~ 2-7/8" EU 8 Rd X 2-3/8" EU 8 Rd BxB P-105 B1-W Power Cable Feed Thru For No. 2 Round Cable. 100 AMP, 2400 Volts, 4 KV Rated. Field Attachable Male Connector and Pc~er Feed ~%ru with a 20' Electric Cable Pig-Tail. (P/N 12 OO 1225) Tubing Seal Sub A~aptor 2-7/32"-14 UNS-2 x 2-3/8" EU 8Rd BxP (P/N 12 O 6722) Otis Annular Vent Valve 3,000 psi W.P. Setting Depth 540', 2-3/8" EU 8Rd BxP (P/N 78 AVS 2001) 2-3/8" 4.6 lb EU 8 R~ Pup Joint P-105 I.Do 2.44" 2.313" 2.44" 2.44" 1.97" 1.83" 1.99" O.D. 3.668" .25" 4.76" 3.668" 3. 668" 25" 2.62" 3.09" ~C. 3.69" 3.06" 600' 7.0' 6.0' .6' 23' 1.8' ~TE: .9~tember 17, 1990 I.D. 11. Otis "RDH" Dual Hydraulic Retrievable Prod. Packer 7" 26-32 lb 2-3/8" EU 8Rd Box x Pin - Primary and Secondary. I~png String Set. (P/N 12 RDH 7003) 1.94" 1.94" Sec. 12. 2-3/8" 4.6 lb ~7J 8t~ Pup Joint W/Coupling P-105 1.99" 13. Otis "X" Selective Lar~ Nipple W/Coupling ~110 (Nipple P/lq 11 X 18700-A "Blank" Thread Corulections for 2-3/8" EU 8 Rd PxP)* a. 2-3/8" 4.6 Lb 5)3 8Rd c~upii~ ~105 1.875" 14. 2-3/8" 4.6 lb ~J 8 R~ Pup Joint W/Co~lirg P-105 1.99" 15. A~aptor 2-3/8" EU x 2-7/8" EUE E~xP P-105 ** 1.97 16. 2-7/8" 6.4 lb 5LqE %~bi~g Conoco Supplied 2.44" 17. Otis circulating Ball Catcher Shear ~ab. Shears at 1,000 psi Diff. Pressure. "Blank" %~.~ead connections for 2-7/8" ~ Kb<B)* 1.29" Option to It~n 17 17A. 2-3/8" Otis '.~' Slid/ng Side Door (Oper~ b_~/Closes Dc~n) Not Shc~n on [k-awing 1.875" 18. One (1) 2-7/8" 6.4 lb ELFE Joint of ~abing or Pt%o Joint-Conoco Supplied 2.44" 19. Electric ~ible I~ O.D. 5.95" 3.06" 3.06" 3.06" 3.06" 3.76" 3. 668" 3. 668" 3. 093" 3. 668" PAGE2 L~NC~t 7.1' 2.0' 1.0' 4.0' .6' .S0' _.Et' RILI.FT EQUIPMEN_ Q .JTATION A Baker Hughes company 200 W. Stuart RooEa Dr. · Claremore, Oklahoma 7401 7 · (9181 341-9600 DATE 8-03-90 CONOCO, INC. QOOTATtON NO. D2213-06-22-3190 ___ --' 32~1 -"C" Street _.. L' I PRESENTED BY S. Hess;er Anch-ora,~;e,. AK 99503 6798 71. A'I'TN: , Van Linebe, rger WELL NAME: L--6 FIELD NAME: Kuparuk ~OCATION: Deadhorse, AK - SP.G~. '.97 PERF$ Below mcr. SE]-~iNG DEPTH 7002- V' ~:,Oc~ ~0 il ~---~-~- ],7.5 PRIMARY VOLTAGE ~80 REO. SURFACE VOLTAGE ~~OUIR~D KVA ~ NE~LIFT SURFACE PSi ___ FRICTION LoSS T.D.H. Varies vOLTAGE SERIES FRt~QUENCY ~ 60 HERTZ "'~- 50 HERTZ MOTOR H.P. lO0 2145 AMPERAGE 27 NO.~CS. 1 RATING 562 MODEL ~ LENGTH 12.0 842 PUMPSTAGE$ 7~~ ~PE FC-650 HSG, NO. 12 NO,~C$. 1 .-226 SaRIES 400 MOO~L FPU LENGTH 19.2 582 PUMP INTAKE SER',ES MODEL L~NGTH PUMP DSCHRG. SERIES MOD~L LENGTH CONN SERIES 400 MODEL FRSX LENGTH 2,89 75 ' 263 GAS SEPARATOR SEAL SECTION SER!ES 5']~3 MOOEL GSB- 1 LENGTH. POWER CABLE .A'WG TY,r;;c_ .E,NG rH A;RMOq FLATCABI.,E SER:E5 544 T'r~E KT-3 ~.---,'4GT~. 35 ' FLAT GUARDS ' Adaptor 400 x 513 CABLE BANDS CABLE 8ANDS SWAGED NIPPLE CHECK VALVE DRAIN VALVE EQUIPMENT COATING: MOTOR CONTROLLER AC~CE$$ORI ES ~NCLUDE: LENGTH TYP~. MODEL OVERLOAD .AUTO RESTART L-. LIGHTINGARRESTER" OTHER VARIABLE FREQUENCY CONTROLLER: 200 KVA "rcs TRANSFOR HERS SIZE TYPE PRIMARY TAPS SIZE VOLTAGE UNDERCURRENT S.D. '-, RECORDING AMMETER '" SECONDARY TAPS VARIABLE FREQUENCY TRANSFORMER 200 KVA 5 KV ~ + JUNCTION BOX fVENTED-SAFETY) TUBING HEAD :Kage ?HD 5i~uctor Package CONOCO Mods CABL~ GUIDE Discount CABLE REEL NO. REEL SUPPORT SHIPPING CASE QTY. SIZE SHIPPING CASE QT"( S;7_.£ SHIPPING CASE QTY SIZE f SHIPPING CASE QTY. SIZE T NOTE: SERVICING EOUIPM~N,T MAY 8E AETUF~N£O FOR 100'4-, CRE'I~IT WITHIN d MO. 5UBJ¢;CT TO ,A ¢,EPAIR CHARGE ¢..QUAL TO 25%OF THf~ , ~.'~T PRICE., 64.~ H~ 59.tl ti;, ?0¢0 5000 5000 CONOCO ~ILNE POINT 71 .~ VSC System Performance L-6 _ . ~ _ PUMP __ FC650 I"iOTO~ (6,') Hz ~62 ~r'l~ 103 h~ 1235 volt 4~ amp __ _ 2000 , 100 2OO 300 400 ' 500 BEN D, GOULD ~oo ?oo ~oo ~oo ,ooo ~oo 1200 I 1~00 BPD ! _ ~ ooJo] i, , . , f I 2.) : ; O'OoOc OOOO¢2' ¢ ..... (WWH[3 >Hd{2 I 0'0002 00002' < Ww~O ) P,'13.g 0'0002 00002' ......................... ('~ ~'H'~ 5 ~-~ ~-z ......................... o'o0o¥ 'ooot,~: ........ '(- ')iz'i ~ ~'~2i ......... ! . ~- o'o o'ooos1 1 I O0'O01 0'0 i <IdUg> 892 I 0 ~ 0 ~ O~ Checked Da:c- Conoco inc Calculation Sheet Interoffice Communication TO: FROM: CVL - DATE: October 11, 1990 SUBJECT: MPU L-2, L-l, L-5, L-6 Completion Procedures - Summary of Changes The procedures are basically the same as the L-3 procedure. The frac design has changed slightly. These designs go up to 12 ppg proppant. Also, the gel concentration has been increased from 40 to 50 # loading. I've attached a 40 # L-2 design so that you can see the benefits of going to 50. Apparent viscosity increases from approximately 200 to 300 cp at our temperatures with this revision. I am still working on Proposed and Blank Well Schematics. them Mondayish. I'll circulate If we see anything that calls for an adjustment from well to well as we progress, I'll propose addendums. As of now, our plan is to move EWS to L-5 and then L-6 upon completion of the L-3. Pool will rig up on L-2 and then move to the L-1. The Pool rig is better equipped (rotary table, etc...) to handle the L-1. The Pool rig will then go to H-Pad and EWS will kick off the worKovers and possibly knock out G-Pad. Let me assist you should you have questions. · an Lineberger Sr. Prod. Engr. R CEJVED NOV 1 5 1990 ch0ra '"' ..... r--I CURE I ! EXPLOSIVES m Field Sa~et? Procedures ~ Schlumberqer · . . Voltage Mom,tot ~a r~admg m I. Check to Me t~at Imertormtu~ leg, than 0 2.5V [] eqUJl:m~ent tS loaded and of pr°per (h) Clear line of fire of all [] siz.~ and deSCnpuon, personnel. m 2. Check to s~ that prtqsure control (i) Attach CST or F'T to cable [] eqkupment is complat~ and of head and proc'et,~ m hole. ~ proper ~z~. (j) Or attach Sharpshooter or I s. Check to ... i~ op.. ~oia ~oo a~ ~S.T ~to 5o,!;. ,o~. ~o~ _a?d I avmilble for proper depth control, caole nema. r~t~ea in note. .5. Armmg SC and aCE Gur~ [] B. ARRIVAL AT LOCATION (a) Cica, I,ne o~ ~,,e of all ~ per~onnei. [] 1. Hold spot &l~ety meetir~. (b) Check. concactor w,r~ for m 2. Hold consultation with client if i~oMmle sDarxinl[. . · pc~lbte (c) l'nm c-~n,-c~or w~r~l · Dr IZT~lCOrd ~ 3. Check well area for hazami~ and .... n~e i~t,n ca ,n Blur W -- __~ .. . Tam w,re ieao~. [] (,;, I'I~':L -"ij%.l'l:.lI ~U~lL) (e) Cormec~ Olutm~t cap leacta to m O~:TE~T'~ONA~ EOg"~'~l~ ~ lead w.r%.~. [] (f) Re,move o~uuna, cap from m 1. No smokmg except in ~errn,,,.lbie Safety I...ommn~ Tube I areas. ~mokmg mater'ta~ to be cmmD to p~macor~l. .= stored when leamg me~ areu. Blutlng Cap Cnmoln~ Pliem. [] 2. Ri~ up cnble. Remove ng winn~ (g) PreDare gun ~or ,-.~r m that masht contact mae. . ,cai. ~ 3. Check ri~ and Schlumbe~er umt (h) Proceed mto B for stray voltage. £1imxnate ~f 6. Omeratmna] Proc~lure m Hole _, pre~enL Ir,,Jtall safety grounding (a) At 100' depth, turn on &atetv ~ strap a_.-ld recheck. Instill Ca~mg- sw~tch, start AC generator mm to-Ri~ Voltage Mom~or. Do not Watch c~mg coders to [] proce~ w~th operauon d re~du~ torn. Fie ,n an° recor~ c~uar [] volta~ ts tn excen~ ot 0.2.5V. log. ~ 4. Prepare to attach explo~tv~ dev'~'~. (b) Pc~mon ~un and shoot. [] fa) Turn o~t safety sw~tci~ and (c) Come out of hole---~mo at "~ ~v~ key to r~ door ooer~tor. I00' and re,eat ,-~ietv [] (b) ~hut ott' AC Renermr~r. [atmn C-4 ia mmuin l~ ~ (c) Turn off ma~n circuit (d) Turn o~ USP. PSP. GSP. D. C051PLETION OF ~ lei ~.)]J(:onnec~ L,.~IL-' ~ LT~3 brought to the weU ,s [oaoe~ ~ ot.l~r panel~ not used for rn t · truck [o be renu ed o ID m (f) Tufa orl all radio trans- 2. Polic~ the area for Drlmacord I mit'-~rs, r~mnant~, char~es. Ir,,=h. etc. q~immmmmmmmmmmsmmmmmm m mmmmns~ CONFIDENTIAL :f SCHLUMBERGER WELL ~ERVICES DIVISION OF ~CHLUMBIrRGER 'rE:CHNOL.OGY COf~PORATION HOUSTON. TE:XA5 77251-2175 I~LEAB~ REPLY TO ~LU~BERC~ER WELL Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Affention:. Marc Shanno~ Gentlemen: Enclosed ore_Z_BL_prints of the Company CONOCO, Inc, Well Milne Point Unit L-6 Field Milne Point Additional prints ore being sent'to: I BL prints - ~ CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 At,n: George Lamb - OF 2018 PER. 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5600) GGT, Run ~,ay5/03/90 CCL/Gamma Log, Run 1, ~/03/90 On: County Nnrth $]oP.e' State_ Alaska '~- ; rint~, :1 KF Sepia :::~: :7:(.i;.,'i000 South:Pine , ,, '~ -';;: Ponca CIt~ OK 7~603 : .... -. nrints _A_]iL_prints, 1 RF Sepia Chevron U.S.A. 6001 BollJnger Canyon Road San Ramon; CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) 1 BL prints,~- t:-I~-F~:Se~Ia-~'~ Alaska Oil & Gas Conservation .... 'Commission · 3001 Porcupine Drive Anchorage. AK 99501 Attn: John Boyle The film is returned to Conoco, Log Library. prints prints Rece~ red by; Dar e: MAY - B 199u We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT UANAGER SWS-- 1327-F Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 April 1, 1990 Mr. Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Letter of Application Conoco is requesting to shut down well operations on the L-6 well until we can move the drilling rig far enough ahead of the workover rig to conduct completion operations. The cement plug was bumped, casing was pressure tested, the tree was flanged up and tested and the well was shut in. Sincerely, D.L. Mountjoy Senior Drilling Foreman DI~/dj w STATE OF ALASKA r~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator CONOCO INC. 3. Address P,0, Box 340045, 4. Location of well at surface 2119' FNL, 318' At top of productive interval Prudhoe Bav. AK FWL, SEC 8, T13N, Operation shutdown -.X-- Re-enter suspended well __ Plugging __ Time extension ~ Stimulate Pull tubing ~ Variance __ L 5. Type of Well: Development ----X Exploratory __ Stratigraphic ~ g g 7.'% Service __ RIOE, UM At effective depth GYRO SURVEY At total depth NOT PRESENTLY AVAILABLE i2. Present well condition summary Total depth: meas'ured true vertical Effective depth: measured true vertical _ Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6277' 11,036' measured 11,091' feet 7,268'* feet 10,983'PBT~eet 7335.8'* feet Size 13-3/8 480 Plugs (measured) Junk (measured) Cemented SKS PERMAFROST C Perforate ~ Other true vertical Tubing (size, grade, and measured depth) *NOTE: DATA, NOT Packers and SSSV (type and measured depth) N/A 13. Attachments N/A Measured depth 9-5/8~26 BBLS PERMAFROST E / /._84 BBLS PERMAFROST E 7" 65 BBLS CLASS G TVD DEPTHS ARE BASED ON FROM GYRO. 6. Datum elevation (DF or KB) 56' KB MSL 7. Unit or Property name M!LNE POINT UNIT 8. Well number L-6 9. Permit number 90-10 10. APl number 50-- 029-22003 11. Field/Pool KUPARUK RIVER FIELD True vertical depth 115' 115' 6,314' 4,587' ',-APR 1 2 .& 6as Cons, '.., nchorage MWD DIRECTIONAL Description summary of proposal ~ Detailed operations program 15. Status of well classification as: Oil '/ Gas__ 14. Estimated date for commencing operation ,lillY 1.~_ lqq¢l 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,4~,~,¢~,¢'~'"~/~Title .l:'NTl"l...TIITNR FdRFMAN " - / / FOR COMMISSION USEONI_Y ............. feet Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 1'"~7- /}o4 Commissioner ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH BOP sketch __ SuspenderS;... Dat~_ 3/__.8/90 JApproval No. ,~¢ .-..m~ / Approved Copy Returned Date - -/¢':'/)__.. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ALASKA OIL AND GAS CONSERVATION COMb, ,ON ~; :. ;, REPORT OF SUNDRY WELL OPERATIONS' 1, Operations performed: Opera!ion shutdown .~ SIimulale __ Plugging Pul! ruing ~ Alter casinc~ __ Repair well ~ Perforate __ Other __~ 2, Name of Operator CONOCO INC. 3. Address P.O. Box 340045, Prudhoe Bay,._AK 4. Location of well at surface 2119' FNL, 318' FWL, SEC 8, T13N, At top of productive interval 9973z 5. Type of Well: Development --X Exploratory __ Stratigraphic __ Service ~ At effective depth Gyro Survey Not ~ total depth Presently Available 12. Present well condition summary Total depth: measured true vedica~ 11,091' fe~ 7268'* ~ Eff~Uvedepth: measured 10,983' PBT~et true~dical 7335.8'* feet Plugs (measured) Junk(measured) RIOE, UM 6. Datum elevation (DF or KB) _ 56' KB MSL Z Unit or Propedy name i~ilne Point Unit 8. Well number 9. P~'r~t number/aj:)proval number i0. AFi~nu~n~r ,/ ' 50-- d29-2208~ . 11. Field/P~l Kupa~uk River Field Casing Length Structural 80 ' Conductor Surface 6277' Intermediate Production 11,036 ' Pedoration depth: measured Size 13-3/8 480 9-5/8 L84 7" 65 Cemented Measureddepth ~uevedicaldep~ SKS PERMAFROST C 115' 115' BBLS PERMAFROST E BBLS CLASS G 6,314' 4,587' BBLS CLASS G 11,068' 7,321' feet true vertical Tubing(size, grade, and measured depth) *Note: TVD depths not from Gyro, Packers and SSSV ~pe and measured depth) 13. Stimulation or cement squeeze summary IntervaJs treated (measured) N/A Treatment description including volumes used and final pressure are based on MWD directional data, 14. Prior to well operation N/A Subsequent to operation .Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Repeal of Well Operations 16. Status of well classification as: Oil ~ Gas ~ Suspendedi~ Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE Kuparuk River River Field - North Slope Borough, Alaska W.I. 100% Milne Point L No. 6 CONFIDENTIAL AFE 10-61-1194 API No. 50-029-22003 Ak. Permit No.90-10 Elevation 56'KB MSL Location: 2,119' FNL, 318' FWL, Sec 8, T13N, R10E Umiat Meridian MARCH 7, 1990 MOVE RIG, TAKE ON SPUD MUD, INSTALL DRAG. NU DIVERTOR, MODIFY BELL NIPPLE, FUNCTION TEST DIVERTOR, NU FLOWLINE, PICKUP BHA. DRLD OUT ICE. ORIENT MWD. DRLD F/l18 TO 243. DAVID MOUNTJOY Daily Mud Cost: Daily Cost: $ 2,147 Cumulative Mud Cost: $ 2,147 $ 171,172 Cumulative Cost: $ 171,172 MARCH 8, 1990 DRLD F/243' TO 534'. POOH CHANGE OUT MWD (FAILURE IN PULSATOR). DRLD F/534' TO 1566'. SHORT TRIP 9 STANDS. DRLD F/1566' TO 2132'. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 2,305 Cumulative Mud Cost: $ 4,452 50,025 Cumulative Cost: $ 221,197 MARCH 9, 1990 DRLD F/2132' TO 2226'. POOH 3 JTS, REAM F/2137' TO 2226', REMOVE EXCESSIVE DOGLEG. DRLD F/2226' TO 2637'. SHORT TRIP 12 STANDS. DRLD F/2637' TO 3810'. SHORT TRIP 34 STANDS. DRLD F/3810' TO 4344'. LOST 400 PSI PUMP, TEST SURFACE EQUIP, POOH WET LOOKING FOR HOLE. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 3,964 Cumulative Mud Cost: $ 8,416 37,599 Cumulative Cost: $ 258,796 MARCH 10, 1990 POOH LOOKING FOR WASHOUT, NONE, RIH. DRLD F/4344' TO 5449'. SHORT TRIP 12 STDS. DRLD F/5449' TO 5531'. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 4,004 Cumulative Mud Cost: $ 12,421 37,435 Cumulative Cost: $ 296,231 MARCH 11, 1990 DRLD F/5541' TO 6047'. CIRC FOR WIPER TRIP. DAVID MOUNTJOY 3,145 51,992 Daily Mud Cost: $ Daily Cost: $ Cumulative Mud Cost: $ 15,566 Cumulative Cost: $ 348,223 %PR 1 MARCH 12, 1990 CIRC BOTTOMS UP, PUMP DRY JOB. WIPER TRIP TO 500, WORK TIGHT SPOTS F/2000' TO 2500', 25K. OVERPULL, SLM NO CORRECTION. CIRC AND COND HOLE, PUMP DRY JOB. POOH TO 2460, HAD TO PUMP AND WORK OUT TO 2000', PULLING 150K OVERPULL, RIH, GRAVEL WAS RUNNING. CIRC AND COND. POOH, LAYED DOWN BHA. RU TO RUN CASING. RAN 50 JTS CASING. WORK ON SKATE, 22:30 TO 24:00 RUN CASING. DAVID MOUNTJOY Daily Mud Cost: Daily Cost: $ 3,873 Cumulative Mud Cost: $ 19,439 $ 174,588 Cumulative Cost: $ 522,811 MARCH 13, 1990 FINISHED RNG 151 JTS 9-5/8" 36# J-55 BTRC CSG. CIRC. CEMENTED STG 1 WITH 923SKS E AND 330 SKS G, SHOE @ 6314, FLOAT COLLAR @ 6224, STG COLLAR @ 1884'. BUMPED PLUG TO 2500, OPEN DV @ 3000 PSI. CIRC, HAD 20 BBLS OF CEMENT RETURNS. CEMENTED STG 2 WITH 539SKS E AND 80SKS G, 40 BBLS RETURN, CLD DV. RD CSG CREW AND CEMENTERS. ND DIVERTOR AND NU BOP. TESTING CHOKE MANIFOLD AND BOP TO 500 AND 5000~ ND TO CHANE API RING IN STACK. Daily Mud Cost: $ 0 Daily Cost: $ 201,499 Cumulative Mud Cost: Cumulative Cost: $ 19,439 $ 723,310 MARCH 14, 1990 N/D STACK, CEHCK RX RING AND GROOVEAND CHG OUT RX RING. ATTEMPT TO PRESSURE TEST -- FAILED. N/D STACK, CHECK RX RING AND GROOVE -- OK. N/U STACK FINISH TESTING BOP'S. RUN WEAR BUSHING B/U BHA, TURBINE, & MWD. ORIENT TURBINE&MWD. SLIP & CUT 110' OF DRILL LINE. TIH TO 1870' & DRILL OUT 10' OF CEMENT AND DV TOOL. TIH TO 6215' & DRILL CMT TO FLOAT COLLAR & 6223'. CBU & TEST CSG TO 1600 PSIG FOR 30 MIN. -- OK. DRILL FLOAT COLLAR, FLOAT SHOE, & 10~ OF NEW FO~4ATION. PERFORM FORMATION INTEGRITY TET TO 13.5 PPG EMW AT 6335'. DRLG F/6335' - 6648'. DAILY MUD COST: $ DAILY COST: $ MARCH 15, 1990 DRLG F/6648'- 7341'. SHORT TRIP 12 STDS. DRLG F/7341' - 8318'. SHORT TRIP 12 STDS. DRLG F/8318' - 8571'. 2,715 CUMULATIVE MUD COST: $ 22,561 49,709 CUMULATIVE COST: $ 783,775 (NO HOLD PROBLEMS -- NO FILL). ...... ..,~, Oii ..,.5: ~"°...,~.~ OOiiS, gOgli-~ti$SiOic (P/U BALL AROUND STAB. -- NO FILL). DAILY MUD COST: $ 5,204 DAILY COST: $ 46,107 CUMULATIVE MUD COST: CUMULATIVE COST: $ 27,765 $ 829,882 MARCH 16, 1990 DRLGF/8571'- 8613' SUSPECT WASHOUT DUE TO DEC. IN STD PIPE PRESS., SURFACE EQUIP CHECKED OUT OK. POOH WET 27 STDS, WASHOUT IN SLIP AREA OF JT. #142 RIH TO 8613' (HOLE IN GOOD SHAPE -- NO FILL). DRLG F/9262'- 9459' SHORT TRIP 12 STDS. (HOLE IN GOOD SHAPE -- NO FILL). DRLG F/9459'- 9785' DAILY MUD COST: $ 5,076 DAILY COST: $ 47,029 CUMULATIVE MUD COST: CUMULATIVE COST: $ 34,404 $ 876,886 MARCH 17, 1990 DRLG F/9785' - 9997' SHORT TRIP 6 STDS. (NO HOLE PROBLEMS -- NO FILL). DRLG F/9997' - 10186' SHORT TRIP6 STDS. (NO HOLE PROBLEMS -- NO FILL). DRLG F/10186' - 10320' DAILY MUD COST: $ 5,388 DAILY COST: $ 49,731 CUMULATIVE MUD COST: CUMUALTIVE COST: $ 39,792 $ 926,617 MARCH 18, 1990 DRLG F/10320' - 10524' POOH L/D TURBINE, CHG. OUT JARS, CHG. BIT. M/U NEW BHA & CHG. OUT MWD TOOL. TEST & ORIENT MWD TIH TO 5200', CBU, TIH TO 10390', WORKED TIGHT SPOT AT 8510'. CBU WHILE WORKING PIPE, RIH TO 10400, PACKED OFF AROUND STAB~ PIPE STUCK, WORKED PIPE FREE WHILE JARRING 400k. DRLG 10440' - 10524' DAILY MUD COST: $ 2,034 DAILY COST: $ 40,401 CUMULATIVE MUD COST: $ 41,826 CUMULATIVE COST: $ 967,019 MARCH 19, 1990 DRLG F/10524' - 10705' SHORT TRIP 10 STDS. (NO HOLE PROBLEMS -- NO FILL). DRLG F/10705' - 10786' SERVICE RIG ~,~.~ DRLG F/10786' - 11091' (TD -- ESTIMATED 481' RATHOLE BELOW BLK) CIRC & COND HOLE FOR WIPER TRIP TO SHOE NOTE: CALLED 10091' TEMPORARY TD UNTIL LOGS SINCE THE LK1 TOP WAS CUT 75' HIGH. THIS CAN BE ATTRIBUTED PARTLY TO DIRECTION RUNNING 40' LOW VERTICALLY AS WELL AS GEOLOGICAL PROGNOSIS RUNNING 35' DEEP. DRLG F/10524' - 10705' SHORT TRIP 10 STDS. (NO HOLD PROBLEMS -- NO FILL). DRLG F/10705' - 10786' SERVICE RIG DRLG F/10786' - 11091' (TD -- ESTIMATED 481' RATHOLE BELOW BLK) CIRC & COND HOLE FOR WIPER TRIP TO SHOE NOTE: CALLED 11091' TEMPORARY TD UNTIL LOGS SINCE THE LK1 TOP WAS CUT 75' HIGH. THIS CAN BE ATTRIBUTED PARTLY TO DIRECTION RUNNING 40' LOW VERTICALLY AS WELL AS GEOLOGICAL PROGNOSIS RUNNING 35' DEEP. DAILY MUD COST: $ 4,062 DAILY COST: $ 37,803 CUMULATIVE MUD COST: $ 45,888 CUMULATIVE COST: $1,004,822 MARCH 20, 1990 PUMP DRY SLUG, BLOW DOWN KELLY. WIPE TRIP TO CSG SHOE (NO OLE PROBLEMS--NO FILL). POOH (SLM--NO CORR NECESSARY). CLEAN RIG FLOOR AND LOGGING EQUIP. LOGGING DITE-CNL-LDT-NGT-CYBERLOOK. NOTE: RUN #1 LOGGER td 11078'. RUN #2 TOOL STACKED UP @ 10420' (UNABLE TO REPEAT). CALIBRATE LOGGING TOOL AND R/D SCHLUMBERGER. SERVICE WEAR BUSHING. RIH TO 4000', CBU. RIH TO 8000', CBU 2X. RIH. JOE POLYA DAILY MUD COST: $ 1,518 DAILY COST: $ 109,078 CUMULATIVE MUD COST: $ 47,406 CUMULATIVE COST: $1,113,563 MARCH 21, 1990 FINISH CIRC 2X BU AT 8000'. RIH TO 11090' (NO FILL). CIRC AND COND WHILE WORKING TIGHT PIPE. POOH 12 STD SHORT TRIP AND RIH TO 11090 (NO FILL). CIRC ~ND COND MUD. SET BACK 10 STD IN DERRICK (NO PROBLEMS). PUMP DRY SLUG. POOH L/D DRILL PIPE. RIH WITH 10 STDS F/DERRICK AND L/D. CHANGE TOP PIPE RAM BLOCKS F/5" TO 7". L/D BHA AND KELLY. KELLY TO TOWN FOR MAGNA FLUX AND STRAIGHTENING. R/U CSG CREW EQUIP, ALIGN ROTARY OVER HOLE AND SAFETY MEETING. RIH WITH 50 JTS 7" CSG TO 2194'. JOE POLYA DAILY MUD COST: $ 1,426 DAILY COST: $ 52,035 CUMULATIVE MUD COST: $ 48,833 CUMULATIVE COST: $1,208,453 MARCH 22, 1990 RIH W/ 7" CSG TO 4200'. BREAK CIRC--PUMP 2~0~.~~.,,.RIH WITH 7" ooo,. ooo ~:~.~=~ , ~ ~ CSG TO ~ ,~{~chora~a 10800--LOST TOTAL DISPLACEMENT RETURNS. RIH LAST 6 JTS WHILE BREAKING CIRC AT 10920' ON JT #253, RAN LAST 3 LTS AND LINER HANGER ON RUNNING JOINT. REESTABLISHED CIRC WHILE RECIPROCATING CSG 15' TO 310,000# P/U (+/- 43000# DRAG). PUMPED 6000 STKS BEFORE LANDING HANGER DUE TO EXCESSIVE P/U WEIGHT (345,000). PUMP CMT JOB AS FOLLOWS: 60 BBLS 11.5 SEPIOLITE SPACER. PUMPED 5 BBLS H20. DROPPED BOTTOM PLUG. PRESSURE TEST SURFACE LINES TO 3500 PSIG. PUMP 5 BBLS H20 BEHIND. PUMPED 65 BBLS 15.8 PPG CMT "G" PREMIUM. DROPPED TOP PLUG, CHASED W/ 5 BBLS H20. PUMPED 340 BBLS NACL2 AND 70 BBLS DIESEL FOR DISP. BUMPED TOP PLUG WITH 3000 PSIG FOR 10 MINUTES. R/D HALLIBURTON AND CSG CREW EQUIP CLEAN AND CLEAR RIG FLOOR. SET PACK OFF, CHANGE RAM 7" TO 5", ND BOP'S, CLEAN PITS. FLOAT SHOE AT 11068' RKB, PBTD @ 10983' . DAILY MUD COST: $ 1,709 DAILY COST: $ 255,186 CUMULATIVE MUD COST: $ 50,542 CUMULATIVE COST: $1,463,639 MARCH 23, 1990 N/U AND TEST TREE, CLEAN PITS, FREEZE PROTECT ANNULUS WITH 60 BBLS DIESEL. NOTE: RELEASE RIG @0730 HOURS WITH 8164 GALS OF DIESEL. DAVID MOUNTJOY DAILY MUD COST: $ 0 DAILY COST: $ 21,705 CUMULATIVE MUD COST: $ 50,542 CUMULATIVE COST: $1,485,344 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Marc Sh~nno~ SCHLUMBERGER WELL SERVICES A DIVIS, IC)~I OF ~CHLUMBE:RGER TE:CHNOI~Y COR~ATION HOUSTON, TEXAS 77251-2175 Iq. EAIZ REPLY TO ~-,HLUMBERGER WELL ~ERVICES Prudhoe Bay, ~K 99736-0069 ~ttn: Bernie/Shelley C~ntlemen: Enclosed are 2 BLprints of the Company CONOCO, Inc. Well Milne Point llnit T.-fi Field.. Milne Point ,~lclitionol prints ore being sent to: i BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PEK DITE/NGT/Raw Data/Porosity/Cyberlook, ..... 1, 3/2r~''~,.,/~v County North Slope State. Alaska 1BL prints, 1RF Sepia CONOCO, Inc, 1000 South Pine Ponca City, OK 74603 Attn: Log L~hrary on: 1BL prints , 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol * (915/685-5§00) 1BL prints , 1RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy * (4i5/s42-iooo) nrints~,?~l= :' t~t ~ask~.-~ii: A Gas Conservation~ Co~ssion 3~1 Porcupine Drlve ,~'chorage, ~ 99501 Ab~n: John Boyl~ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints CLtlVEU Date: ':d;~ska ;)il & 6'.~s Cons. C0mmiss[0~ Very truly yours, SCHLUMBERGER WELL SER~~.qe David M. Saalwaechter DIGTRICT MANAGER ~--1327-F January 4, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Foreman Conoco Inc Pouch 340045 Prudhoe Bay, AK 99734 Re: Miine Pt Unit L-6 Conoco Inc Permit # 90-10 Surf Loc 2119'FNL, 318'FWL, Sec 8, T13N, R10E, LrM Btmhole Loc 2460'FSL, i291'FWL, Sec 4, Tt3N, R!0E, UM Dear Mr Rainwater: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V ~ery. tru~ y ~your s, . C V Chatterton Chairman Alaska Oil and Gas Conservation Co~_n~mission BY ORDER OF THE COPSMISSION jo Enclosure C; Department of Fish & Game, Habitat Section - w/o enci Department of Enviror~ental Conservation - w/o eric! January 2, 1990 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE' Drilling Permits for L-6 Dear Mr. Minder' I have attached a check to cover the application fee for the L-6 well. Should further information be required for these applications, please call me in Anchorage at 564-7616. Very truly yours, ~Copel and uction Superintendent Attachment t ALASKA_OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 '-la. Type of work Drill ~ Redrill d lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry ~ Deepen~1 Service Iq,., Developement Gas [] Single Zone ~r Multiple Zone ' 2. N;arne of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO INC. KB 35 feet Kuparuk River Fie 3. Address 6. Property Designation Pouch 340045, Prudhoe Bay, AK 99734 ADL 47434 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2119'FNL,318'FWL,SEC 8,T13N,R10E,U.M. Milne Point Unit Blanket At top of productive interval 8. Well nurpber Number 2210' FSL,950'FWL,SEC 4,T13N,R10E,U.M. L-6 8086-15-54 At total depth 9. Approximate spud date Eo~unet / 2460'FSL,1291'FWL,SEC 4,T13N,R10E,U.M. February 5, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed d(~)th(MD a.d TVD) property line 950 feet ].08' f/L-2 @ Surf.feet 2560 7345'TVD/].l,166'f~t 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Kickoff depth 660 feet Maximum hole angle 550 Maximum surface 3200 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling lLength MD TVD MD TVD (include stage data) 30 13 3/8 48. H-40 Weld 80' 35 35 115 115 '+485 sks Permafrost C 12 1/4 9 5/8 36 J-55 BTRS 6294 35 35 6322 4541 +770 sks Permafrost E +293 sks Class G 2nd .~;tage ±~90 si<., Permafrost b +/~ sks Class G 8 i/2 7 26 L-80 u~K~ ]i138 35 35 ii66 7345 +330 sks el'ass G : Down Squeeze' +180 sks Perm~frosL C 19. To be completed for Redrill, Re-entry, and Deepen Operations. - Present well condition summary -!-60 bbls Dead Crude Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor REC£1VED Surface Intermediate DEC 6 Production Liner ,~i~$~ Oil & ~t$ COB~. Perforation depth: measured true vertical Pit Sketch X 20. Attachments Filing fee ,zX Property plat EX BOP Sketch ~ Diverter Sketch EX Drilling program EX Drilling fluid program ~ Time vs depth plot ~ Refraction analysis E] Seabed report E3 20 AAC 25.050 requirements EX _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,_ ~.~,~--~ Title Senior Production Foreman Date12/15/89 Commission Use Only Pe'rmit N~umber I APl number { Approval date {See cover letter 50--0.2, -- Z,~'~:24::~._~ { 01/0Z~/90 {for other requirements I ? . .. ConditiSns of approval Samples req.uire, d ~ Yes ~ No Mud log required E! Yes ~,~':'No Hydrogen sulfide measures ~.' Yes /,~No Directional survey required ~Yes E2 Nt) Required working pressure for B¢~-,E' .,~2M; ~ 3M; [~ 5M; © 10M; [] 15M Other: ~ 'J //-///"// ' '/ ~' /' by order of Approved by ( _//~~... , ( ~~-- Commissioner the commission Date/.,~/Z~. Form 10-401 Rev.'~7~-l-~'5/ :riplicate R T H VICINITY MAP PAD L SECTION 8~ TI3N. RIOE, AS-BUILT UI~ IAT IV. ERI DIAN LOCATION IN SECTION ?,'ELL : FROM NORTH LINE i FROM Y,'EST LINE i i 1970' 158' · ~ i 2. o7.~ ~ :;z2 . t~/ ..... ....~. ............. ........................... ......... . STATE PLANE COORDINATES WELL ~ NORTHiNGS ~ LASTINGS : : I : 6, 03 I, 499.2 · : · , : ZONE 4 544,758.7 CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER ~Y SUPERVISION, D THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. SURVEYED FOR: CONOCO I" = ~00~ T 13 N R 9 E ¥ 13 N R 10 E T 13 N R 1 1 E MILNE POIN~ ? ........... ! ~1,1 1, , ,1,, iiii ,1 mi 2! iiiii "~-~ iiI i I ii i · ~ I I IJ J I ® CONOCd ET AL .G 111 7 8 ~ . ~-255~ 2533.C ADL'47434 2560 AC _ ADL'47433 ~60 AC. aD~743~08 A% ~ "CO CONOCO ET A CONOCO ET AL 18 17 16 15 14 13 ~ 15 + + -- _ 23 24 1~ 20 ~I 22 23 24 21 22 ADL-25516 ADL-47439 ADL-3158~ AOL-315a41 1280 AC ADL-47437 2560 AC ADL-47438 2544~C 1280 AC .1280 ACl ~-25514 25~0 AC AOL-25515 2~4 AC 1280 AC , , , ,, i ~ Ex~ ~ = ~O m~ A~-25517J ~ 2560 AOL-28231 2555 AC t "~ 2235 AC ~20 ADL-25~ 25~O AC ADL-25518 AC UNIT 35,744 A¢-',~ 6/84 6 I IBIT A lINT UNIT AREA t Meridian.Alaska I 2 Scale ARCO MUO THOUGH ' ,.__ I, [ MUO CLEANER wATER PUMP HC, L.E FI~.L ~$ p:j~ , HOLE FILL TANK I I- . VA" UL.M ~IX CH,r. aGE PbM,'~ 2 I::Uk'P I i ,. CH^~GE ---4/t-- --.b4-- .~(~ Cl.'- AGITATO~ HUT T£~FLY VAL'./~ GATE VALVE laud GUN PSV ~CT~ON V~VE ~C~C~ CR DISCH~G~ I ~ VAL~ ) I SuED FO~ CuST ~P~ROv~L MILNE POINT UNiT BOP STACK FOR 9-5/8" SURFACE CASING FILL-UP LINE I FLOW LINE ANNULAR PREVENTER (1) APl ~0004 L · 13 '/~ APl 5000 RAM lOP !$$/i" AP I $000 ~ (2) (3) RAY DOP APl $000~' · '11' APl ~,000 B.0.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to - ,m' iP~ soooe include a minimum of one set of blind rams and two sets of appropriate pipe I!:':: · '°- ..'.:. ,,ECEIVED (5) Choke and kill _ ,~ ~t~_~ mani folds shown !i'.": :': ": " :' ' - ' DII.& Gas Cons, Oommts~t~p z RP .53 c ] a s s 5M "'".' DEC26 t:~0 . _:~.eparately '" "' ]~ll~i0r~g8 requirements. 11o. '.,'.. !1 -,. /' KILL MANIFOLD FROM RE),IOTE HIGH PRESSURE PU,'AP NOTE: I. H~RAUUC CC, NT~OL S~STE~ FOR eOP ST.~CK ~ C~O~ ~ANIFOLO TO INCLUDE' (51 STATI~ CCNTROL MANIFO~ L~ATED REMOTELY WITH ~0 PSi ACCUMULATOR SrA. ~TROL ~ PLUS ~m~a~ c~o[E ~T~L ~0 aK mC~[O O~ Rm FLOOR. 5. KILL UANIF~D S1Z[- RATING 2"- 5~0 ~ CHOKE ~ANIFO~ SIZE - RATING ADJUSTABLE CHOKE FRON MUD PU,~r RLMOTE PRESSURE GAGE SENSOR DRILLING SPOOL HYDRAULIC CONTROLLED __~__R D~OTE OPERATED REI~OTE PRESSURE . ADJUSTABLE CHOKE ,. GAGE SENSOR CHOKE MANIFOLD __ VARIABLE CHOKE RE]~OTE i CONTROL 1 TO ATMOSPHERIC MUD/GAS SEPARATOR TO SHALE SHAKER CHOKE 8 KILL MANIFOLDS FOR q~/S" & 7" OD CASING BOP STACK BOP ,IANIFOLD LAYOUT - CONOCO, INC. ., i · i CONOCO, INC. MILN£ POINT UNIT DIVERTER STACK FOR 13 318' .CONDUCTOR SELl. NIPPLE · JI, PI EOOO I~l~ &I~NUL~,R PREV[NT£R ,,.,,--,,,,.,,RIJCEIV ED 1. The hydraulic control system will be in a~ordanee with API specifications and AO~ requirements. 2. The HCR valve will open e~hen the preventer closes. A singl~ 10" relief line will run off of the drilling spool HCR valve and will have a targeted do~mstream tee for dowr~ind diversion. Valves on both sides of the te~ will be full opening and linked together to enabla on~ to always be open and the other to be closed. DEC 2 61989 STARTI~O HEAD ?Jl~ 0U & Gas Cons. Cotnmtsslo:. ' Anchorage SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-6 Conoco Inc. 3201C Street, Suite 200 Anchorage, AK 99503 I . Be C. II. A. B. D. III. Casing and Cementing Program The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with +480 sacks Permafrost type "C". The 9-5/8" surface casing will be cemented in 2 stages with the first stage using +770 sacks of Permafrost "E" cement followed by _+293 sacks of Class "G" cement. A DU tool will be placed at +_1860' MD. The second stage will contain +490 sacks of Permafrost "E" cement followed by +73 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will consist of +330 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of +180 sacks of permafrost type "C" cement followed by +60 barrels of Dead Crude pumped down the 7" x 9-5/8" annulus. Drilling Fluid Program 0-500' 9.0 ppg freshwater spud mud. RECE, IVED 500'-6322' 9.0 ppg-9.8 ppg freshwater spud mud. DEC 61 6322'-9600' 9.0 ppg-9.5 ppg dispersed. A~mkaOii&fia$(~onm(~omml~i~ 9600'-TD 10.4 ppg dispersed. Anchorage Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is L-2 with 108' of closure at a depth of 500'. Dead crude will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. Ae Drill a 30" conductor hole to +80' and set 13-3/8" conductor. B, Drill a 12-1/4" surface hole to +4541' TVD (6322' MD) and set 9- 5/8" casing. C. Drill an 8-1/2" production hole to 11,166' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' 0~ Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3617' 4726' "K" Sands 1-1-4 9.2 25 15 65 14 3706' 4855' "M" Sands 1-1-4 9.4 25 15 65 13 3962' 5320' "N" Sands 1-1-4 9.4 25 15 65 12 4134' 5618' "0" Sands 1-1-4 9.4 25 15 65 12 6599' 9877' Surface Casing 6821' 10,260' Kup Top 1-1-6 10.2 8 12 35 5 7045' 10,647' L K (1) 1-1-6 10.2 8 12 35 5 7064' 10,679' L K (2) 1-1-6 10.2 8 12 35 5 7245' 10,682' B L K 1-1-6 10.4 6 12 35 5 7345' 11,166' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. RECEIVED DEC 2 61989 ? taslia 011 & Cons. Cornmissio. Anchorage A. B. C. De E. Ge I . TIME ESTIMATE Rig Up Drill Surface Hole Run Surface Casing and Cement Drill Out and Test Drill Production Hole Log Open Hole Condition, POOH, L.D. Run Production Casing Cement Production Casing Move Rig Hours 10 IlO 36 8 130 36 20 16 10 10 Days 0.42 4.58 1.50 0.33 5.42 1.50 0.83 0.67 0.42 0.42 Cum. Days 0.42 5.00 6.50 6.83 12.25 13.75 14.58 15.25 15.67 16.10 TOTALS 386 16.10 16.10 WP/PERMSUPP RECEIVED DEC26 MILNE POINT INIT WELL -1 -2 -3 -4 -5 -6 -7 -8 -9 10 11 Rate vs. Depth 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 RIG DAYS HORIZONTAL PROJECTION SOALE 1 IN. = 1000 FEET CONOCO. I n,~ · Pad L. Well No, ? Pr'o~o.ed I~11 I ne Po I n~: Un I ~: NoPt SI ope, Al aeka z 5000 . 4000 _ ~000 _ 2000 _ 1000 _ 1000 _ 000 0 1000 2000 I I I S'URFAOE LOCATION ,, 2119' FI,IL. 318' FW'L SEC. 8. T13N. RiOE WEST-EAST 5000 4000 I 5000 I 6000 I 7000 I TD LOCATION, 24~C" FSL. 1291' FWL SEC. 4. T13N. RIOE TARGET LOCATtONt 2210' FSL. 950' FWL SEC. 4. TI3N. RIOE TARGET TV0=7045 TMD=IO~7 DEP=?327 NORTH 4.329 EAST 5912 N 53 DEG 47 HI N E 7327' (TO TARGET) CONOCO, Pad L. Well Not 6 H~lne Porn{ Unl{, Pr Geed Uor~r~ S~ops. Alaska 0 .~ RKB ELEVATION, 28' ri3 1000_ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 8000., KOP $ lO l$ 20 80 35 45 $o EOB TVD=660 THD=660 DEP=O BUILD 2.5 DEe PER 100 FT TVD=2529 THD=2845 DEP=965 9 5/8' CSg PT TVD=4541 THD=6322 DEP=3800 AVERAGE ANGLE 54 DEG ;38 HI N RECEIVED /Jaska Oil & Gas Cons. Commissi Anchorage TARGET / TOP KUP TVD=7045 THD=10647 DEP=7327 TD / 7' LINER TVD=7345 THD:ll166 DEP=T750 I 1000 I 2000 3000 4000 5000 VERTICAL SECTION ! 6000 I 7000 i 8000 100 200 300 400 5~,., 600 700 I I I I I I I 5OO 1600 1700 1800 1' 9 2000 2100 22OO 230O T40'O'" 1"2l~) 66OO 68OO 5200 5600 )0 6200 · ,~ 1400 /'~ 200 1000 ~600 · ,~ 1600 /"~ 800 RECEIVED DEC 2 6 ]989 :~iaska 011 & C',as Cons. Commissio; Anchorage 7000 100 _ 150' I I I _ 170 I I 180 "'20 i _ 190 I I I I I _21C I I _ 22C I I _ 23C _ 160: I I I I I i ' 200 300 400 500 600 700 _ 2OO ... _,:coNoco, ":": ~nTTN: LUCY FELLERS · '~' · t' <='P 0 BOX 441:~ · - HOUETON, TX 77210 -. · ~ :~-LUCY FELLE~ .' ;.; -- _ ..... . ,-- . . :i..'] ~ ~ ~ ~ 4 ,'-~?,.,.', . ,<. ,,. ~..- ':':.':'/' PROC ~RCTZC CLO~ED AND THREAD · .~-~=:' PROTECTORE .. "~... ~ K-D5 COUPLZNG~ ON ENTZRE ORDER INSP ELECT'ROM~QNETIC SPECIRL END ~lOG~ THREAD GAU(;ING . ¢' LORD NO OVERAGE DE$ZRED,.',;HZF' ~UANTZTY ORDERED ONLY. .~E£ SPECIAL ZNSTRUC'TZOH$ · o · o . ~ PREF'A 46376 5'041 - J-I~AT NO. p.4 F_ I I I , CONOCO MPU OPS CTR ~07-65-~-6390 ~ --= - . 9-5/B j.G, O0 - Cus~ome~ order: 907-1£07~9 , mm i_ -'--- -' -- ' ~-- cfa% Orcler; 12-756.-7~1~. Number 33899 33900 47330 Number Number IC Mn F $ Si Cu N1 Cr Me alt ........ ~- ~ l__. ' · ' '-- ~- ' - '0.~4 0.93 .009 .006 .19 .19 .07 0,05 ,013 ,015 ,000,0oO~ ,0~4 .00' 0,23 0.99 .014 .004 .22 .24 ,07 0.09 .012.0L6.000 .0005 ,004 .O0, 0.26 0,97 ,013 .003 ,23 .24 .07 0.08 .011 ,015 ,000 '0,~5 Q.94 .,Oll .004 ,~0 .15 .07 0.08 .010 .0i8 ,000 ,0004 .004 ,00 _ _. . , . .~i~ [$am~ie 0~Iginal -,~ Yiell Ul~!m&~e I Number Dimens ions 1.49~ X .373 1.490 X ss,700 ,4oo z 55.800 Bl.$0O m2 34.0 1.493 X .36§ , 56,000 80.600 '2 38.0 . _ THIS TEST C~RTIFICAT~J OCCURRED IN THE UNITED STAT~$ OF AMERICA. Thi~ ~s to certify tha~ %he material ~ubJec~ tu thi~ ¢~rtifi¢~t= of in$[~ection an~l N.J~ice ~f Limited Warran%y wa~ m.~nufactured in accordance with and conforms to the ~pec~fication~ de~iqna~ed he~on. NO ~RANTY IS ~PRESSED 0R IMPLI~ other than thos~ set forth above. In ~rticular. CF&i Steel Corporation specifically disclaims any implied warranty of meuchantabilit}' o~' fitness_fo~ Inter, de. purpose. . / . I4mN 00? CC,419F~C, AT~ (3/'* II~gP'~k % CF&I STEEL {X)~?0EATiON :.. n CONOCO P 0 ~OX 3t6 PUE~I.i:), COL0. 8t ~2 H TAX EXEMPT T~G FOR:CONOCO %NC. $&T k~HSE-~I..ASK~ . conoco ~T~ NO, oeot 3E~HL~ ~TE~L PIPE 4-7~30 26 JNT '20.7 It 12.~ 40064 4-733, ,2 JNT 2~.7 .. 133~.g 4790, II ~ ~AL, TO ~H%P 23er. TOTAL NET WT, . _ _ I II - i {--. · · ~ .... {.. .~ M~M.~ .... , { ] ___~ ................... i 1 4,.? , ~G FOR:CONOCD INGo CA$IN[ (O.C.T.G ) H & K GRADE J-~ FOR ARCTzu SERV,T. CE R-$ BUTTRI~$$ .T/C HEAT ~TY UOPt THRD LENGTH 4-7]:30 1 ~: JNT 20.T ,..~*"~ " ~ ..._~ "~, .... __ _ ....... ' ..... ~i~, i '~ 12/J0~89 ii i i i ii CONOCO MPU OPS CTl;~--3?-659-~J90 001 Conoco Inc. R~lU~ For Facsimile Trammi~ion L. ocat~on {C;w~ " ' ' '- Fax Keply Number: (907) §59-6390 E~ &81-6390 Please notify (907) 659-63&'0 if complete :rmn~mis~io~ is no= r~ce£ve&. -- C_~NOCO MPU OPS C, ~7-659-~390 DATE; December 29, 1989 PA6~ ! of 1 TO: Dave MountJoy Conoco A1 aska FAX NO; FROM' e07-6~9-6390 J. E. Oton~s~o Manager-Tubul ar Produc%s Please find Oelow the impact values for the five heats conducted on 3/4 ~ndty].~u=l Te~ts (~_t/Lbs) He~t 3-3899 10, lZ, 17 ...... 14, 9 Heat Heat 8-9110 1~, 21, 2~ Minimum ~llow~ble ave~ag~ for 3/4 siz~ specimen - 12 1't/lbs Minimum individual tee% for 3/4 s4ze specimen If ?ou requl~e fur%her inPorm~%ion, don't hmmt%a%e to call, ~4~age~-Tubul a~ ~.oduc%s 3 Test 13.0 14.3 3~;'7 ~3.7 JED/sp cc: j, O, Hotttnqer CONOCO MPU OPS CTR 90?-659-6]90 .. · I, ~.t990 14:4e 002 t:: "~:s'.': '? GF~I EiTEI~L CORPOBATION m~~ Pueblo, Colorado 81003 TEL HO. 800-9M-~g00 DATE: 0anuary ~, 19~)0 PAGE ._t. of J_. TO: Dave NountJoy Conoco A1 aska FAX NO: g0)-05!)-6390 FROM: J. E. Otontsto Hanager-Tubul ar Products Below are listed some impact values for API K-DS product as requested, All were cvnduct.d at room temperature, lmoacl: Value (Ay_o)_ Ft/Lb.~ 3-7337 35,8 4-0607 $1,0 4-0608 35.0 3-7336 34.5 3-7328 35.5 4-0581 30,3 3-7313 ~7,0 3-7314 27.5 4-0580 36.8 'these impacts are above most manufacturers K-SS product as CF&I designs their steel for toughness, As previously stated, the Arctic service d-55 memt API J-55 in every sense but is designed i'or better impact properties at low temperatures, If furthev Information is required, let me know, .,.~,. , . i.'~-',; J. [~, Otonts(o Hanager-Tubul ar Products OEO/sp Anchor,.~,~ CHECK LIST FOR NEW WELL PERMITS Company ~~o~_.~ ~~, (1) Fee .~ ~ /~/~? 1. Is the permit fee attached ......... ----- (J' thru (8) (3) Admin.//~ ~)/Z ?/~ 9. · ('9 t~fhru' ' 10. (10 and 13) 12. 13. (4) Casg '(14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Lease & Well No. ~.~__z~ ~I ...... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available 'in this pool ............ / -- 6. Is well to be deviated and is wellbore plat included ................ 2 ~__ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~.. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... , i Is conductor string provided ........................................ . Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... .~ Will cement tie in surface and intermediate or production strings ..... ,~¢ Will cement cover all known productive horizons ......................... ~z Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. i. ~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~K~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ,'5"'c:P~O psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (6) Add: Geo lo gy: Engine ering: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE