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Home My WebLink About195-161Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-62 (PTD 195-161) COIL FLAG 10/24/2020 Please include current contact information if different from above. PTD: 1951610 E-Set: 34581 Received by the AOGCC 01/19/2021 Abby Bell 01/19/2021 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: 12.0' 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 20" H-40 112' 9-5/8" L-80 4537' 7" L-80 7561' 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 11/4/1995 10/26/1995 ADL 025509 & 355018 94-019 1800' (Approx.) N/AN/A None 11910' / 7587' MWD, LWD, GR, JB Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 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 N/A Water-Bbl: PRODUCTION TEST Not on Injection Date of Test: Flow Tubing 91.1# 40# 112' 6025' 11877' Gas-Oil Ratio:Choke Size: See Attached Per 20 AAC 25.283 (i)(2) attach electronic information 26# 4512' DEPTH SET (MD) 11269' / 7096' PACKER SET (MD/TVD) Surface CASING WT. PER FT.GRADE 540234 540132 TOP SETTING DEPTH MD Surface SETTING DEPTH TVD 6043183 BOTTOM TOP 8-1/2" 6025' Surface 12-1/4" HOLE SIZE AMOUNT PULLED 50-029-22609-00-00 MPU F-62 541935 6035593 4130' FSL, 869' FWL, Sec. 31, T14N, R10E, UM, AK CEMENTING RECORD 6042852 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 11/9/2020 2141' FSL, 2627' FEL, Sec. 06, T13N, R10E, UM, AK 4461' FSL, 769' FWL, Sec. 31, T14N, R10E, UM, AK 195-161 / 320-396 Milne Point Field, Kuparuk Oil Pool 45.75' 5942' / 4484' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 30" Surface 6059' 1160 sx PF 'C', 250 sx 'G', 250 sx PF 'E' 260 sx Arctic Set (Approx.) 351 sx Class 'G' 10775' - 11280'3-1/2" 9.3# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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 Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 2:50 pm, Dec 15, 2020 Abandonment Date 11/9/2020 HEW RBDMS HEW 12/17/2020 xGMGR04FEB2021DLB 12/21/2020 DSR-2/25/21 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 11365' 7167' 11135' 6996' 11365' 7167' 11422' 7210' 11569' 7320' Base Kup 11569' 7320' 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: 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 Kuparuk A Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Base Kuparuk / Miluveach Kuparuk D This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). 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 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. Formation at total depth: Kuparuk C / B Summary of Pre-Rig Work, Drilling Report, Wellbore Schematic Signature w/Date: 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 The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 12.15.2020Digitally 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: 2020.12.15 10:27:48 -09'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 11/30/2020 SCHEMATIC Milne Point Unit Well: MPU F-62 Last Completed: 11/9/2020 PTD: 195-161 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112’ 9-5/8" Surface 40 / L-80 / Btc. 8.835 Surface 6,059’ 7" Intermediate 26 / L-80 / BTC 6.276 6,025’ 11,877’ TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.99 10,775’ 11,280’ JEWELRY DETAIL No Depth Item 1 11,267’ XO 4.5” x 3.5” NSCT 2 11,269’ 7” Baker SAB-3 Packer 3 11,273’ XO 4.5” x 3.5” NSCT 4 11,275’ 3.5” XN Nipple –MIN ID = 2.75” 5 11,278’ WLEG –Bottom @ 11,280’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk B6 11,365’ 11,375’ 7,167’ 7,174’ 10’ 3/3/2020 Squeezed Kuparuk B 11,374’ 11,382’ 7,174’ 7,179’ 8’ 11/8/1995 Squeezed Kuparuk A3 11,430’ 11,450’ 7,215’ 7,230’ 20’ 3/2/2020 Squeezed Kuparuk A 11,434’ 11,444’ 7,218’ 7,226’ 10’ 11/8/1995 Squeezed 11,444’ 11,474’ 7,226’ 7,248’ 30’ 11/8/1995 Squeezed 11,474’ 11,504’ 7,248’ 7,271’ 30’ 11/8/1995 Squeezed 11,504’ 11,535’ 7,271 7,294’ 31’ 11/8/1995 Squeezed Kuparuk A1 11,535’ 11,565’ 7,294’ 7,317’ 30’ 3/1/2020 Squeezed Perforation Summary: Ref Log – SBT/GR/ CCL – 11/7/1995 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0.50” TTP=32.0” @ 135 / 4572 deg. Phasing (Kuparuk B / A) OPEN HOLE / CEMENT DETAIL 30" 260 sx of Arcticset (Approx.) 12-1/4" 1,160 sx PF ‘C’, 250 sx Class ‘G’, 250 sx PF ‘E’ 8-1/2” 361 sx Class ‘G’ WELL INCLINATION DETAIL KOP @ 1,000 Max Hole Angle = 64 to 66 deg. f/ ~4,200’ to ~9,600’ MD Hole Angle through perforations = 42 deg. TREE & WELLHEAD Tree 3-1/8” – 5M Cameron NS Wellhead FMC 11” 5M FMC Gen 5 w/ 11” FMC Tubing Hanger, 3.5” NSCT Lift Threads and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22609-00-00 Drilled, Cased & Completed by Nabors 27E - 12/26/1995 Abandoned: 11/9/2020 TD =11,910’(MD) / TD = 7,587’(TVD) 20” Orig.DF Elev.: 45.75’/ GL Elev.: 12.0’ Nabors 22E 7” 4 5 CIBP set at 5960’ 9-5/8” 1 2 55555555555555555555555 Min ID= 2.75” @ 11,275’ Cut 7” Casing at 6025’ Whipstock set at 5942’ PBTD =5,942’ (MD) / PBTD =4,484’(TVD) 3 Tubing Punch at 11230’ KUP B Sands Cement Retainer at 11242’ Top of Cement at 10801’ KUP A Sands KUP B6 Sands KUP A3 Sands KUP A1 Sands Tubing Cut at 10775’ 4 1 3 WELL NAME: MPU F-62 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 11637' 20 Bbls Class 'G' 11242' Set Cement Retainer 11235' 19 Bbls Class 'G' 11230' - 11235' Tubing Punch 10801' 11.3 Bbls Class 'G' 10775' Cut & Pull Tubing 6025' Cut & Pull 7" Casing 5960' Set CIBP 5942' Set Whipstock Well Name Rig API Number Well Permit Number Start Date End Date MP F-62 Eline / Coil 50-029-22609-00-00 195-161 10/13/2020 10/30/2020 10/19/2020 - Monday No operations to report. 10/20/2020 - Tuesday No operations to report. 10/21/2020 - Wednesday No operations to report. 10/22/2020 - Thursday No operations to report. 10/15/2020 - Thursday No operations to report. CTU #6 1.75" CT .156" wall. M/U and test Northern Solutions MHA/CTC. Pull test and pressure test. M/U and RIH with READ GR/CCL logging bha. Log up from 11,410' to 11,160' and paint flag. Continue logging pass up to 10500' ctmd. POOH. Secure well and R/D logging tools. Confirm good data. Stand back for the night. 10/18/2020 - Sunday MPU Well Support Techs shot TBG FL. TBG FL @ 1,300'. Tbg Inj. Test (Post cement plug) (Pressure test surface lines 250/2,500psi) Pump 35 bbls 60/40 @ 2 bpm caught fluid after 14 bbls away. Tbg Inj rate is 2 bpm at 238 psi 10/23/2020 - Friday CTU #6 1.75" CT .156" wall. Conduct initial BOPE test 300L/ 4,00H. M/U and RIH with 2.80" nozzle for drift run. RIH to 11,306.7' and tag suspected XN nipple. Repeat tag to confirm depth of 11,306.7. POOH. Secure well and stand back for the 10/24/2020 - Saturday Hilcorp Alaska, LLC Weekly Operations Summary 10/16/2020 - Friday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. RAN 2.70" CENT, 5'x2" DRIVE DOWN BAILER W/ BALL BOTTOM & TAGGED CEMENT @ 11,606' SLM (11,637' MD), RECOVERED 4 CUPS OF CONTAMINATED CEMENT. USED +31' KB FOR MD CORRECTION. WELL S/I ON DEPARTURE, DSO NOTIFIED. 10/17/2020 - Saturday No operations to report. Displace cement (Pre Rig Side track) (Pressure test surface lines 250/2500psi) Pump 1 bbl 60/40 down Tbg to check if Tbg was clear. T/I/O= 1,801/1,389/124 Halliburton cementers pumped 20 bbls of source water down TBG to establish injection rate. Pumped 20 bbls of 15.8 ppg cement followed by 73 bbls of source water. LRS pumped 25 bbls of diesel for freeze protect. Total of 98 bbls of fluid for displacement. 10/13/2020 - Tuesday 10/14/2020 - Wednesday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-62 Eline / Coil 50-029-22609-00-00 195-161 10/13/2020 10/30/2020 Hilcorp Alaska, LLC Weekly Operations Summary 10/27/2020 - Tuesday CTU #6 1.75" CT .156" wall. Crews arrive on location and check all equipment and engine oils. MU 2.0" BDJSN. MU injector and coil to well. PT to 250/4,000psi. RIH to tag Retainer. Tag at 11,257, PU to up WT and correct depth -22' and we are on depth with the retainer. Pump 15.3 bbls of CMT as per plan. Pump 11.3 bbls into IA and 4.0 bbls in TBG and POOH. FP coil and 1000' of TBG. OOH LD BHA, stack down, install night cap and PT to 250 low and 3,500 high. Job completed. Suspend OPS and RDMO tomorrow morning. 10/28/2020 - Wednesday 10/25/2020 - Sunday CTU #6 1.75" CT .156" wall. RIH and set 3.5" Alpha one trip cement retainer @ 11,242' corrected depth. Set 6k down and confirm retainer set. Rig up and P/T Hal cement pump. Fluid pack lines and pt to 5k. Batch up and pump 19 bbls 15.8 ppg class G cement. Unsting with 0.5 bbls left in coil and leave on top of retainer. Displace coil with Powervis and POH pumping at 70%. Freeze protect coil with diesel. Freeze protect well with 5bbls of diesel. Secure well and recover 0.5" setting ball. Stand back for the night. 10/26/2020 - Monday CTU #6 1.75" CT .156" wall. MU and RIH with SLB 1.56" 4 spf 1606M Puncher. Total length between shots = 5'. Tag cement top at 11,263' ctmd. POH and repeat tag. Drop 1/2" aluminum ball for firing head. Punch appeared to fire at 35 bbls away. Simultaneous drop in pressure noted on IA. Pump diesel down coiled tubing to begin AOGCC witnessed CMIT. Test passed with initial and final pressures of: IAP = 1,758/1,702 and T = 2,204/2,128. POH. T/I/O= 443/0/0. LRS unit 72 AOGCC MIT-T to 1,750 psi *PASSED* at 1,932 psi (2,000 max applied pressure). TBG lost 45 psi during the 1st 15 minutes and 18 psi during the 2nd 15 minutes. Pumped 0.6 bbls to achieve test pressure. Bled back 0.6 bbls to T/I/O= 416/0/0. MIT-IA to 1,750 psi *PASSED* at 1,937 psi (2,000 psi max applied pressure). IA lost 44 psi during the 1st 15 minutes and 16 psi during the 2nd 15 minutes. Pumped 3.4 bbls of diesel to achieve test pressure. Bled back 3.0 bbls to Final T/I/O= 416/4/0. Circulate 75 bbls of diesel into the TBG with IA returns to a tank. CMIT-TxIA Inconclusive. Test lost to much pressure in the 2nd 15 minutes on 2 attempts. Final T/I/O= 504/425/0. 10/29/2020 - Thursday WELL S/I ON ARRIVAL, PT PCE 250L/3000H. DRIFT WITH 2.67"" CENT. & 5' x 2.25"" DRIVE DOWN BAILER (mule shoe ball btm). TAG TOC @ 10,801' SLM (recovered good cement sample, state witness satisfied). LRS MIT-T AND MIT-IA (pass, see LRS log). CHANGE OUT TO ALLISON & CREW. LOG TBG WITH HES MEMORY CCL-PRESSURE-TEMP TOOL FROM 10802' SLM TO 10600' SLM (good data). CUT TBG AT 10775' SLM WITH HES MEMORY JET CUTTER. LRS PUMP 75bbls DIESEL DOWN TBG AND TAKING RETURNS OUT IA TO OPEN TOP TANK (LRS U-tube freeze protect). 10/30/2020 - Friday (Pressure test surface lines 250/2500psi) (RWO) CMIT-TxIA Passed at Passed. Pressured up T/IA to test pressure with 2.25 bbls dsl. 15 min T/IA lost 34/36 psi. 2nd 15 min T/IA lost 12/13 psi for a total loss of 46/49 psi in 30 min. Bled T/IA to 400/275 psi and recovered ~ 2.2 bbls. Final Whp's=400/275/0 Activity Date Ops Summary 11/4/2020 On MPU L-21A, please see M-21A report for details. 15:27 Nov 4 - Provided 24 hour BOP test notification to the AOGCC. 18:48 Nov 4 - AOGCC inspector Adam Earl waived the right to witness BOP testing;Install rear booster tires. Install front booster tire frame and tires. Prepare for rig move to F-pad. Notified pad operator and security of rig move.;Move rig from L-pad to F-pad.;Remove front and rear booster tires.;Move rig around the pad, pull onto F-62A. Spot and level the rig. 11/5/2020 Skid rig floor into drilling position and slide conveyor into normal position. Spot service buildings and trailers.;The electrician powered up the top drive. M/U 3 joints of 5" drill pipe, hang stand to verify plumb over the rotary table - good.;Rig up. Weld ladder in mud pit #1. Load 290 bbls of 9.5 ppg brine into the pits. Pull BPV, top of cement is 10,801'. Tubing & IA were pressure tested to 2500 PSI pre-rig. Secure well. Spot and R/U rockwasher. Spot 500 bbl flow back tank. Completed rig acceptance checklist - rig accepted at 15:00.;Remove check valve on tubing wing. Rig up lines to circulate well to flow back tank. Load 290 bbls of 9.5 ppg brine into the upright tanks. Clear rig floor of 4" handling equipment and remove XT-39 saver sub. PJSM for displacement. *** Rig on high line power at 16:20 ***;Pressure test lines to flow back tank to 300 PSI low / 1000 PSI high. Circulate through 3.5" tubing cut at 10,775'. Pump 290 bbls of heated seawater with Deep Clean detergent, 4.5 BPM, 1690 PSI. Pump 30 bbl high vis spacer followed by 473.9 bbls of 9.5 ppg brine, 4.5 BPM, 1770 PSI. Flow check-static;Install BPV. Pressure test hanger void to 5000 PSI – good. N/D tree as per Hilcorp wellhead rep. Install test dart in BPV. Verify lifting threads in hanger are good - 3-1/2" NSCT XO made up 7.5 turns.;N/U BOP stack and install kill line.;Remove upper 2-3/8" solid rams from upper rams. Remove 2-7/8"x5" VBR rams from lower rams and install in upper rams. Install 4-1/2" x 7" VBR rams in lower rams. Sim-ops: welder had to shorten trip nipple 1' due to well elevation;Install trip nipple. Install 5" donut test joint and R/U BOP test equipment. Fill stack with water and purge lines. 11/6/2020 R/U BOP test equipment. Flood and purge lines. Shell test 13-5/8" 5M BOP's and choke. Leak on OTECO flange on choke line. Replace and retest (good).;Test BOP equipment as per PTD and Hilcorp requirements. AOGCC inspector Adam Earl waived witness at 18:48 on 4 Nov 2020. Test against test dart installed BPV in 7" hanger. All tests performed with fresh water. Test held for 5 min each and charted. Annular tested to 250 PSI low / 2500 PSI high.;All other tests performed to 250 PSI low / 4500 PSI high. 1) Upper 2-7/8" x 5" VBR on 5" test joint, choke valves 1, 12, 13, 14, kill Demco, 5" dart & upper IBOP. 2) Choke valves 9, 11, kill HCR, 5" FOSV #1 & lower IBOP. 3) Choke valves 5, 8, 10, kill manual, 3.5" dart;4) Choke valves 4, 6, 7 & 3.5" FOSV. 5) Choke valve 2. 6) Choke HCR. 7) Upper 2-7/8" x 5" VBR on 3.5" test joint & choke manual. 8) Annular on 3.5" test joint. 9) Blind rams & choke valve 3. 10) Super choke A. 11) Manual choke B. 12) Lower 4.5" x 7" VBR on 4.5" test jt. 13) Lower 4.5" x 7" VBR on 7" test jt;Accumulator: 3025 PSI system pressure, 1625 PSI after closure, 200 PSI recovery = 38 sec, full recovery = 191 sec. Six nitrogen bottle average 2041 PSI. BOP functioned from both primary & remote controls. No failures.;R/D test equipment and blow down top drive, choke and kill lines.;Pull test dart & BPV. Install 3.5" NSCT landing joint. Check IA for pressure (static). BOLDS, unseat hanger 97k clean and pull hanger to the rig floor. L/D landing joint & hanger. M/U XO to FOSV, change elevators & R/U casing equipment while monitoring well (static).;POOH laying down 3.5# 9.3# L-80 EUE tubing f/ 10775'. Laid down 341 full joints (10,562.42'), cut joint (12.89'), hanger & pups (4.56') + Doyon 14 RKB (30.85') = 10610.72' tubing cut measurement vs. 10,775 slickline measurement. 20:00 - 15 PSI on OA, bleed to 0. 03:00 - 0 PSI on OA.;L/D 3.5" casing equipment. Mobilize 7" casing equipment to the rig floor.;PJSM. Spot Alaska E-line truck. R/U sheave & wireline hanging on elevators. R/U 5" donut test joint, FOSV, XO and pump in sub. 11/7/2020 Clean and clear rig floor. R/D and L/D 3.5" handling equipment. Stg 7" handling equipment on floor.;P./U 5" donut test joint and feed rope socket thru w/ psi control equipment on top. Ak E-line dress tool w/ 5.75" jet cutter, GR, CCL w/ (2) ea. bow spring roller centralizers. Set 5" and close upper pipe rams. flood stack and lubricator. P/T to 500 (c/o plug vavle then tested good).;RIH with Jet cutter on E-line to 6246' ELM. Logged up locating collars and identifying 9-5/8 shoe presumably w/ significant Gamma shift. Correlate and adjust ELM for tally. Put cutter on depth @ 6025' ELM. Call clear and fire same. Good indication of fire on rig floor. 7" on vac, OA 400 psi.;Pump down kill line taking returns out OA back to flowback tank. Establish circ @ 1.5 bpm, 40 psi. Pump 230 bbls heated seawater w/ deep clean. Shut down monitor well - 200 psi on 7", 0 psi on annulus. Cont pumping a total of 290 seawater, 30 bbls hi vis spacer then disp entire well 9.5 ppg brine.;Pull 5" riser, FOSV, XO, pump in sub & grease head. Hoist e-line to the rig floor - weight was lower than expected. E-line CCL, gamma ray, XO, centralizer, bottom sub, firing head & jet cutter were missing (8.95'). Threaded section backed off or parted. R/D e-line.;Drain stack, blow down choke and kill lines. Monitor OA - static.;M/U pack-off running tool on 5" drill pipe & pup joint. Engage pack-off and BOLDS. Pull pack-off with 12K initial then 2K seal drag. L/D pack-off (in good condition). L/D running tool, 5" drill pipe & pup joint.;C/O elevators to 7". P/U 7" landing joint and M/U to hanger ACME thread with 5-3/4 LH turns. P/U to 175K (calculated PU), then pull 225K (1.5' stretch), 250K (2'), 275K (2.5') & 300K (3') working each 3 times with no success. M/U top drive to landing joint. Pull 325K (4' stretch) 3 times.;Casing pulled free at 340K (180K overpull). Verify free with 160K PU / 130K SO. Hoist hanger to the rig floor. L/D hanger & landing joint. Perform derrick inspection after pulling on casing.;L/D 7" 26# L-80 BTC casing f/ 5982'. Laid down 148 full joints (5962.49') + cut joint (19.91') + RKB, pack-off, hanger, pup (39.95') = 6022.35' casing cut depth vs. 6025' ELM. 7/8" of the circumference was not cut w/ the Jet Cutter. 180K overpull parted it.;R/D & L/D casing equipment, hanger, pack-off. Install 9-1/16" I.D. long wear bushing in tubing spool.;Mobilize Yellow Jacket BHA components to the rig floor for both the casing scraper and CIBP runs. PJSM. P/U 5" drill pipe (drift w/ 3.15), M/U 7"x8-5/16" starter mill, double pin XO, 9-5/8" casing scraper, bit sub & 8-5/16" string mill to 14.96'.;Daily losses = 0 bbls, Cumulative losses = 0 bbls Total. H20 from 6-Mile: 0 bbls Daily / 560 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 300 bbls Daily / 525 bbls Total. Cuttings/mud/cement to MPU G&I: 575 bbls Daily / 1,265 bbls Total. 50-029-22609-01-00API #: Well Name: Field: County/State: MP F-62A Milne Point Hilcorp Energy Company Composite Report , Alaska 11/8/2020 RIH w/ 9-5/8" scraper / cleanout assy (14.96' total length) to 6021' picking up 190 jts of 5" DP. Drift 3.15". Hole took proper displacement. Tag TOF @ 6021' 2x w/ 5k dn (6025' ELM). 150k up, 115k dn.;L/D single. CBU @ 6011' MD. Pump @ 10 bpm, 470 psi, 21% flow out. Saw trace of crude and fine sand @ btms up. Gas climbed to ~300u then dropped off and shakers cleaned up. Circulated a total of 460 bbls.;Flood Beyond MPD lines. Pressure test MPD lines and choke 250 / 1500 psi w/ 5 min hold on each (test good).;PJSM, Cut and slip 73' drilling line. Svc and inspect line wt sensor, saver sub, brakes and traveling equipment. Monitor well via trip tank (static).;POOH F/ 6011' - T/ 14' racking back 5" dp in derrick. L/D 9-5/8" casing scraper assembly. Note: 10 missing cuttings and 5 chipped on gauge of starter mill. Will pick-up back up starter mill on whipstock run.;M/U 9-5/8" CIBP, running tool & XO to 6.07'. RIH with CIBP on 5" drill pipe f/ 6' t/ 5960', 148K PU / 120K SO.;Pump fluid through mud pump pop-off lines. #1 good but #2 didn't release until 2000 PSI & held 1800 PSI while pumping 3 SPM indicating restriction. Isolate #2 pump to troubleshoot. Pressure test mud lines to 4000 PSI - good test. *** Remove & inspect pop-off. Found rubber in pop-off. Replaced ***;Drop 1-1/4" phenolic ball and allow to free fall for 20 min. Pump 2.2 BPM, 70 PSI. Ball on seat at 469 strokes. Pressure up to 2120 PSI and observe slips set as pressure dropped to 1820 PSI. Bleed off pressure. P/U to 200K (50K over) w/ 2.4' of travel. Hold for 5 min to set element. S/O to 149K.;Turn string 11 turns to the right to release. P/U with 147K, verified release. Rack back stand to 5907'. Blow down top drive. Top of bridge plug at 5960'.;Rig up to test casing. Pump down drill pipe and kill line against closed upper 2-7/8" x 5" VBR on 5" drill pipe. Hold 2900 PSI for 30 minutes on chart - good test. R/D test equipment and blow down lines.;PJSM w/ Doyon, M-I & DSM. Pumped 25 bbl high vis spacer and displace wellbore with 422 bbls of 9.5 ppg LSND mud, 8 BPM, 260 PSI. Dumped 8.5 bbls interface before returning back to the pits. Flow check - static. Blow down top drive.;POOH f/ 5907' t/ 2384'. Pipe was pulling wet, pumped dry job at 5022' and blew down top drive.;Daily losses = 0 bbls, Cumulative losses = 0 bbls Total. H20 from 6-Mile: 100 bbls Daily / 660 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 525 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 1,265 bbls Total. 11/9/2020 POOH w/ CIBP running tool f/ 2384' t/ 3' and laydown the running tool.;Mobilize BHA components to the rig floor. M/U starter mill (7" x 8-5/8" O.D.), watermelon mill (8-5/8" O.D.), 31.75' 5" drill pipe joint, MWD DM & TM collars and float sub to 59.23'. Shallow pulse test MWD at 425 GPM, 700 PSI - good test. Blow down top drive.;P/U Yellow Jacket 9-5/8" whipstock slide w/ bottom trip anchor (3° slide - 12' length). M/U to mills with 35K shear bolt. Perform MWD offset - 338/476*360=255.63°. RIH w/ whipstock assembly to 77.74'.;Single in the hole w/ 17 joints of 5" HWDP f/ 77' t/ 604'. TIH out of the derrick w/ 5" drill pipe f/ 604' t/5917'. Fill pipe every 2000', 75'min running speed. 150K PU / 115K SO.;Orient whipstock 42°R with 460 GPM, 960 PSI. Slack off from 5917' and tag CIBP on depth at 5960' with 10K to set anchor. Continue to slack off, 35K shear bolt released at 38K.;Mill window in 9-5/8" casing from 5942' to 5960' as per Yellow Jacket, 505 GPM, 1125 PSI, 90-130 RPM, 6-9K TQ, 5-20K WOB. Place full gauge watermelon mill just off whipstock slide. TOW at 5942' MD / 4485' TVD and BOW at 5954' MD / 4490' TVD.;Pumped high vis sweeps at 5949' and 5960' - no increase of cuttings observed. 70# of metal recovered.;Dress window from 5960' to 5940' three times w/ no torque or drag observed. Slack off with no rotation from 5940' to 5960' - no drag observed. 450 GPM, 1000 PSI, 110 RPM, 6K TQ.;Drill 8-1/2" hole f/ 5960' t/ 5982' (22' drilled, 5.5'/hr AROP), 450 GPM, 940 PSI, 120 RPM, 8K TQ, 25K WOB w/ mills. 28' drilled f/the bottom of the window, 23' of gauge hole. ROP slowed to 3 FPH, changed parameters from 450-550 GPM, 940-1300 PSI, 95-125 RPM, 6-8K TQ & 10-35K WOB w/ no improvement;Pump 15 bbls high vis sweep - no increase observed. Dress window with watermelon mill f/ 5960' t/ 5940', 480 GPM, 1100 PSI, 120 RPM, 6K TQ - to drag or torque observed. Work through with no pumps or rotation - no drag observed. 148K PU / 130K SO. Rack back stand to 5917'. 89# total metal recovered.;Blow down top drive & R/U to test. Attempt FIT to 13.0 ppg. Close upper pipe rams on 5" drill pipe then pump down drill pipe and kill line. 9-5/8" shoe at 5954' MD / 4490' TVD. 9.6 ppg MW in/out. Leaked off at 687 PSI for 12.5 ppg EMW. Repeat test with same results.;POOH from 5917' to 5430' with good displacement. Pump dry job and blow down the top drive. .;Daily losses = 0 bbls, Cumulative losses = 0 bbls Total. H20 from 6-Mile: 0 bbls Daily / 660 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 525 bbls Total. Cuttings/mud/cement to MPU G&I: 632 bbls Daily / 1,897 bbls Total. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '2e P.I. Supervisor r/ ,I 10CZtn�o FROM: Austin McLeod Petroleum Inspector DATE: October 29, 2020 SUBJECT: Plug Verification Milne Point Unit F-62 - Hilcorp Alaska North Slope LLC PTD 1951610; Sundry 320-396 ' Section: 6 Township: 13N Range: 10E Drilling Rig: NA Rig Elevation: NA Total Depth: 11,910 ft MD Operator Rep: Josh McNeal Suspend: X Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ 112 Feet Surface: 9-5/8" - 0. D. Shoe@ 6059 Feet Intermediate: NA 0. D. Shoe@ NA Feet Production: 7" - 0. D. Shoe@ 11,877 Feet Liner: NA 0. D. Shoe@ NA Feet Tubing: 3-1/2" O.D. Tail@ 11,280 - Feet Plugging Data: Test Data: Remarks: Meridian: Umiat Lease No.: ADL 025509 P&A: T pe Pluq Casing Removal: Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Tbg Cut@ NA Feet T pe Pluq Founded on Depth Btm Depth To MW Above veritiea Fullbore Retainer - 11,257 ft MD 10,801 ft MD 8.3/6.9 ppg- Wireline tag 0 0 Ini+iol 1F min in min 45 min Result Tubing 1995 1950 1932 - IA 0 0 0 P OA 0 0 0 I 4:_1 I G _;n '20 min dpi min RACIIlt Tubing 650 651 649 IA 1997 1953 - 1937 P OA 6 4 6 I traveled to location to witness the tag and pressure test of a cement plug that was laid in via coil tubing on 10/27/20. This was to continue to prep the well for a redrill. Using a 225 pound, 2.25 -inch slickline string, we tagged the top of the plug at 10,801 ft WLM (inclination -44 degrees) with multiple set downs/licks. With a proposed balanced height of 428 -feet this put the tag 0.25 barrels or 28 -feet higher than anticipated. Once out of the hole they broke down the bailer and we observed cement in it. A passing pressure test of the tubing and inner annulus was then done with barrel counts in and out appropiate for both. This was two separate pressure tests due to the tubing punches being covered in cement (11,250-11,255 ft MD) The bottom depth of this plug was also the previous tag depth of the plug below this one which was founded on the retainer (11,264 ft MD). Type of plug referred to as fullbore due to balanced plug not being an option in drop down. Top perforation depth -11,365 ft MD. Attachments: none rev. 11-28-18 • 2020-1029_Plug_Verification_MPU_F-62_am MEMORANDUM _ TO: Jim Regg 2 /e�. i I � i0� P.I. Supervisor l FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 26, 2020 SUBJECT: Plug Verification MILNE PT Unit F-62 Hilcorp Alaska LLC PTD 1951610; Sundry 320-396 " Section: 6 Township: 13N Range: 10E Meridian: Umiat 11264 ft MD Drilling Rig: NA Rig Elevation: NA Total Depth: 11910 ft MD Lease No.: ADL025509 Operator Rep: Rich Burnett Suspend: P&A: X Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 20" O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 6059 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 11877 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 11280 Feet Tbg Cut@ Feet Plugging Data: Test Data Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Retainer 11264 ft MD I 11257 ft MD" C.T. Tag- OA 89 82 76 InitinI 1.ri min 30 min 45 min Result Tubing 2204 2161 2128 - IA 1758 1723 - 1702. P OA 89 82 76 Initial 15 min 30 min 45 min Result Remarks: Pluigback for redrill. I witnessed a coil tubing tag of a cement retainer that was used to pump 20.3 bbls of cement to isolate the production zone. The tag was shown to have the top of cement @ 11257 ft MD, then the coil was pulled up -hole 1 ft and a tubing punch was fired. After comunication was established between the tubing and IA, a Combination MIT TxIA was performed. The test passed only losing 46 psi total during the 30 minute test. Attachments: none rev. 11-28-18 2020-1026_Plug_Verification_MPU_F-62_11 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/29/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-62 (195-161) PERFORATING RECORD 03/03/2020 Please include current contact information if different from above. Received by the AOGCC 09/29/2020 PTD: 1951610 E-Set: 34010 Abby Bell 09/29/2020 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: ___________________ 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): 11,910'None Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8434 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 Tubing MD (ft): COMMISSION USE ONLY Authorized Name: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025509 & ADL0355018 195-161 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 Milne Point Field, Kuparuk Oil Pool 50-029-22609-00-00 Hilcorp Alaska LLC Length Size 7,587' 11,765' 7,472' 1,999 None MPU F-62 112' 112' L-80 TVD Burst 11,280 MD N/A Tubing Size:Tubing Grade: 5,750psi 7,240psi 4,511' 7,561' 6,059' 11,877' See Schematic See Schematic 112'20" 9-5/8" 7" 6,059' 11,877' Perforation Depth TVD (ft): C.O. 432D Baker SAB-3 Packer and N/A 11,269 / 7,096 and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 10/10/2020 3-1/2" 9.3# Perforation Depth MD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.25 11:57:18 -05'00' By Samantha Carlisle at 9:21 am, Sep 25, 2020 320-396 X DLB 09/25/2020MGR29SEP20 10-407 Per 20 AAC 25.112 Well Plugging Requirements (g) (2) Pressure test to .25 psi/ft multiplied by TVD ~1750 psi minimum DSR-9/29/2020Comm. 9/30/2020 dtws 9/29/2020 JLC 9/29/2020 RBDMS HEW 11/2/2020 Plug for RD Well: MPU F-62 Date: 09-22-20 Well Name:MPU F-62 API Number:50-029-22609-00 Current Status:Shut-in injector Pad:F-Pad Estimated Start Date:October 10 th, 2020 Rig:Non Rig Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:195-161 First Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:Plug for RD Current Bottom Hole Pressure:2,699 psi @ 7,000’ TVD SBHP survey on 3/24/19 | 7.41 ppg Maximum Expected BHP:2,699 psi @ 7,000’ TVD SBHP survey on 3/24/19 | 7.41 ppg MPSP:1,999 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 66° at 7,802’ MD Max Dogleg:4°/100ft at 4,088’ MD BPV Profile:3” CIW Type H Minimum ID:2.75” at 11,275’ MD Last Tag:11,740’ MD on 1/13/2020 Brief Well Summary: MPU F-62 was drilled and completed in November 1995 as a Kuparuk A and B sand injector. It has been determined that this well is not an effective injector. The plan is to re-drill the production interval to a new bottom hole location and make it a Kuparuk producer. Notes Regarding Wellbore Condition x The 7” production casing passed an MIT to 1,500 psi on 5/27/2020. Objective: x Plug the Kuparuk sands with cement. x Punch holes above the packer. x Pump balanced cement plug. Tag TOC, PT the cement plug and PT the 7” casing to 1,500 psi. x Jet cut the tubing above TOC to prep the well for the drilling rig. Cementing: 1. MIRU cementing unit and spot support equipment. 2. Line up to bullhead down the tubing. PT lines to 2,500 psi. 3. Establish injection rates and pressure by pumping up to 20 bbls of source water into the formation. 4. Mix and pump 20 bbls of 15.8 ppg Class G cement down the 3-1/2” tubing. Use freshwater spacers as needed around the cement. a. 7” cement volume: last tag depth to bottom of WLEG = 17.6 bbls b. Tubing volumes: bottom of WLEG to top of packer = 0.1 bbls 5. Displace the cement with 98 bbls of source water, squeezing away 2.3 bbls and leaving the estimated TOC at 11,269’ (top of the packer). 6. Flush all surface line with fresh water to tanks. 7. RDMO cementing unit. 1750 psi minimum. Plug for RD Well: MPU F-62 Date: 09-22-20 Slickline: 8.Notify the AOGCC 24 hours in advance for tag of TOC and PT. 9. MIRU the slickline unit and support equipment. 10. RIH with drive down bailer, tag TOC (note tag depth on report) and POOH. 11. PT the tubing and cement plug to 1,500 psi for 30 minutes (charted). 12. PU, MU and RIH with tubing punch to just above the TOC. 13. PU to 11,242’ (middle of first full joint above the packer), punch the tubing and POOH. 14. CMIT – TxIA to 1,500 psi for 30 minutes (charted) to confirm the integrity of the 7” casing after the tubing punch. 15. RDMO the slickline unit. Cementing: 16. MIRU cementing unit and support equipment. 17. Line up to circulate down the tubing taking return up the IA to tanks. PT lines to 2,500 psi. 18. Establish circulation and pump 55 bbls of fresh water to recover the diesel on the IA. 19. Mix and pump 15 bbls of 15.8 ppg Class G cement balanced plug down the 3-1/2” tubing taking returns up the IA to tanks. Use freshwater spacers as needed around the cement. a. Balanced plug height = 428’ 20. Flush all surface lines with fresh water to tanks. 21. RDMO the cementing unit. Slickline: 22.Notify the AOGCC 24 hours in advance for tag and PT. 23. MIRU the slickline unit and support equipment. 24. RIH with drive down bailer, tag TOC (note tag depth on report) and POOH. 25. PT the tubing to 1,500 psi for 30 minutes (charted) and PT the IA to 1,500 psi for 30 minutes (charted). 26. RDMO the slickline unit. E-line: 27. MIRU the E-line unit and LRS. 28. PU, MU and RIH with a jet cutter. Cut the 3-1/2” tubing in the middle of the first full joint above the TOC. POOH. 29. With LRS establish circulation down the tubing up the IA to confirm the tubing is cut. 30. Freeze protect the well by pumping ~75 bbls of diesel down the tubing taking returns out the IA. Place the tubing and IA in communication allowing time for the diesel to u-tube and equalize. 31. RDMO E-line unit and LRS. 32. Set 3” HP BPV. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Blank MOC Form 1750 psi minimum ~11,269' MD. 1750 psi 1750 psi minimum BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϰͬϭͬϮϬϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&ͲϲϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϭͬϭϵϵϱ Wd͗ϭϵϱͲϭϲϭ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬEdϴϬ>,ͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕Ϭϱϵ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬd ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϴϳϳ͛ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵ ^ƵƌĨĂĐĞ ϭϭ͕ϮϴϬ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭ ϭϭ͕Ϯϲϳ͛ yKϰ͘ϱ͟ǆϯ͘ϱ͟E^d Ϯ ϭϭ͕Ϯϲϵ͛ ϳ͟ĂŬĞƌ^ͲϯWĂĐŬĞƌ ϯ ϭϭ͕Ϯϳϯ͛ yKϰ͘ϱ͟ǆϯ͘ϱ͟E^d ϰ ϭϭ͕Ϯϳϱ͛ ϯ͘ϱ͟yEEŝƉƉůĞʹD/E/сϮ͘ϳϱ͟ ϱ ϭϭ͕Ϯϳϴ͛ t>'ʹŽƚƚŽŵΛϭϭ͕ϮϴϬ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉĂƌƵŬϲ ϭϭ͕ϯϲϱ͛ ϭϭ͕ϯϳϱ͛ ϳ͕ϭϲϳ͛ ϳ͕ϭϳϰ͛ ϭϬ͛ ϯͬϯͬϮϬϮϬ KƉĞŶ <ƵƉĂƌƵŬ ϭϭ͕ϯϳϰ͛ ϭϭ͕ϯϴϮ͛ ϳ͕ϭϳϰ͛ ϳ͕ϭϳϵ͛ ϴ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ <ƵƉĂƌƵŬϯ ϭϭ͕ϰϯϬ͛ ϭϭ͕ϰϱϬ͛ ϳ͕Ϯϭϱ͛ ϳ͕ϮϯϬ͛ ϮϬ͛ ϯͬϮͬϮϬϮϬ KƉĞŶ <ƵƉĂƌƵŬ ϭϭ͕ϰϯϰ͛ ϭϭ͕ϰϰϰ͛ ϳ͕Ϯϭϴ͛ ϳ͕ϮϮϲ͛ ϭϬ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ ϭϭ͕ϰϰϰ͛ ϭϭ͕ϰϳϰ͛ ϳ͕ϮϮϲ͛ ϳ͕Ϯϰϴ͛ ϯϬ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ ϭϭ͕ϰϳϰ͛ ϭϭ͕ϱϬϰ͛ ϳ͕Ϯϰϴ͛ ϳ͕Ϯϳϭ͛ ϯϬ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ ϭϭ͕ϱϬϰ͛ ϭϭ͕ϱϯϱ͛ ϳϮϳϭ ϳ͕Ϯϵϰ͛ ϯϭ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ <ƵƉĂƌƵŬϭ ϭϭ͕ϱϯϱ͛ ϭϭ͕ϱϲϱ͛ ϳ͕Ϯϵϰ͛ ϳ͕ϯϭϳ͛ ϯϬ͛ ϯͬϭͬϮϬϮϬ KƉĞŶ WĞƌĨŽƌĂƚŝŽŶ^ƵŵŵĂƌǇ͗ZĞĨ>ŽŐʹ^dͬ'Zͬ>ʹϭϭͬϳͬϭϵϵϱ ϰ͘ϱ^W&ϯϮŐŵ͕ůƉŚĂ:ĞƚŚĂƌŐĞƐ;,сϬ͘ϱϬ͟ddWсϯϮ͘Ϭ͟ΛϭϯϱͬϰϱϳϮĚĞŐ͘WŚĂƐŝŶŐ;<ƵƉĂƌƵŬͬͿ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ;ƉƉƌŽǆ͘ͿŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ϭ͕ϭϲϬƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͕͟ϮϱϬƐǆW&͚ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϯϲϭƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϭ͕ϬϬϬ DĂǆ,ŽůĞŶŐůĞсϲϰƚŽϲϲĚĞŐ͘ĨͬΕϰ͕ϮϬϬ͛ƚŽΕϵ͕ϲϬϬ͛D ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϰϮĚĞŐ͘ dZΘt>>, dƌĞĞ ϯͲϭͬϴ͟ʹϱDĂŵĞƌŽŶE^ tĞůůŚĞĂĚ&Dϭϭ͟ϱD&D'ĞŶϱǁͬϭϭ͟&DdƵďŝŶŐ,ĂŶŐĞƌ͕ ϯ͘ϱ͟E^d>ŝĨƚdŚƌĞĂĚƐĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϬϵͲϬϬͲϬϬ ƌŝůůĞĚ͕ĂƐĞĚΘŽŵƉůĞƚĞĚďǇEĂďŽƌƐϮϳͲϭϮͬϮϲͬϭϵϵϱ dс ϭϭ͕ϵϭϬ͛ ;DͿͬdсϳ͕ϱϴϳ͛;dsͿ KƌŝŐ͘&ůĞǀ͗͘ϰϱ͘ϳϱ͛ͬ'>ůĞǀ͗͘ϭϰ͘ϵ͛EĂďŽƌƐϮϮ Wdс ϭϭ ͕ϳϲϱ͛;DͿͬWdсϳ͕ϰϳϮ͛;dsͿ _____________________________________________________________________________________ Revised By: IAT 9/22/2020 PROPOSED Milne Point Unit Well: MPU F-62 Last Completed: 11/11/1995 PTD: 195-161 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 112’ 9-5/8" Surface 40 / L-80 / Btc. 8.835 Surface 6,059’ 7" Intermediate 26 / L-80 / BTC 6.276 Surface 11,877’ TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.99 Surface 11,280’ JEWELRY DETAIL No Depth Item 1 11,267’ XO 4.5” x 3.5” NSCT 2 11,269’ 7” Baker SAB-3 Packer 3 11,273’ XO 4.5” x 3.5” NSCT 4 11,275’ 3.5” XN Nipple –MIN ID = 2.75” 5 11,278’ WLEG –Bottom @ 11,280’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk B6 11,365’ 11,375’ 7,167’ 7,174’ 10’ 3/3/2020 Open Kuparuk B 11,374’ 11,382’ 7,174’ 7,179’ 8’ 11/8/1995 Open Kuparuk A3 11,430’ 11,450’ 7,215’ 7,230’ 20’ 3/2/2020 Open Kuparuk A 11,434’ 11,444’ 7,218’ 7,226’ 10’ 11/8/1995 Open 11,444’ 11,474’ 7,226’ 7,248’ 30’ 11/8/1995 Open 11,474’ 11,504’ 7,248’ 7,271’ 30’ 11/8/1995 Open 11,504’ 11,535’ 7,271 7,294’ 31’ 11/8/1995 Open Kuparuk A1 11,535’ 11,565’ 7,294’ 7,317’ 30’ 3/1/2020 Open Perforation Summary: Ref Log – SBT/GR/ CCL – 11/7/1995 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0.50” TTP=32.0” @ 135 / 4572 deg. Phasing (Kuparuk B / A) OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset (Approx.) in 24” Hole 9-5/8" 1,160 sx PF “C”, 250 sx Class “G”, 250 sx PF ‘E in 12-1/4” Hole 7” 361 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 1,000 Max Hole Angle = 64 to 66 deg. f/ ~4,200’ to ~9,600’ MD Hole Angle through perforations = 42 deg. TREE & WELLHEAD Tree 3-1/8” – 5M Cameron NS Wellhead FMC 11” 5M FMC Gen 5 w/ 11” FMC Tubing Hanger, 3.5” NSCT Lift Threads and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22609-00-00 Drilled, Cased & Completed by Nabors 27E - 12/26/1995 TD =11,910’(MD) / TD = 7,587’(TVD) 20” Orig.DF Elev.: 45.75’/ GL Elev.: 14.9’ Nabors 22E 7” 4 5 9-5/8” 1 2 55555555555555555555555555 Min ID= 2.75” @ 11,275’ PBTD =11,765’ (MD) / PBTD = 7,472’(TVD) 3 KUP B Sands KUP A Sands KUP B6 Sands KUP A3 Sands KUP A1 Sands Jet cut tubing Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: September 22nd, 2020Subject: Changes to Approved Sundry Procedure for Well MP F-62Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 )RUP5HYLVHG6XEPLW:LWKLQGD\VRI2SHUDWLRQV Digitally signed by Chad Helgeson DN: cn=Chad Helgeson, ou=Users Date: 2020.04.02 15:47:33 -05'00' Chad Helgeson By Samantha Carlisle at 2:35 pm, Apr 02, 2020 RBDMS HEW 4/6/2020 gls 4/2/20 DSR-4/2/2020 SFD 4/2/2020 BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϰͬϭͬϮϬϮϬ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWh&ͲϲϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϭͬϭϭͬϭϵϵϱ Wd͗ϭϵϱͲϭϲϭ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬEdϴϬ>,ͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚĐ͘ ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϲ͕Ϭϱϵ͛ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬd ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϭϭ͕ϴϳϳ͛ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵ ^ƵƌĨĂĐĞ ϭϭ͕ϮϴϬ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭ ϭϭ͕Ϯϲϳ͛ yKϰ͘ϱ͟ǆϯ͘ϱ͟E^d Ϯ ϭϭ͕Ϯϲϵ͛ ϳ͟ĂŬĞƌ^ͲϯWĂĐŬĞƌ ϯ ϭϭ͕Ϯϳϯ͛ yKϰ͘ϱ͟ǆϯ͘ϱ͟E^d ϰ ϭϭ͕Ϯϳϱ͛ ϯ͘ϱ͟yEEŝƉƉůĞʹD/E/сϮ͘ϳϱ͟ ϱ ϭϭ͕Ϯϳϴ͛ t>'ʹŽƚƚŽŵΛϭϭ͕ϮϴϬ͛ WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ <ƵƉĂƌƵŬϲ ϭϭ͕ϯϲϱ͛ ϭϭ͕ϯϳϱ͛ ϳ͕ϭϲϳ͛ ϳ͕ϭϳϰ͛ ϭϬ͛ ϯͬϯͬϮϬϮϬ KƉĞŶ <ƵƉĂƌƵŬ ϭϭ͕ϯϳϰ͛ ϭϭ͕ϯϴϮ͛ ϳ͕ϭϳϰ͛ ϳ͕ϭϳϵ͛ ϴ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ <ƵƉĂƌƵŬϯ ϭϭ͕ϰϯϬ͛ ϭϭ͕ϰϱϬ͛ ϳ͕Ϯϭϱ͛ ϳ͕ϮϯϬ͛ ϮϬ͛ ϯͬϮͬϮϬϮϬ KƉĞŶ <ƵƉĂƌƵŬ ϭϭ͕ϰϯϰ͛ ϭϭ͕ϰϰϰ͛ ϳ͕Ϯϭϴ͛ ϳ͕ϮϮϲ͛ ϭϬ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ ϭϭ͕ϰϰϰ͛ ϭϭ͕ϰϳϰ͛ ϳ͕ϮϮϲ͛ ϳ͕Ϯϰϴ͛ ϯϬ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ ϭϭ͕ϰϳϰ͛ ϭϭ͕ϱϬϰ͛ ϳ͕Ϯϰϴ͛ ϳ͕Ϯϳϭ͛ ϯϬ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ ϭϭ͕ϱϬϰ͛ ϭϭ͕ϱϯϱ͛ ϳϮϳϭ ϳ͕Ϯϵϰ͛ ϯϭ͛ ϭϭͬϴͬϭϵϵϱ KƉĞŶ <ƵƉĂƌƵŬϭ ϭϭ͕ϱϯϱ͛ ϭϭ͕ϱϲϱ͛ ϳ͕Ϯϵϰ͛ ϳ͕ϯϭϳ͛ ϯϬ͛ ϯͬϭͬϮϬϮϬ KƉĞŶ WĞƌĨŽƌĂƚŝŽŶ^ƵŵŵĂƌǇ͗ZĞĨ>ŽŐʹ^dͬ'Zͬ>ʹϭϭͬϳͬϭϵϵϱ ϰ͘ϱ^W&ϯϮŐŵ͕ůƉŚĂ:ĞƚŚĂƌŐĞƐ;,сϬ͘ϱϬ͟ddWсϯϮ͘Ϭ͟ΛϭϯϱͬϰϱϳϮĚĞŐ͘WŚĂƐŝŶŐ;<ƵƉĂƌƵŬͬͿ KWE,K>ͬDEdd/> ϮϬΗ ϮϲϬƐǆŽĨƌĐƚŝĐƐĞƚ;ƉƉƌŽǆ͘ͿŝŶϮϰ͟,ŽůĞ ϵͲϱͬϴΗ ϭ͕ϭϲϬƐǆW&͕͟͞ϮϱϬƐǆůĂƐƐ͞'͕͟ϮϱϬƐǆW&͚ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϳ͟ ϯϲϭƐǆůĂƐƐ͞'͟ŝŶϴͲϭͬϮ͟,ŽůĞ t>>/E>/Ed/KE d/> <KWΛϭ͕ϬϬϬ DĂǆ,ŽůĞŶŐůĞсϲϰƚŽϲϲĚĞŐ͘ĨͬΕϰ͕ϮϬϬ͛ƚŽΕϵ͕ϲϬϬ͛D ,ŽůĞŶŐůĞƚŚƌŽƵŐŚƉĞƌĨŽƌĂƚŝŽŶƐсϰϮĚĞŐ͘ dZΘt>>, dƌĞĞ ϯͲϭͬϴ͟ʹϱDĂŵĞƌŽŶE^ tĞůůŚĞĂĚ&Dϭϭ͟ϱD&D'ĞŶϱǁͬϭϭ͟&DdƵďŝŶŐ,ĂŶŐĞƌ͕ ϯ͘ϱ͟E^d>ŝĨƚdŚƌĞĂĚƐĂŶĚϯ͟/t,WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϲϬϵͲϬϬͲϬϬ ƌŝůůĞĚ͕ĂƐĞĚΘŽŵƉůĞƚĞĚďǇEĂďŽƌƐϮϳͲϭϮͬϮϲͬϭϵϵϱ dс ϭϭ͕ϵϭϬ͛ ;DͿͬdсϳ͕ϱϴϳ͛;dsͿ KƌŝŐ͘&ůĞǀ͗͘ϰϱ͘ϳϱ͛ͬ'>ůĞǀ͗͘ϭϰ͘ϵ͛EĂďŽƌƐϮϮ Wdс ϭϭ ͕ϳϲϱ͛;DͿͬWdсϳ͕ϰϳϮ͛;dsͿ <ƵƉĂƌƵŬϯ ϭϭ͕ϰϯϬ͛ ϭϭ͕ϰϱϬ͛ ϳ͕Ϯϭϱ͛ ϳ͕ϮϯϬ͛ ϮϬ͛ ϯͬϮͬϮϬϮϬ KƉĞŶ <ƵƉĂƌƵŬϭ ϭϭ͕ϱϯϱ͛ ϭϭ͕ϱϲϱ͛ ϳ͕Ϯϵϰ͛ ϳ͕ϯϭϳ͛ ϯϬ͛ ϯͬϭͬϮϬϮϬ KƉĞŶ ------------ <ƵƉĂƌƵŬϲ ϭϭ͕ϯϲϱ͛ ϭϭ͕ϯϳϱ͛ ϳ͕ϭϲϳ͛ ϳ͕ϭϳϰ͛ ϭϬ͛ ϯͬϯͬϮϬϮϬ KƉĞŶ Well Name Rig API Number Well Permit Number Start Date End Date MP F-62 Eline 50-029-22609-00-00 195-161 3/1/2020 3/3/2020 2/28/2020 - Friday No operations to report. 2/26/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/27/2020 - Thursday No operations to report. ARRIVE TO LOCATION. CHECK IN W/WSL, OPEN PERMIT W/PAD-OP. STACK PCE ON THE WELL WITH TOOL STRING ,CH/GPST/20' 2.5'' GUN , PT PCE 250L/2,500H. RIH W/ CH/GPST/20' 2.5'' GUN 60DEG PHASE MILENIUM CHARGES. TARGET DEPTH 11,680' CORELATED TO BAKER ATLAS LOD DATED 7-NOV-1995 GAMMA RAY AND CCL FROM 11,680' TO 11,200' AND SEND LOG TO THE OFFICE. SHOOT THE GUN FOUR ON INTERVAL 11,365' TO 11,375', CCL OFFSET TO TOP SHOOT 7.8' CCL STOP @ 11,357.2'. ON SURFACE SHUT IN SWABS & SSV BLEED OFF PRESSURE PULL THE GUN FROM THE LUBRICATOR AND CONFIRM THE GUNS FIRED. COMPLETE THE THIRD INTERVAL AND RIG DOWN. No operations to report. 2/29/2020 - Saturday ARRIVE TO LOCATION. CHECK IN W/WSL, OPEN PERMIT W/PAD-OP. STACK PCE ON THE WELL WITH TOOL STRING ,CH/GPST/20' 2.5'' GUN , PT PCE 250L/2,500H. RIH W/ CH/GPST/20' 2.5'' GUN 60DEG PHASE MILENIUM CHARGES. TARGET DEPTH 11,680' CORELATED TO BAKER ATLAS LOD DATED 7-NOV-1995 GAMMA RAY AND CCL FROM 11,680' TO 11,200' AND SEND LOG TO THE OFFICE. SHOOT THE FIRST GUN ON INTERVAL 11,430' TO 11,450' ,CCL OFFSET TO TOP SHOOT 7.8' CCL STOP @ 11,422.2'. ON SURFACE SHUT IN SWABS & SSV BLEED OFF PRESSURE PULL THE GUN FROM THE LUBRICATOR AND CONFIRM THE GUNS FIRED. COMPLETE THE SECOND INTERVAL AND LAY DOWN LUBRICATOR PER WEATHER (-42 F) AND SECURE THE WELL. 3/3/2020 - Tuesday 3/1/2020 - Sunday WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. TARGET DEPTH 11680' CORELATED TO BAKER ATLAS LOD DATED 7-NOV-1995 GAMMA RAY AND CCL FROM 11680' TO 11200' AND SEND TEH LOG TO OFFICE. SHOOT THE FIRST GUN ON INTERVAL 11,545' TO 11,565' ,CCL OFFSET TO TOP SHOOT 7.8' CCL STOP @ 11,537.2. ON SURFACE SHUT IN SWABS & SSV BLEED OFF PRESSURE PULL THE GUN FROM THE LUBRICATO AND CONFIRM THE GUN FIRE 100%. RIH W/ CH/GPST/10' 2.5'' GUN @ 11,680' TO DO A CORRELATION PASS. TARGET DEPTH 11,680' CORELATED TO BAKER ATLAS LOD DATED 7-NOV-1995 GAMMA RAY AND CCL FROM 11,680' TO 11,200' AND SEND TEH LOG TO OFFICE. SHOOT THE SECOND GUN ON INTERVAL 11,535' TO 11,545' ,CCL OFFSET TO TOP SHOOT 7.8' CCL STOP @ 11,527.2'. ON SURFACE SHUT IN SWABS & SSV BLEED OFF PRESSURE PULL THE GUN FROM THE LUBRICATO AND CONFIRM THE GUN FIRE 100%. COMPLETE THE FIRST INTERVAL AND LAY DOWN LUBRICATOR AND SECURE THE WELL TO CONTINUED OPERATION ON NEXT DAY. 3/2/2020 - Monday THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU F-62 Permit to Drill Number: 195-161 Sundry Number: 3 20-03 5 Dear Mr. Helgeson: Alaska Oil and (Bas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276,7542 www. a o gc c.al aska.g ov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, VyPrice DATED thisS3day of January, 2020. RBDMS±* SAN 2 7 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 DDC 95 Min .JAN 2 1 2020 irs /fzn'lz6 A0 CC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑Z Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redhill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q . 195-161 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22609-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT F-62 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLI355018 MILNE POINT / KUPARUK RIVER OIL 11. •/fie L2,Zo PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,910' 7,587' 11,765' 7,472' 1,999 N/A N/A Casing Length Size MD TVD Burst Collapse Coductor 142' 30"' 142' 142' N/A N/A Surface 6,023' 9-5/8" 6,059' 4,511' Production 11,846' 7" 11,877' 7,561' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (it): See Schematic See Schematic 3-1/2" 9.3#/ L-80 / EUE 8rd 11,280' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker S-3 and N/A 11,269 MD 17,096 TVD and N/A 12. Attachments: Proposal Summary 21 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/6/2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAGIN ❑� GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ' ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson � Authorized Title: Operations Manager Contact Email: dhaaklnsoR(WhilCof .Com r Contact Phone: 777-8343 Authorized Signature: Date: 1/20/2020 dr COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:Z ) /WC 1 QLJAJ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS SFE JIAN 2 7 2010 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Ex\pti Required? Yes No Subsequent Form Required: o — 1 () 1 APPROVED BY ^Approvetl b ' COMMISSIONER THE /e COMMISSION Date: '�3 ORIGINAL Submit Form and Form 10-403 evised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate K }Iilwrp Alaska. LU E -line Perforations Well: MPU F-62 Date:01/20/2020 Well Name: MPU F-62 API Number: 50-029-22609-00 Current Status: Injector [Shut lnj Pad: F -Pad Estimated Start Date: February 6th, 2020 Service Unit: E -line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: A3 (Reperf) Regulatory Contact: Tom Fouts Permit to Drill Number: 195-161 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 903-3987 (M) AFE Number: Job Type: Perforating Current Bottom Hole Pressure: Maximum Expected BHP: MPSP: MIN ID: Max Inclination Max Dogleg: BPV Profile: 2,699 psi @ 7,000' TVD 2,699 psi @ 7,000' TVD 1,999 psi 2.75" @ 11,275' MD 66- @ 7,915' MD V/100ft @ 4,115 MD 3" CIW Type H SBHP Survey 03/24/19 17.41 PPG Gas Column Gradient (0.1 psi/ft) Brief Well Summary: MPU injector F-62 was drilled and completed in November 1995 and perforated in the Kuparuk A and C -sands as an injector. Following the drilling of offset producer F-116, additional perforations are needed to support the producer in the Kuparuk C1, and lower Al sands Notes Regarding Wellbore Condition • The 7" production casing passed an MIT -IA to 1,950 prig on 09/04/16 • The well has no known well integrity problems. • A 20'x2.70" dummy gun drift and tag was completed prior to rigging up E -line. Objective: • Perforate Kuparuk A1/136 Sands. • Re -perforate Kuparuk A3 Sands (9 shots mis-fired in 1995 completion) Brief Procedure I. RU E -line. PT PCE to 250 psig Low/ 2,500 psig High. 2. Obtain GR/CCL/CBL log dated 11-07-1995 for tie-in log. 3. RIH with GR and CCL and pert guns i. Perforating guns are 2-1/2" OD, 6 SPF, 60° phase Halliburton Millennium Charges 1. Max Swell: 2.676" 2. Use Max 20' Gun ii. RIH to 11,600' MD iii. Pull up -hole to 11,200' MD for correlation run and tie into GR/CCL log dated 11-07-1995. iv. Short Joint (20.29') Located @ ±11,223' 4. Perforate intervals as followed: Zone Sand Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Length Kuparuk Al ±11,535' ±11,565' 7,294' 7,317' ±30' Kuparuk A3 (Reperf) ±11,430' ±11,450' 7,215' 7,230' +20' Kuparuk 66 ±11,365' ±11,375' 7,167' 7,174' ±10' PAV H I1&.c n :Uasku, LL, E -line Perforations Well: MPU F-62 Date:01/20/2020 a. POOH and LD perforating guns. i. Document condition of fired guns including any damage or un -fired charges 5. RDMO Nine 1. As -Built Schematic 2. Proposed Schematic K llik.o ,, Alaska, ILC Orig.DF Bev.: 45.75'/ GL Bev.:14.9' Nabors 22E To= 11,914 (MD) / TD=7,587'(TVD) PBTD =11,765' (M)) / PBTD= 7,477(TVD) SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU F-62 Last Completed: 11/11/1995 PTD: 195-161 Tree 3-1/8"-5M Cameron NS Wellhead FMC 11"5M FMC Gen 5 w/11" FMC Tubi ng Hanger, 3.5" NSCT Lift Threads and 3" CIW H BPV Profile OPEN HOLE/ CEMENT DETAIL 20" 260sxof Arcticset(Approx.) in 24" Hole 9-5/8" 1,160 sx PF "C", 250 sx Class "G", 250 sX PF 'E in 12-1/4" Hole 7" 361 sx Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/NT80LHE/N/A 1 / NT8i0 N/A Surface 112' 9-5/8" Surface / Btc. 8.835 Surface 6,059' 7" Intermediate 26 / L-80 / BTC 6.276 Surface 11,877' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.99 Surface 11,280' WELL INCLINATION DETAIL KOP @ 1,000 Max Hole Angle=64 to 66 deg. f/ -4,200' to -9,600' MID Hole Angle through perforations =42 deg. JEWELRY DETAIL No Depth Item 1 11,267' XO 4.5" x 3.5" NSCT 2 11,269' 7" Baker SAB -3 Packer 3 11,273' M045-X3.5-NSCT 4 11,275' 3.5"XN Nipple w/RHC Plug -MIN ID= 2.635' 5 11,278' WLEG- Bottom @11,280' PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk B 11,374' 11,382' 7,174' 7,179' 8' 11/8/1995 Open 11,434' 11,444' 7,218' 7,226' 30' 11/8/1995 Open KuparukA 11,444' 11,474' 7,226' 7,248' 30' 11/8/1995 Open 11,474' 11,504' 7,248' 7,271' 30' 11/8/1995 Open 11,504' 11,535' 7271 7,294' 31' 11/8/1995 Open Perforation Summary: Ref Log - SBT/GR/ CCL -11/7/1995 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0.50" TTP=32.0" @ 135 / 4572 deg. Phasing (Kuparuk B / A) GENERAL WELL INFO API: 50-029-22609-00-00 Drilled, Cased & Completed by Nabors 27E - 12/26/1995 Revised By: TDF 1/17/2020 K cora Alaska. LLC. Odg.DF Bev.: 45.75/ GL Elev.:14.9' Nabors 22E TD=11,910' (MD)/TO=7,587'(TVD) PBTD=11,765 (MD) / PBiD= 7,472 -(TVD) PROPOSED TREE & WELLHEAD Milne Point Unit Well: MPU F-62 Last Completed: 11/11/1995 PTD: 195-161 Tree 3-1/8"-5M Ca meron NS Wellhead FMC 11"5M FMC Gen 5w/31" FMC Tubing Hanger, 3.5" NSCT Lift Threads and 3" CIW H BPV Profile OPEN HOLE/ CEMENT DETAIL 20" 260 sx of Arcticset (Approx.) in 24" Hole 9-5/8" 1,160 sx PF "C", 250 sx Class "G", 250 sx PF 'E in 12-1/4" Hole li 7" 361 sx Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1 / NT80LHE / N/A N/A Surface 112' 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 6,059' 7" Intermediate 26/L-80/BTC 6.276 Surface 11,877' TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8rd 2.99 Surface 11,280' WELL INCLINATION DETAIL KOP @ 1,000 Max Hale Angle = 64 to 66 deg. f/ 4,200'to 9,600' MD Hole Angle through perforations =42 deg. JEWELRY DETAIL No Depth Item 1 11,267' X04.5" x 3.5" NSCT 2 11,269' 7" Baker SAB -3 Packer 3 11,273' XO 4.5" x 3.5" NSCT 4 11,275' 3.5"XN Nipple w/ RHC Plug - MIN ID=2.635" 5 11,278' WLEG - Bottom @ 11,280' PERFORATION DETAIL Sands Top (MD) BIM (MD)E7,226' Btm (TVD) FT Date Status Kuparuk B6 ±11,365' ±11,375' ±7,174' ±10' Future Future Kuparuk8 11,374' 11,382' 7,179' 8' 11/8/1995 Open Kuparuk A3 11,430' ±11,450' ±7,230' ±20 Future Future 11,434' 11,444' 7,226' 30' 11/8/1995 Open KuparukA 11,444' 11,474' 7,248' 30' 11/8/1995 Open 11,474' 11,504' 7,271' 11,504' 11,535'7,294' 31' 11/8/1995 Open Kuparuk Al ±11,535' ±11,565' ±7,294' ±7,317 1 ±30 Future Future Perforation Summary: Ref Log - SBT/GR/ CCL -11/7/1995 4.5 SPF 32 gm, Alpha Jet Charges (EHD=0,50"TTP=32,0"@135/ 4572 deg. Phasing (Kuparuk B/A) GENERAL WELL INFO API: 50-029-22609-00-00 Drilled, Cased & Completed by Nabors 27E - 12/26/1995 Revised By: TDF 1/20/2020 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,September 07,2016 P.I.Supervisor het T (ll w(l C� SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC F-62 FROM: Chuck Scheve MILNE PT UNIT KR F-62 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry \' NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR F-62 API Well Number 50-029-22609-00-00 Inspector Name: Chuck Scheve Permit Number: 195-161-0 Inspection Date: 9/4/2016 Insp Num: mitCS160906105721 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min F-62 - Type Inj w'ITVD 7096 - Tubing 2482 - 2492 ' 2483 - 2485 1951610 Type Test lilTest psi 1774 - IA 108 1952 - 1893 - 1881 - nterval 4YRTST PAF P " OA 137 390 - 380 - 376 - Notes: SCANNED JUN 2 0 2017, Wednesday,September 07,2016 Page 1 of 1 .. =.f.aauewaixemumn*'x p.mnraV'fl .ash: V ' ..nave '/ " ., w!°^np. -: •fr, +. .vwm<3 ",,.^ N . .'q'..: ,.t^. ..;. asr .:n w. • I bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 , Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder I f. I Alaska Oil and Gas Conservation Commission (� 1 (� 333 West 7 Avenue `` �I Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 822011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/12011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF -49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/112011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF -61 1951170 50029225820000 62 Need top job .-- -)1 2 b MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/312011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/312011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF -80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -848 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/122011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF-88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/112011 MEM®RANDUM To: Jim Regg ~ ` i V~ ~ ~ ~~~~ P.I. Supervisor ~`~'~l FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 1 ~, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-62 MILNE PT (JNIT KR F-62 Src: Inspector NnN_("nNFiT)F.NTT AT. Reviewed By: P.I. SuprvJ~~~~""- Comm Well Name: MILNE PT UNIT KR F-62 mitCS081010070053 Insp Num: Rel Insp Num: API Well Number; 50-029-22609-00-00 Permit Number: t95-161-0 Inspector Name: Chuck Scheve Inspection Date: toi9i2ooa Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i F-6z Type Inj. W ~ TVD 7096 ~ IA ~ 450 2150 2110 ! 2110 P T 1951610 TypeTest ~ SPT TCSt pSl 1774 ~ Q d), 100 340 340 340 ~ Interval 4YRTST P~F P ~ TUhing ~ 1450 1450 1 1450 ~ 1450 ~ ~ Notes' Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. Wednesday, October 15, 2008 Page 1 of 1 A "L... \..J L-I V L.. U . STATE OF ALASKA SFP. ALA Oil AND GAS CONSERVATION CONf1'V1 r-J007 REPORT OF SUNDRY WELÆaQREIIArLQ~~míssion ~ '....?lð~? 1. Operations Abandon 0 Repair Well D Plug Perforations 0 StimulAlfJfliliraps Other 0 Brightwater treatment .~ Performed: Alter Casing 0 Pull TubingD Perforate New Pool 0 WaiverD Time Extension 0 Enhanced oil recovery Change Approved Program 0 Opera!. Shutdown D Perforate 0 Re-enter Suspended Well D ..st¡~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 195-1610 ..- 3. Address: P.O. Box 196612 Stratigraphic Service P' 6. API Number: Anchorage, AK 99519-6612 50-029-22609-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: MPF-62 - 45 KB 8. Property Designation: 10. Field/Pool(s): - ADLO-355018· Kuparuk River Sands Field/ Milne Point Pool 11. Present Well Condition Summary: Total Depth measured 11910 ;- feet Plugs (measured) None true vertical 7587.3 - feet Junk (measured) None Effective Depth measured 11765 feet true vertical 7470 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 32' - 110' 32' - 110' Surface 6059' 9-5/8" 40# L-80 36' - 6059' 36' - 4527' 5750 3090 Production 11877' 7" 26# L-BO 31' - 11877' 31' -7561' 7240 5410 Perforation depth: Measured depth: 11374 - 11382 11434 -11535 - - True Vertical depth: 7173.51 - 7179.44 7218.05 - 7293.9 - - Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 Surface - 11279' Packers and SSSV (type and measured depth) 7" BAKER S-3 11269' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: 2 3 2007 Intervals treated (measured): 5CJ1NNED S E P 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: 0 0 2997 0 895 Subsequent to operation: 0 0 2485 40 994 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory Development Service P' Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas r WAG GINJ WINJ W 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 Jennifer McLeod Printed Name Jennifer McLeod Title Petroleum Engineer Signature VA " I 1. VV\-Y" NJ Phone 564-5764 Date 9/13/2007 v V HMI 1IUI'Io:: 6Ft SEP 24 2DD7 fr,1 ~ . . - Form 10 404 Revised 04/2006 ORIGINAL 1.1y \ SUbml~l¡6..? . . F-62i BriQht Water Treatment Summary A Bright Water Treatment was pumped at well F-62i with the objective of improving the waterflood sweep in the upper reservoir. EC9378 Bright Water chemical and EC9360 surfactant were chosen for the treatment. Prior to treatment modeling of the formation was performed to determine thief zones and quantity of the Bright Water treatment to be injected downhole. This was the first Bright Water treatment for this well. Two 400 bbl tanks were staged at F-62, one for each chemical. IMO's used transfer pumps to pump chemical into 400 bbl tanks. The chemical was in turn pumped from the tanks downhole. The treatment began on 7-30-07 and was pumped until 8-16-07. Total Bright Water (EC9378) pumped was 15,925 USG. Total Surfactant (EC9360) pumped was 8523 USG. The surfactant continued to be pumped one hour after Bright Water chemical as called for in the procedure. 9378 lines were flushed with diesel and 9360 lines flushed with 50/50 methanol-water. The entire Bright Water set up was the rigged down in preparation for the next job at E- Pad. . MPF-62 WORK SUMMARY . Delivered as Delivered as measured by measured by Water Pressure EC9378 EC9378 tank strap EC9360 EC9360 lank strap Date Time bwpd) [(psi) inches) (gal) (gal) Inches) (gal) (gal) COMMENTS 7/29/200 14:25 2607 89 65 455C 73 5110 Usinç¡ bottom of Ihe tank as a reference 7/30/2007 13:25 2609 917 53 840 65.5 525 Usinç¡ bottom of the tank as a reference 7/31/2007 7:35 2609 924 44.5 595 59.75 402.5 Usina bottom of the tank as a reference Switched to top 01 tank as a reference for more consistent measurement. This was a 4" difference for EC9378 and a 5" 7/31/2007 7:35 2609 924 40.625 54.75 difference for EC9360. 7/31/2007 9:15 2607 925 40.375 17.5 54.25 35 7/31/2007 11:45 2606 925 107.875 4725 N/A Reli11 both lanks. EC9360 unreadable due to bubbles. 7/31/2007 16:20 2606 925 105 201.25 122.5 4777.5 First EC9360 readino after fillina 8/1/2007 8:10 2602 935 96.25 612.5 117.5 350 8/2/2007 8:10 2525 935 83.375 901.25 110.75 472.5 8/3/2007 10:15 2522 939 70.75 883.75 102.375 586.25 8/4/2007 8:10 2516 944 59.5 787.5 95.625 472.5 8/5/2007 8:10 2510 946 48 805 88.625 490 8/6/2007 6:10 2510 949 37 770 81.75 481.25 Refill EC9378 tank 8/6/2007 8:40 2510 949 113.625 5363.75 81.5 17.5 First strap after EC9378 refill 8/712007 8:05 2511 961 100.375 927.5 74 525 8/8/2007 7:05 2494 966 87.375 910 66.375 533.75 8/9/2007 8:10 2499 972 75.25 848.75 58.625 542.5 8/10/2007 8:20 2496 977 63.25 840 51.25 516.25 8/11/2007 8:10 2498 984 50.125 918.75 43.375 551.25 8/12/2007 8:05 2493 987 37.25 901.25 36.25 498.75 8/13/2007 8:00 2490 992 24.875 866.25 30.5 402.5 8/13/2007 22:10 2490 992 16.5 586.25 25.875 323.75 Refill EC9378 8/14/2007 0:00 2495 998 89.875 5136.25 25.5 26.25 First strap after EC9378 refill 8/1512007 0:10 2495 998 76.375 945 20.625 341.25 Refill EC9360 8/15/2007 20:10 2495 998 65.875 735 88.125 4383.75 First strap after EC9360 refill 8/18/2007 8:05 2486 1005 60.375 385 85 218.75 8/16/2007 16:00 2485 1008 55 376.25 82.125 201.25 End treatment Total Delivered 19775 14271.25 Remainder 3850 5748.75 Delivered, Remainder Pumped 15925 8522,5 MPF-62 Well head repair work Subject: MPF-62 Well head repair work From: "MPU, Wells Ops Coord2" <MPUWellsOpsCoord2@BP.com> Date: Thu, 04 Nov 2004 09:23:30 -0900 To: "Tom. Maunder (E-mail)..<tom_maunder@admin.state.ak.us>...Sauve.MarkA..<mark.sauve@BP.com> CC: aogcc -prudhoe - bay@admin.state.ak.us tSS""-\Co \ FYI: h b . d d t t d t 5000 Psi." The upper seal leak that was found on the seal sleeve under the adapter as een repa1re an es e 0 The well is slated to be put back on injection after slickline gets the plug pulled this morning. Lee Hulme MPU Well OPS Coord II 907-670-3293 .~ Failed Pack off test on F-62 Subject: Failed Pack off test on F-62 From: "MPU, Well Operations Supervisor" <welloperationssupervisor@BP.com> Date: Sun, 31 Oct 2004 12:45:17 -0900 To: "Sauve, Mark A" <mark.sauve@BP.com> CC: "AOGCC- Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> Mark, Yesterday the F-pad operator noticed a small leak on the test cap to the tubing hanger void on the tree of F-62. The well was recently converted to gas and the WHP was 3800 psi. FMC was notified and tested the packoff later that morning. The test failed (ie upper seals have failed) and the void had 3800 psi. We currently are not communicating to the IA which is 1000 psi. The well was shut in yesterday and 300 bbl of water wI F/P pump today. Slickline is currently setting a TIP and a BPV will be installed once slickline is finished. We will try to redress the seals tomorrow if possible, if we can't get a successful pack off test will need to add .this well to the 4ES schedule. ~' Thanks Clint Spence \.. SCANNED NOV 0 52004 1 of 1 11/5/2004 9:23 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~~ S~:~isor X~~ I DJ It (C4- DATE: Monday, October 11,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-62 MILNE PT UNIT KR F-62 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~IÒ) u/D4- Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR F-62 API Well Number: 50-029-22609-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLGO41008035216 Permit Number: 195-161-0 Inspection Date: 10/7/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-62 Type Inj. N TVD 7100 IA 200 1920 1860 1860 960 960 P.T. 1951610 TypeTest SPT Test psi 1775 OA 100 340 310 310 180 170 Interval 4YRTST P/F P Tubing 2000 2000 2000 2000 2000 2000 Notes: After 30 minutes bled annulus down to 960 psi to test WTubing integrity. Monday, October 11,2004 Page I of! ( (' 195-1U\ WELL LOG TRANSMITTAL ProActive Diagnostic SelVices, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration(Alaska),lnc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LR2-1 P. o. Box 1369 900 East Benson Blvd. Stafford, TX 77497 Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 Res. Eva!. CH 1 1 1 F..62i 1-13..04 Mech.CHL~¡~~C~ - Caliper Survey Signed: ~\ \J.. ~~, Ci D.. ~('. J'Y'. Date: n~f"CI\ll:n " ~ Print Name: J¡~~t;l 2 9 2004 A1ækaOil & Gas Cons.Comm_n Anmorage PRoAcTivE DiAGNOSTic SEI{viCES, INC., PO Box 1 }69 STAFFoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com R~~('\'\~ fþ~Ák'!k'!EIC ffB 022004 ( (\<15-1u\ WELL LOG TRANSMITTAL ProActive Diagnostic SelVices, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration(Alaska), Inc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LR2-1 P. O. Box 1369 900 East Benson Blvd. Stafford, TX 77497 Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BlUELINE Open Hole 1 1 1 F-62i 1-13-04 Res. Eva I. CH ~..~ 1 1 ¡~/ J~1 - Mech. CH 1 I " , Caliper Survey Signed: ~D ~ ~ ,Q..JI:J b <":::-~ Date: RE6EtVE9 Print Name: f1Q04 J/\N 2 9 L ¡Aiaskaa" Gas Cons.Commisian Anøage PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 }69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memQrylog.com Wét)'§ite: www.memoryt~i.bbm ~ \~'\n '''\',' ~'ì î ,~~' I;~ ',' ~~~\'\\~ ,<1\, Alas h¢sred e ices TO- Blair Wondzell FROM' Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily susPend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose Setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8, x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call. me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ANNULAR INJECTION DATA ENTRY SCREEN Asset MilD.e. ........................................ ~¢ANNEiC) NOV 1 2 2D02 Legal Desc 2.1..4.1.'.bI~.I,,..$~.6.${Z'.~F,I,,..{~.~..§,.T..1.:~o..EI.1.QF, ..................... ............... Research Rig Name ~l.~,b.Qm.i~.7.F, ............................. Inj Well Name M..P..E:.~i?,...: ......... ........................ Permit Start ....... .1..Q:.1.:~:.~.,5. ...... Permit End .......~1.;~/.:~.1/.~.,5. ....... Sur Csg DeP §.0.[~.~. ................ Cumulative Data Rig, ComPletion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ........... ;~.8.~ ...................... .3.1.6 ................. ............................................................................................................................. 7.Q. ........... /,};'~,~? r~l A Gas COtds. r:Oi~}mi8 .... ~ Daily 'Data ~ Dal~ of ~nated ] Rig Wash ~ Fcxmali°n iFree-'ze Freeze, Daiy Anrulus Well tried~ Dflg Mud { Fluicts Fluids Fluids F'poteclion Protedion ' Total Rate Pressure Stalus rfii~f:~ ....................... ]~ iTO'g?~g .................. ~':J'~ ' ................ ~'i"~' Oi~'$h ................ 'i'§'§'~;" ?'~i:" ~ i;i~'"~'i3 ~'~.'i:~; MPF-62 r 1.__./01/95 '~ 70 171 _ -- -- .............................................................................................................................................. ....................................................................................................................................................................................................... ~ ........................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................ : .... . ................. .................... .:' ...... : ,...:...,.. .......... '""-'Zi'2~.12.'111'LI-'.,Z Z'Z' ~'ZS'.L't' ................................................................ 7.11.7".ZZ~ ................................................. 7-Z-'~"-_'Z.'i.._ ' .......................................................................................................................... I I .............................................................. .............. ~ ........................................................... -~ .................. ................................................................ . .............................................................................. ..................................... i 1 ..................................... ~ ................................................................................................................................................................................................... ...................................... ................. I ........................................................................................................................................................ ..................................... ......................... , ................ ...................................................... re.d rvlces rilling 900 East Benson Boulevard, MB 8-1 - Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 14.1.998 Naska 0il & Gas Cons, Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the ssD database which coincide With the approved wells on your attached AOGCC Annular Log. The SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated fr°m these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled · after June 6, 1996 were required by SSD procedure to be permitted with a SUndry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular dispoSal: ,, ,Annular Disposal Letter .', 12/14/98 ~4 -~?_~ q4- ~ ¢z.- ~4-15'7.. ! / · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh #3 - ~:oo ~ ,~ . · Mi~e Point wells F-06, ~ 5, ~-06, J-13, L-24 - PBU wells-18-30, 18-31, 14~,~-43, ~-34, E-36, G-~A, ~d S-33- hd~v~du~ logs are provided to you fo~ t~ese ~ogs tis we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) 8CANNED NOV i :3 21102 RECEIVED ~--"- 14- 1998 Alaska 0ii & ~as Cons. ~0mmissi0~ Anchorage 8661 l 33(] AON CI':':':'aNN pesolo /-6/9~/[ 96/9~/~ 9S ~' ~ 0B9'1~ 9B/.'~; ' 3ff~l:l 'N6/'6~ 'oas '93-1 ,/-909 ~U 98~t~ 8# q§nopJnos V lC uedo g6/I.8/'~ I. g61/.IL ~ 06 600'i~ 806 ;~00'8 =1171.1:1 'N I. I..l.'Z8 oas '"I::IM,9S6t "lSN,St~9[: § ~'~ ................... Zt~Zg'[ ......... ~ ["~; uedo 96/~;/'& L g6/g/-d ~ snlelS pu=l pel$ azee~_-I ezeeJ_-i sp!nl-1 sp!nl:l qseM s§lo ~ lelOl uJno snlnuuv po!Jed I~SOds!o leu!-1 [uno [UJelUl [uno u~Jo-I [unO IdUJoO [uno 6!1:1 [uno pnlAI Luno 3seO le6a'l qidao IleM !Ul IJodel:l a^!l~ln[un [166 ~ Jeq~ueoeO 1!3un S66 [ 'Si~/lin se~unloA uoqoelul 6U!llpa ~o!~aS p~Jeq N:ldO 86//J9 /- 6/L/S 09 L H;'L , ~ e6ed uedo /.6/L~/~ 96/[Z~ OSL 90['Z 9gi~'Z [99'1~ 'NJ [1 'CZ '03S '-I~M ,L90[ "ISN ,996Z ZZZC CC-C] 6 uoAoc uedo Z6/0 [/~ '96/0~/~ 0GL 0SI 3BIB 'NJ L.L '9~ 'O:qS gL~C [C'O 6 uo~oc lJode~l e^!leln~un3 966L JeqtueoeO IRun S66L 'GZ/~lnp setunlOA uoqoelul Jelnuuv §U!ll!~O ~o!~.~S P'~u~eqs Shared Sei~ice Dr. illing Ann/~i~'r injection Volumes July 25, 1995, until December 1998 Cumulative Report Surface Casing Rig Inj Well Depth Nabors 28E B-33 3504' Nabors 28E E-34 3664 Nabors 28E E-36 3648 Nabors 28E E-37 3810 Nabors 28E E-39 3638 Cum Mud Legal Desc · Cum Total & Ctgs 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 3391'NSL 881'WEL, Sec 6,T11N, R14E 4,695 4,241 Cum Rig Cum Compl Cum Form Cum Inlerm Cum Final Disposal Period Wash Fluids Fluids Freeze Freeze Start End 857 195 80 5/1/96 12/31/96 1.420 858 40 110 8/23/95 12/31/95 1,293 3,096 365 100 7/25/95 12/31/95 · . 374 80 9/16/95 12/31/95 3358'NSL 501'W. EL, sec 6,T! !.N, .R1.4E ................. .2.~2.50 ............ 928 . 2_2..0 1,022 80 8/28/95 12/31/95 Annulus Status Broached · .. O O 3eh O >en O >en 10/20/95 12/31/95 O 3en Nabors 28E G-04A 3509 2917'NSL 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1.824 2,315 Nabors 28E G-21 3509 2911'NSL 2368'WEL. Sec 12,T11N, R14E 11,430 3,956 3.072 4,270 70 62 9/8/95 12/31/95 O3en Nabors 28E S-24 2750 1633'SNL 4228'WEL, Sec 35.T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 O3en Nabors 28E S-33 2958 1639'SNL 1487'WEL, Sec 35 T12N R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 __ 12/1/96 O3en Nab??...2.~E. ......... ~.~'4.!. ............................ 3~! ................... 41.5.2.'...l~..S..L,..~ ~ .0.~'....W...E.L.,......S.~(~..;~ .5..~..T-.! ;~ .N.'. ............................................... ..8.'...°.~.2. ............................. ~.!..5.? ...................... ~,.0.~ ............................. !.?..5..4 .......................................115 2/8/98 2/8/97 o:)en 168 1 oo 68 3/13/96 3/13/97 0 Nabors 28E S-42 3077 Sec 35, T12N, R12E 3en Nabors 2ES H-35 3157 4535'NSL 1266'WEL Sec 21 T11N R13E 4 860 3 725 555 480 20 80 10/26/95 12/31/95 O3en Nabors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 O3en Page 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 46 feet 3. Address Exploratow__._ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Milne Point Unit 4. Location of well at surface 8. Well number 3139' FNL, 2627' FEL, Sec. 06, T13N, R10E, UM (asp's541935, 6035593) MPF-62 At top of productive interval 9. Permit number / approval number 1171' FNL, 4315' FEL, Sec. 31, T14N, R10E, UM (asp's540177, 6042830) 195-161 At effective depth 10. APl number 910' FNL, 4331' FEL, Sec. 31, T14N, R10E, UM (asp's540159, 6043100) 50-029-22609-00 At total depth 11. Field / Pool 817' FNL, 4357' FEL, Sec. 31, T14N, R10E, UM (asp's 540132, 6043184) Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 11910 feet Plugs (measured) true vertical 7587 feet Effective depth: measured 11765 feet Junk (measured) true vertical 7470 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 250 sx Arcticset I (Approx 142' 142' Surface 9-5/8" 1160 sx PF 'C', 250 sx 6059' 4527' 'G', 250 sx PF 'E' Production 7" 361 sx Class 'G' 11877' 7561' Perforation depth: measured Open Porfs 11374' - 11382', 11434' - 11535' true vertical Open Perfs 7172'- 7178', 7217' - 7292' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tubing to 11269'. 3-1/2", 9.3#, L-80 Tubing Tail @ 11279'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 11269'. No SSSV in well. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 03/29/2002 4093 3145 Subsequent to operation 04/07/2002 3760 1774 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended _ Service WAG INJECTOR ~~at~~s~rect to the best of my knowledge. Title: Technical Assistant Date May 09, 2002 DeWayne R. Schnorr Prepared by DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE MPF-62 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/04/2002 WAG SWAP: GAS TO WATER INJECTION EVENT SUMMARY O4/O4/O2 WELL SUPPORT TECHS RIGGED UP AND SWAPPED BLINDS FOR WELL TO TAKE WATER. ALL FLANGES WERE TORQUE TO SPEC. HB&R RIGGED UP AND PUMPED 10 BBLS METHANOL FOLLOWED BY 107 BBLS SOURCE WATER THEN 3 BBLS METHANOL TO FREEZE PROTECT TRUCK. CONCLUSION: JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT ON INJECTION. FLUIDS PUMPED BBLS 13 METHANOL 107 SOURCE WATER 12O TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Dan Seamount Commissioner DATE: October 1,2000 THRU' Blair Wondzeli P.I Supervisor [ ~"~ (CO FROM: John Cr~'~ Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX F Pad 10i,30i,46i,62i,74i Milne Point Unit Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI F-lOi I TYpe,njl s I T.¥.D. 17082 I T,~i,~.~l 32O0 13200 13200 I~=oo'l,,ter,,.,I 4' P.T.D.I 196O940 ITypetesil P I Test psil ,.1771 I~asingl 0 I 1900'1 189°1 18801 P/F I ~P- Notes: - · Wel!lF-30,I Typelnj. I s I T.9.D.i ~o~' i~u~,~l ~oo i'~oo i~=oo I ~=oo IIntervall4 P.T.D.I 1951840 ITy~etestI P ITestpsil 1768 J CasingI 0 I 19101 1900 I 1960 I P/F I ~P" Note,: I Type,nj'I s I ~ ~ ~. I ~o~ I +;~":;~ I '~,oo I ~,oo I ~oo I ~,oo I,.,...a,!4 Well! F-46i P.T.D.I 1941270 ITypetesil P IT;;~'psil 1757 ]Ca~!~g'I 630 I 192C~ I 1900 ] 1900 I P/F 'l P- NoteS:Welll F.62i ITypelnj] S' ! T.V.D. I '7100 ]Tubing"i 3150 I 3150 I 3150 [ 3150'll~tervall 4" P.T.D.I 1951610 TypetesiI P ITestpsil 1775 i c~,;.g'l 840 i 1875 i 1845 I "1830'.1 P/F J __P.-- Notes: . ' WellI F-74i I Typelnj. 1 S ! T.~/.D. ! 7260 ]Tubing I 3350 13350 ! 3350I~so l,nterva, I 4 'P.T.D.I 1961080 T.v'.oetes{I P ITestpsii 181'5'jCasi~g} 1300 I 1900 j 1890 J 18~0.1 P/F I _P- Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperatcre Anomaly Sun,ey D= Differential Temperature Test 'Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) Test's Derails I traveled to BP's Miine Point Field to witness Mechanical Integrity Tests on F Pad. Larry. Niles was BP rep. in charge of testing. Testing went well with no failures witnessed .I.T.'s performed: 5__ Attachments: Number of Failures: 0 Total Time dudng tests: 2 hrs. c.c: MIT report form 5/12/00 L.G. MIT MPU F Pad 10-01-00jc.xls 10/3/00 6/30/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11118 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU B-14 L.~ ~. C ...... INJECTION PROFILE 970607 I 1 MPU E-07 t....L t L ..... INJECTION PROFILE 970606 1 1 MPU E-16 ~ INJECTION PROFILE 970605 1 1 MPU F-05 ,.~' PERFORATION RECORD 97051 7 1 1 MPU F-05 ~ ..... TEMP & PRESSURE SURVEY 97051 7 1 1 MPU F-05 "" GR/CCL LOG 970517 1 1 ,, , MPU F-26' ~--" GR/CCL LOG 970525 I 1 MPU F-26 / ISTATIC PRESS &TEMP 970527 I 1 MPU F-26 v' PERFORATION RECORD 970527 I 1 MPU F-50 '- -~ PERFORATION RECORD 970508 I 1 MPU F-50 ..... STATIC PRESSURE SURVEY 970509 1 1 MPU F-57 '.-'" PERFORATION RECORD 970512 I 1 MPU F-62 ~./ (.,~.t C INJECTION PROFILE 970608 I 1 MPU F-65 ./ PERFORATION RECORD 97051 I I 1 MPH -07 ,-- GPJCCL RECORD 97042 4 I 1 MPH -07 '-' GPJCCLRECORD 970427 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-161 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22609 4. Location of well at surface 9. Unit or Lease Name 2141 NSL, 2627' WEL, SEC. 6, T13N, R10E ~ ' -' Milne Point Unit At top of productive interval ;-'. ~~_~,~,_. ': !~i 10. Well Number 4108' NSL, 812' EWL, SEC. 31, T14N, R10E . MPF-62i v~.i~i~[~ ~ 11. Field and Pool At total depth } ~..~¢'~_ ~:;-! 4461' NSL, 771' EWL, SEC, 31 T14N, R10E ~. ' ~ ...................... ~ - ~-.~ Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. L~tse Designation and Serial No. Sands KBE= 45.75'I ADL 355018 12. Date Spudded10/26/95 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffsh°re I 16' N°' °f C°mpleti°nsl 1/04/95 11/11/95 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 11910 7587 FT 11765 7470 F~ [] Yes [] No I N/A MD ! 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR, JB 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-I-IN G DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT80LHE 32' 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 36' 6059' 12-1/4" [1160 sx PF 'C', 250 sx 'G', 250 sx PF 'E' 7" 26# L-80 31' 11877' 8-1/2" 361 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.3#, L-80 11280' 11269' MD TVD MD TVD 11374' - 11382' 7172' - 7178' 11434' - 11535' 7217' - 7292' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) April 3, 1996 I Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing PressureCALCULATED I~ OIL-BBL iGAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , .. ,. . , , Form 10-407 Rev. 07-01-80 Submit In Duplicate -' Geologic Markers 30. I-ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk D 11140' 6999' Top Kuparuk C 11368' 7168' Top Kuparuk A3 11432' 7215' Top Kuparuk A2 11454' 7232' Top Kuparuk A1 11484' 7254' Top Miluveach 11570' 7319' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~'J/~~ /, /cc 'Bm Schofield *"'?(~ , Title Senior Drilling Engineer Date ~ q ~;. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. iTEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SurfCsg Dep 16059 Legal Desc (Sec, T, R) VOLUME (BBLS ~v~ethod of dispIosal=pumpin~l down outer annulus / SOURCENuMBERWELL INJECTIoNDATE OF MUD/CTGS BRINE WATER DIESEL/PRoT.FREEZEI Daily ~um./o~al/ COMPLICATIONS, COMMENTS I I MP F-62 1 1 / 8 / 9 5 21 5 liii:~ii?;[ iiiiii!i'i?~iii i!iiii i?~i;,i?~i~!i~iIi~i~/ MP F-62 1 1 / 9/9 5 1 01 70. 00l{ii~iiiii~=~i=;[iii!iii{i!ii iiii;ii:iiiiiiii Well Cum Total Cum Mud/Ctgl~ii~!~ I Cum Brine Cum Water Cum Dies/FP BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPF-62I BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/26/95 02:00 SPUD: 10/26/95 05:00 RELEASE: OPERATION: DRLG RIG: NABORS 27E WO/C RIG: NABORS 27E 10/26/95 (1) TD: 110'( 0) 10/27/95 ( 2) TD: 1239' (1129) 10/28/95 (3) TD: 3537' (2298) 10/29/95 (4) TD: 5583' (2046) 10/30/95 ( 5) TD: 6080' ( 497) 10/31/95 (6) TD: 6080' ( 0) NU DIVERTER LINES MW: 0.0 VIS: 0 MOVE IN RIG UP. MOVE RIG FROM MPF-70 TO MPF-62I. RIG ACCEPTED @0200 HRS., 10/26/95. NU DIVERTER SPOOL, HYDRIL & DIVERTER LINES. SET RISE & FLOWLINE. DRILLING MW: 0.0 VIS: 0 FINISH NU DIVERTER LINES, FUNCTION TEST, WITNESSING WAIVED BY JOHN SPAULDING, AOGCC. DRILL F/105' TO 1239' DRILLING MW: 0.0 VIS: 0 DRILLING F/1239' T/3036' CIRC SWEEP AROUND UNTIL HOLE CLEANED UP. MONTIOR WELL. OK. MADE SHORT TRIP. HOLE IN GOOD CONDITION. DRILL F/3036' T/3537' CIRC FOR BIT TRIP MW: 0.0 VIS: 0 DRILL F/3537' T/5298'. CIRC HI/LO SWEEP & CLEAN UP HOLE. MONITOR WELL. OK. SHORT TRIP T/3000'. NO FILL. OK. DRILL F/5298' T/5583'. BIT TORQUED UP. PREP TO TRIP. CIRC HI/LO SWEEP & CLEAN UP HOLE. RUNNING 9-5/8" CASING MW: 0.0 VIS: 0 FINISH CIRC LO/HI SWEEP. MONITOR WELL. OK. POOH FOR BIT. DOWNLOAD MWD. CHANGE BITS. LD MPT. CHANGE BATTERIES IN LWD. PU NEW MPT. PROGRAM MWD. RIH. NO FILL. DRILL F/5583' T/6080'. CIRC. MONITOR WELL. OK. SHORT TRIP T/5500'. NO FILL. OK. CIRC LO/HI SWEEP UNTIL HOLE CLEAN. MONITOR WELL. OK. DRY JOB. POOH. DOWNLOAD MWD. LD BHA. RU TO RUN 9-5/8" CASING. START RUNNING CASING. TESTING BOPE MW: 0.0 VIS: 0 FINISH RUNNING 9-5/8" CASING. LAND SAME. FLOAT SHOE @ 6059' & FLOAT COLLAR @ 5974'. CIRC & COND. TEST CEMENT LINES. DISPLACE CEMENT. BUMP PLUG. FLOATS HELD. OK. CIP @ 1830 HRS., 10/30/95. FLUSH FLOWLINE. ND FLOWLINE, DIVERTER LINES & DIVERTER. RU 1" PERFORM TOP JOB. INSTALL FMC GEN SPEED HEAD & TEST. NU BOPE. SET MOUSEHOLE. TEST BOPE & ANNULUS. OK. TEST WITNESSED BY BOBBY FOSTER WITH AOGCC. WELL : MPF-62I OPERATION: RIG : NABORS 27E PAGE: 2 11/Ol/95 ( 7) TD: 7160' (1080) 11/02/95 (8) TD: 9703'(2543) 11/03/95 (9) TD:ll300' (1597) 11/04/95 (10) TD:ll910' ( 610) 11/05/95 (11) TD:ll910' ( 0) 11/06/95 (12) TD:ll910' ( 0) DRILLING MW: 0.0 VIS: 0 SET WEAR RING. PU BHA #3. RUN HWDP F/DERRICK. PU DP F/SKATE. TEST CASING. OK. PU PIPE T/5922'. DRILL FLOAT COLLAR @ 5932' & 40' CEMENT. TEST CASING. OK. DRILL CEMENT, SHOE & 10' NEW HOLE T/6090' CBU. TEST SHOE TO EMW. DRILL F/6090' T/7111'. CONTROL DRILL F/CUTTINGS. CIRC & CLEAN HOLE, SHAKERS NOT HANDLING SOLIDS. DRILL F/7111' T/7160' SHORT TRIP MW: 0.0 VIS: 0 DRILL F/7160' T/8008'. CIRC LO/HI VIS SWEEP UNTIL HOLE CLEAN. SHORT TRIP T/6268'. OK. NO FILL. DRILL F/8008' T/9707'. CIRC L0/HI VIS SWEEP UNTIL HOLE CLEAN. SHORT TRIP T/7900'. DRILLING MW: 0.0 VIS: 0 DRILL F/9703' T/11212' PUMP LO/HI VIS SWEEP, CIRC HOLE CLEAN. CHECK FOR FLOW. PUMP PILL. SHORT TRIP T/9650' OK. NO FILL. DRILL F/11212' T/il300'. DRILLING MW: 0.0 VIS: 0 DRILL F/l1300' T/l1910' PUMP LO/HI VIS SWEEP. CIRC HOLE CLEAN. CHECK FOR FLOW, PUMP PILL, BLOW DOWN LINES. POOH T/5947'. RIH T/9923', FILL DP, CONT RIH T/l1910' NO FILL. PUMP LO/HI VIS SWEEP, CIRC HOLE CLEAN. SPOT PILL. CHECK FOR FLOW, PUMP PILL. LD DP. CUT DRILLING LINE. LD DP. CHECK FLOATS MW: 0.0 VIS: 0 LD DP & BHA TO MWD. DOWNLOAD & RETRIEVE SOURCES FROM MWD. FINISH LD BHA. PULL WEAR BUSHING. CHANGE BAILS & RU CASING EQUIP. RUN 7" CASING. WORK PIPE TO ESTABLISH CIRC. RAN LOW ON MUD. SWITCH TO HOWCO & DO CEMENT JOB. BUMPED PLUG. CHECK FLOATS. OK. WELL STARTED FLOWING UP ANNULUS AFTER CIP. SHUT HYDRIL ON CASING. STABILIZED. PU 3-1/2" TUBING MW: 0.0 VIS: 0 MONITOR CASING PRESSURE WHILE DRIFTING, CLEANING. INSTALL SEAL RINGS & STRAP 3-1/2" TUBING. LD LANDING JT. CHANGE BAILS & ELEVATORS ON TOP DRIVE. BLEED OFF ANNULUS, STILL FLOWING. HOOK UP GUZZLER TO ANNULUS. SET PACKOFF, RILDS. TEST PACKOFF. OK. CHANGE TOP RAMS TO 3-1/2". INSTALL TEST PLUG. TEST BOPE, SAFETY VALVES & MANIFOLD. RD TEST EQUIP & INSTALL WEAR RING. RU TUBING TONGS. MU BHA. RIH WITH TUBING FROM PIPE SHED. WELL : MPF-62I OPERATION: RIG : NABORS 27E PAGE: 3 11/07/95 (13) TD:ll910 PB: 0 11/08/95 (14) TD:ll910 PB: 0 11/09/95 (15) TD:ll910 PB: 0 11/10/95 (16) TD:ll910 PB: 0 11/11/95 (17) TD:ll910 PB: 0 RUN CBL MW: 0.0 RIH WITH TUBING FROM PIPE SHED. RU & REV CIRC WITH DIRT MAGNET & ZANVIS SWEEPS & CLEAN WATER UNTIL CLEAN RETURNS. DISPLACE WELL WITH BRINE. RU MI FILTERING UNIT. FILTER BRINE. RD HOSES. PU TUBING TONGS. POOH. CHANGE OUT SEAL RINGS IN COLLARS. ND FLOWLINE & DRILLING NIPPLE. NU SHOOTING FLANGE. RU ATLAS WIRELINES & RIH WITH CBL. RUN 6" GR/JB MW: 0.0 RUN CBL, RD ATLAS. CHANGE OUT LOGGING UNITS. RU ATLAS PERF UNIT. PU LUBRICATOR & TEST. RUN #1 - #5 PERF GUNS. RUN #6, 6" GR/JB TO 11350'. POOH MW: 0.0 MAKE REPAIR GR/JB RUN T/11350' RD ATLAS WIRELINE. ND SHOOTING FLANGE. NU RISER & FLOWLINE. RU TUBING TONGS, STRAP & MU BHA. RIH, MULE SHOE & SCRAPER @ 11283'. REV CIRC. FILTER BRINE. CHECK FOR FLOW. POOH. CHANGE SEAL RINGS ON WAY OUT OF HOLE. MONITOR TUBING MW: 0.0 POOH, R/U AND RIH WITH 3-1/2" TUBING. LAND TUBING, RUN IN LOCK DOWNS. REVERSE INHIBITED BRINE AND DIESEL. TEST LINES. DROP BALL AND ATTEMPT TO SET PACKER W/HOT OIL. TEST PACKER. PRESSURE ANNULUS, BLEED OFF. MONITOR TUBING. SECURE TREE MW: 0.0 MONITOR TUBING PRESSURE. SPOT CAMCO SLICKLINE UNIT. RU LUBRICATOR & TEST. RETRIEVE ROD & BALL FROM OTIS XN NIPPLE. RD CAMCO. UNDER BALANCE PROBLEM. MONITOR. TBG DEAD. LD LANDING JT. INSTALL 2-WAY CHECK. BREAK PUP OFF LANDING JT. CHANGE TOP RAMS, RD MOUSEHOLE, FLOWLINE, BOPE & XO SPOOL. NU TREE. TEST HANGER & TREE. RU LUBRICATOR & PULL 2-WAY CHECK. TEST PACKER. WITNESSED BY JOHN SPAULDING. FREEZE PROTECT TUBING WITH DIESEL. INSTALL BPV WITH LUBRICATOR. FILL TREE WITH DIESEL. SECURE TREE. RIG RELEASED @ 0600 HRS., 11/11/95. SIGNATURE: (drilling superintendent) DATE: SP' Y-SUN DRILLING SERVICES ANCHORAGE ALASKA SH3~RED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/95 DATE OF SURVEY: 110395 MWD SURVEY JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -45.75 243 243.03 197.28 334 334.83 289.08 425 425.29 379.54 517 517.08 471.33 0 0 N .00 E .00 .00N .00E 0 15 N 9.66 W .10 .52N .09W 0 18 N 19.36 W .09 .95N .20W 0 21 N 28.17 W .08 1.44N .42W 0 38 N 5.40 W .37 2.20N .60W .00 .53 .98 1.49 2.28 607 607.36 561.61 698 698.23 652.48 787 787.78 742.03 881 881.92 836.17 976 976.02 930.27 0 42 N 7.09 W .08 3.26N .72W 0 37 N 73.63 E .95 3.95N .32W 0 55 S 85.52 E .46 4.03N .87E 1 4 S 79.78 E .19 3.82N 2.51E 0 53 S 33.37 E .85 3.05N 3.78E 3 .34 3,93 3.74 3,17 2.13 1072 1071.94 1026.19 1163 1163.24 1117.49 1255 1254.95 1209.20 1351 1351.59 1305.84 1446 1446.48 1400.73 1 3 S 18.23 E .32 1.58N 4.47E 1 8 S 19.51 E .09 .07S 5.04E 1 0 S 40.85 E .46 1.55S 5.87E 1 37 N 51.76 E 1.93 1.34S 7.50E 4 34 N 29.72 E 3.30 2.78N 10.44E .55 -1.19 -2.81 -2.98 .39 1543 1542.64 1496.89 1638 1637.34 1591.59 1733 1731.33 1685.58 1825 1823.05 1777.30 1919 1916.13 1870.38 6 29 N 16.50 E 2.36 6 54 N 5.35 E 1.43 6 52 N 9.66 W 1.90 6 50 N 13.24 W .46 6 52 N 14.93 W .22 11.37N 13.90E 8.00 22.25N 15.97E 18.14 33.50N 15.55E 29.21 44.31N 13.36E 40.23 55.17N 10.63E 51.43 2014 2010.55 1964.80 2108 2102.79 2057.04 2203 2196.39 2150.64 2298 2287.45 2241.70 2391 2377.20 2331.45 8 10 13 15 17 11 N 8.12 W 1.67 35 N 8.20 W 2.57 19 N 7.63 W 2.86 28 N 9.84 W 2.36 17 N 6.85 W 2.14 67.39N 8.21E 63.88 82.49N 6.04E 79.08 102.12N 3.32E 98.83 125.21N .26W 122.14 151.31N 4.05W 148.43 2484 2465.63 2419.88 2579 2554.91 2509.16 2673 2642.00 2596.25 2767 2727.70 2681.95 2859 2810.17 2764.42 19 7 21 6 22 57 24 55 27 46 N 3.97 W 2.20 N .35 W 2.45 N 2.47 E 2.28 N 4.13 E 2.22 N 3.82 E 3.09 180.27N 6.76W 177.26 212.93N 7.94W 209.37 248.15N 7.25W 243.56 286.14N 5.04W 280.10 326.89N 2.22W 319.21 2958 2896.02 2850.27 3053 2976.40 2930.65 3149 3054.60 3008.85 3244 3130.75 3085.00 3338 3203.54 3157.79 31 33 36 38 4O 9 51 12 3 12 N 3 . 17 E 3 . 45 N 3.58 E 2.84 N 2.32 E 2.56 N .91 E 2.14 N 1.04 E 2.28 375.30N .73E 365.75 426.44N 3.75E 414.94 481.18N 6.55E 467.69 538.81N 8.16E 523.52 598.02N 9.17E 581.03 SP IY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/9 DATE OF SURVEY: 110395 MWD SURVEY JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3430 3272.63 3226.88 3526 3342.06 3296.31 3620 3407.64 3361.89 3713 3469.68 3423.93 3804 3528.26 3482.51 42 29 44 37 47 8 49 5 51 18 N .26 W 2.66 658.81N 9.57E N 1.25 W 2.34 724.83N 8.69E N 1.83 W 2.70 792.43N 6.86E N 3.93 W 2.69 861.51N 3.37E N 4.93 W 2.57 931.62N 2.07W 640.21 704.77 771.09 839.22 908.78 3898 3585.41 3539.66 3993 3639.82 3594.07 4088 3689.71 3643.96 4183 3735.77 3690.02 4275 3775.86 3730.11 53 27 56 37 59 46 62 31 65 42 N 5.66 W 2.38 1005.46N 8.92W N 5.54 W 3.34 1082.93N 16.52W N 8.10 W 4.03 1162.80N 26.10W N 10.65 W 3.71 1245.25N 39.74W N 11.96 W 3.70 1326.26N 55.94W 982.30 1059.52 1139.52 1222.94 1305.53 4369 3814.49 3768.74 4465 3853.79 3808.04 4560 3892.88 3847.13 4655 3931.74 3885.99 4750 3971.20 3925.45 65 50 65 33 65 51 65 43 65 35 N 14.62 W 2.58 1409.81N 75.68W N 15.57 W .96 1493.86N 98.35W N 16.07 W .57 1577.20N 121.97W N 16.02 W .15 1660.26N 145.86W N 15.74 W .29 1744.16N 169.72W 1391.37 1478.36 1564.86 1651.16 1738.26 4843 4009.53 3963.78 4938 4049.21 4003.46 5030 4088.08 4042.33 5124 4127.80 4082.05 5222 4169.23 4123.48 65 20 65 19 65 0 65 0 64 46 N 15.36 W .46 1825.11N 192.25W N 15.50 W .14 1908.40N 215.24W N 15.24 W .42 1989.37N 237.49W N 15.37 W .13 2071.56N 259.99W N 14.43 W .90 2156.99N 282.72W 1822.19 1908.51 1992.40 2077.53 2165.88 5315 4208.22 4162.47 5411 4247.91 4202.16 5504 4286.59 4240.84 5599 4326.26 4280.51 5690 4365.41 4319.66 65 47 65 24 65 18 65 4 64 29 N 17.33 W 3.03 2238.44N 305.90W N 17.60 W .47 2321.88N 332.15W N 17.54 W .13 2402.26N 357.60W N 17.59 W .24 2484.08N 383.50W N 18.97 W 1.50 2563.02N 409.58W 2250.44 2337.64 2421.66 2507.19 2589.95 5788 4407.52 4361.77 5881 4448.03 4402.28 5975 4489.54 4443.79 6004 4502.21 4456.46 6092 4541.23 4495.48 64 27 63 37 64 1 63 55 63 57 N 14.79 W 3.86 2647.35N 435.17W N 15.86 W 1.37 2727.61N 457.16W N 14.41 W 1.45 2809.14N 479.21W N 15.76 W 4.22 2834.21N 485.96W N 14.47 W 1.31 2911.21N 506.76W 2677.86 2761.00 2845.39 2871.33 2951.03 6190 4584.02 4538.27 6285 4625.62 4579.87 6379 4665.96 4620.21 6474 4705.77 4660.02 6570 4746.06 4700.31 63 58 64 6 65 7 65 11 65 11 N 14.32 W .14 2996.04N 528.53W N 15.08 W .73 3078.68N 550.22W N 15.14 W 1.09 3160.77N 572.38W N 16.04 W .86 3243.61N 595.49W N 15.88 W .15 3327.42N 619.46W 3038.58 3123.97 3208.94 3294.84 3381.87 SP? 'Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/95 DATE OF SURVEY: 110395 MWD SURVEY JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6662 4784.67 4738.92 6760 4825.55 4779.80 6854 4865.31 4819.56 6950 4906.48 4860.73 7045 4947.44 4901.69 65 25 N 16.02 W .28 3408.14N 642.53W 65 8 N 15.80 W .35 3493.54N 666.88W 64 46 N 17.77 W 1.94 3574.99N 691.44W 64 24 N 18.74 W .99 3657.29N 718.59W 64 42 N 16.69 W 1.97 3739.31N 744.78W 3465.71 3554.38 3639.26 3725.53 3811.31 7136 4986.23 4940.48 7231 5026.30 4980.55 7326 5066.22 5020.47 7421 5106.79 5061.04 7516 5147.70 5101.95 64 55 N 16.82 W .26 3818.28N 768.56W 65 12 N 15.54 W 1.26 3901.05N 792.57W 64 58 N 16.98 W 1.40 3983.60N 816.65W 64 33 N 16.14 W .92 4066.10N 841.18W 64 21 N 15.87 W .33 4148.37N 864.78W 3893.60 3979.64 4065.47 4151.36 4236.82 7610 5187.38 5141.63 7704 5225.83 5180.08 7802 5265.09 5219.34 7896 5303.01 5257.26 7990 5341.16 5295.41 65 39 N 16.02 W 1.38 4230.22N 888.17W 66 5 N 13.33 W 2.65 4313.22N 909.90W 66 22 N 13.68 W .44 4399.91N 930.72W 66 17 N 13.72 W .09 4483.96N 951.21W 65 46 N 13.76 W .54 4567.32N 971.59W 4321.82 4407.58 4496.72 4583.22 4669.03 8085 5380.53 5334.78 8179 5419.80 5374.05 8273 5458.94 5413.19 8367 5498.21 5452.46 8463 5538.32 5492.57 65 26 N 14.95 W 1.19 4651.44N 993.12W 65 13 N 14.39 W .59 4734.15N 1014.77W 65 26 N 13.41 W .98 4816.86N 1035.24W 65 18 N 13.51 W .18 4900.15N 1055.18W 64 51 N 13.24 W .53 4984.15N 1075.15W 4755.83 4841.29 4926.47 5012.11 5098.44 8556 5577.87 5532.12 8649 5618.06 5572.31 8743 5659.24 5613.49 8836 5700.54 5654.79 8933 5742.73 5696.98 64 43 N 12.83 W .43 5065.99N 1094.09W 64 12 N 13.45 W .81 5147.92N 1113.22W 63 51 N 12.65 W .85 5230.30N 1132.32W 63 31 N 13.41 W .82 5311.68N 1151.15W 64 43 N 13.02 W 1.30 5396.34N 1171.03W 5182.45 5266.58 5351.15 5434.68 5521.64 9029 5784.01 5738.26 9124 5824.70 5778.95 9217 5864.44 5818.69 9311 5904.92 5859.17 9406 5945.97 5900.22 64 27 N 12.99 W .28 5481.04N 1190.59W 64 49 N 14.08 W 1.11 5564.52N 1210.69W 64 40 N 14.98 W .89 5646.09N 1231.83W 64 28 N 14.33 W .66 5728.48N 1253.37W 64 11 N 15.43 W 1.09 5811.01N 1275.30W 5608.57 5694.43 5778.65 5863.77 5949.11 9501 5987.74 5941.99 9596 6029.51 5983.76 9689 6071.98 6026.23 9781 6116.36 6070.61 9877 6164.61 6118.86 63 49 N 14.76 W .74 5893.75N 1297.62W 63 31 N 16.01 W 1.23 5975.16N 1320.02W 62 3 N 16.02 W 1.58 6054.56N 1342.81W 60 40 N 16.10 W 1.49 6132.70N 1365.30W 58 29 N 16.42 W 2.32 6211.59N 1388.31W 6034.74 6119.09 6201.58 6282.76 6364.79 SF IY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/9 DATE OF SURVEY: 110395 MWD SURVEY JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 9970 6214.77 6169.02 56 34 N 15.67 W 2.15 10066 6268.48 6222.73 55 0 N 15.25 W 1.69 10159 6323.04 6277.29 53 44 N 15.81 W 1.43 10253 6379.51 6333.76 51 58 N 15.02 W 2.01 10347 6438.40 6392.65 50 15 N 14.13 W 1.97 6287.37N 1410.11W 6443.52 6363.50N 1431.17W 6522.43 6436.85N 1451.55W 6598.47 6508.71N 1471.37W 6672.93 6579.37N 1489.75W 6745.92 10442 6500.72 6454.97 48 24 N 14.69 W 1.99 10537 6564.76 6519.01 46 38 N 14.16 W 1.90 10631 6630.39 6584.64 45 2 N 12.67 W 2.04 10726 6697.63 6651.88 44 3 N 12.10 W 1.12 10818 6764.04 6718.29 43 37 N 12.59 W .59 6649.62N 1507.79W 6818.42 6717.35N 1525.22W 6888.33 6783.09N 1540.91W 6955.91 6847.73N 1555.11W 7022.09 6910.04N 1568.74W 7085.88 10913 6833.21 6787.46 43 20 N 12.73 W .32 11006 6901.51 6855.76 42 39 N 14.27 W 1.35 11100 6970.72 6924.97 42 6 N 14.94 W .75 11195 7040.76 6995.01 42 14 N 14.74 W .20 11291 7112.03 7066.28 42 15 N 15.33 W .41 6974.06N 1583.12W 7151.48 7035.97N 1597.98W 7215.15 7097.09N 1613.91W 7278.28 7158.42N 1630.16W 7341.69 7220.93N 1646.95W 7406.37 11385 7181.66 7135.91 42 15 N 15.37 W .04 11482 7253.85 7208.10 41 21 N 16.06 W 1.04 11576 7325.24 7279.49 40 20 N 16.84 W 1.21 11670 7397.82 7352.07 38 43 N 17.21 W 1.73 11765 7471.85 7426.10 37 54 N 17.19 W .88 7281.93N 1663.69W 7469.56 7344.09N 1681.18W 7534.05 7403.29N 1698.65W 7595.66 7460.57N 1716.19W 7655.40 7516.46N 1733.49W 7713.73 11799 7499.21 7453.46 37 17 N 17.55 W 1.85 11910 7586.98 7541.23 37 17 N 17.55 W .00 7536.56N 1739.78W 7734.74 7600.31N 1759.94W 7801.37 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7801.42 FEET AT NORTH 13 DEG. 2 MIN. WEST AT MD = 11910 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 347.16 DEG. SU tY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/95 DATE OF SURVEY: 110395 JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -45.75 .00 N .00 E .00 1000 999.94 954.19 2.74 N 3.99 E .06 2000 1995.91 1950.16 65.30 N 8.50 E 4.09 3000 2931.58 2885.83 397.28 N 1.98 E 68.42 4000 3643.33 3597.58 1088.25 N 17.04 W 356.67 .06 4.03 64.33 288.26 5000 4075.09 4029.34 1962.48 N 230.17 W 924.91 6000 4500.39 4454.64 2830.62 N 484.95 W 1499.61 7000 4927.89 4882.14 3699.67 N 732.90 W 2072.11 8000 5345.04 5299.29 4575.70 N 973.65 W 2654.96 9000 5771.34 5725.59 5455.20 N 1184.63 W 3228.66 568.24 574.70 572.49 582.85 573.70 10000 6231.03 6185.28 6311.09 N 1416.76 W 3768.97 11000 6896.45 6850.70 7031.46 N 1596.83 W 4103.55 11910 7586.98 7541.23 7600.31 N 1759.94 W 4323.02 540.31 334.58 219.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP' !Y-SUN DRILLING SERVICES ANCHORAGE ALASKA P~GE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/95 DATE OF SURVEY: 110395 JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -45.75 .00 N .00 E 45 45.75 .00 .00 N .00 E 145 145.75 100.00 .10 N .02 W 245 245.75 200.00 .53 N .09 W 345 345.75 300.00 1.01 N .22 W .00 .00 .00 .00 .00 .00 .00 .00 .00 445 445.75 400.00 1.55 N .48 W 545 545.75 500.00 2.52 N .64 W 645 645.75 600.00 3.71 N .76 W 745 745.75 700.00 4.08 N .20 E 845 845.75 800.00 3.94 N 1.83 E .00 .00 .01 .01 .02 .01 .02 .01 .04 .01 945 945.75 900.00 3.44 N 3.52 E 1045 1045.75 1000.00 2.04 N 4.32 E 1145 1145.75 1100.00 .25 N 4.92 E 1245 1245.75 1200.00 1.42 S 5.76 E 1345 1345.75 1300.00 1.44 S 7.37 E .05 .02 .07 .01 .08 .02 .10 .02 .13 .03 1446 1445.75 1400.00 2.74 N 10.41 E 1546 1545.75 1500.00 11.71 N 14.00 E 1647 1645.75 1600.00 23.26 N 16.06 E 1747 1745.75 1700.00 35.21 N 15.25 E 1848 1845.75 1800.00 46.96 N 12.73 E .28 .15 .76 .49 .46 .69 .18 .73 .90 .72 1949 1945.75 1900.00 58.62 N 9.71 E 2050 2045.75 2000.00 72.41 N 7.49 E 2152 2145.75 2100.00 90.95 N 4.85 E 2254 2245.75 2200.00 113.95 N 1.67 E 2358 2345.75 2300.00 141.60 N 2.88 W 3.62 .72 4.60 .98 6.35 1.75 9.02 2.67 12.89 3.86 2463 2445.75 2400.00 173.39 N 6.28 W 2569 2545.75 2500.00 209.39 N 7.92 W 2677 2645.75 2600.00 249.74 N 7.18 W 2787 2745.75 2700.00 294.65 N 4.43 W 2900 2845.75 2800.00 346.14 N .98 W 17 24 32 41 54 .88 5.00 .20 6.32 .05 7.85 .73 9.68 .28 12.55 3016 2945.75 2900.00 406.33 N 2.52 E 3138 3045.75 3000.00 474.71 N 6.29 E 3263 3145.75 3100.00 550.55 N 8.35 E 3394 3245.75 3200.00 634.26 N 9.66 E 3531 3345.75 3300.00 728.46 N 8.61 E 71.07 92.30 117.85 148.29 185.71 16 .79 21.23 25.54 30 .44 37.42 SP ..... !Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/95 DATE OF SURVEY: 110395 JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3676 3445.75 3400.00 3832 3545.75 3500.00 4004 3645.75 3600.00 4205 3745.75 3700.00 4445 3845.75 3800.00 834.02 N 5.23 E 953.37 N 3.95 W 1091.99 N 17.43 W 1264.46 N 43.42 W 1476.82 N 93.60 W 231.19 45.49 287.21 56.01 358.72 71.51 459.93 101.21 600.07 140.13 4689 3945.75 3900.00 4929 4045.75 4000.00 5167 4145.75 4100.00 5406 4245.75 4200.00 5645 4345.75 4300.00 1690.11 N 154.43 W 1901.14 N 213.22 W 2108.66 N 270.15 W 2317.40 N 330.73 W 2523.95 N 396.23 W 743.36 143.29 884.17 140.81 1021.46 137.29 1160.76 139.30 1299.42 138.66 5876 4445.75 4400.00 6103 4545.75 4500.00 6331 4645.75 4600.00 6569 4745.75 4700.00 6808 4845.75 4800.00 2723.19 N 455.90 W 2920.17 N 509.07 W 3118.90 N 561.06 W 3326.76 N 619.28 W 3535.36 N 678.88 W 1430.27 130.85 1557.49 127.23 1685.97 128.48 1823.87 137.90 1962.76 138.88 7041 4945.75 4900.00 7278 5045.75 5000.00 7512 5145.75 5100.00 7753 5245.75 5200.00 8001 5345.75 5300.00 3735.88 N 743.76 W 3941.62 N 803.87 W 4144.47 N 863.67 W 4357.00 N 920.30 W 4577.23 N 974.02 W 2096.05 133.29 2232.59 136.54 2366.53 133.94 2508.20 141.68 2655.97 147.77 8241 5445.75 5400.00 8480 5545.75 5500.00 8712 5645.75 5600.00 8940 5745.75 5700.00 9173 5845.75 5800.00 4788.79 N 1028.55 W 4999.56 N 1078.77 W 5203.48 N 1126.30 W 5402.58 N 1172.47 W 5607.90 N 1221.66 W 2796.25 140.28 2934.89 138.64 3066.93 132.04 3194.49 127.55 3328.11 133.63 9406 5945.75 5900.00 9632 6045.75 6000.00 9840 6145.75 6100.00 10026 6245.75 6200.00 10198 6345.75 6300.00 5810.58 N 1275.18 W 6006.50 N 1329.01 W 6182.09 N 1379.61 W 6332.19 N 1422.63 W 6466.64 N 1459.98 W 3460.38 132.26 3586.84 126.47 3695.18 108.34 3780.63 85.46 3852.32 71.69 10358 6445.75 6400.00 10509 6545.75 6500.00 10653 6645.75 6600.00 10792 6745.75 6700.00 10930 6845.75 6800.00 6587.95 N 1491.91 W 6697.84 N 1520.30 W 6798.09 N 1544.28 W 6893.03 N 1564.95 W 6985.60 N 1585.73 W 3912.77 60.45 3964.07 51.29 4007.71 43.64 4047.14 39.43 4084.98 37.85 S~ ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPF-62I 500292260900 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 9/95 DATE OF SURVEY: 110395 JOB NUMBER: AK-MM-951055 KELLY BUSHING ELEV. = 45.75 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 11066 6945.75 6900.00 7075.28 N 1608.09 W 4121.16 36.18 11201 7045.75 7000.00 7162.81 N 1631.31 W 4156.07 34.91 11336 7145.75 7100.00 7250.47 N 1655.04 W 4191.16 35.09 11471 7245.75 7200.00 7337.24 N 1679.20 W 4225.74 34.58 11603 7345.75 7300.00 7419.96 N 1703.70 W 4257.82 32.08 11732 7445.75 7400.00 7497.04 N 1727.48 W 4286.31 28.49 11858 7545.75 7500.00 7570.37 N 1750.47 W 4312.42 26.12 11880 7563.11 7517.36 7582.98 N 1754.46 W 4316.89 4.46 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Date. B.P. EXPLORATION ~'"-" / &l/ WELL NO: MPF-62 F-PAD, MILNE POINT, ALASKA Gyro Muitishot Survey Of 3.5" Tubing Survey date · 2 JUNE 1998 Job number' AK0696G347 RECEIVED BPXA P[::)O SR347.DOC gyro/ /data Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 July 16, 1996 B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re' F-Pad, Well No: MPF-62, Milne Point, North Slope AK Enclosed please find one (1) original and six (6) copies and one (1) disk of the completed survey of Well #MPF-62 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Robert J. Shoup Operations Manager RS/2c Serving the World,.qde Energy Industry with Precision Survey I ....... ~n,a ,on gyro/data CONTENTS JOB NUMBER :AK0696G347 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL EQUIPMENT AND CHRONOLOGICAL REPORT SR347.DOC .gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR347,DOC gyro/data DISCUSSION JOB NUMBER' AK0696G347 Tool 746 was run in well# MPF-62 on ATLAs 7/32" Wireline inside tubing. The survey was run without problems. SR347. DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0696G347 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR347.DOC 2. SURVEY DETAILS SR347.DOC gyro/data SURVEY DETAILS .JOB NUMBER: AK0696G347 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MILNE POINT FIELD, ALASKA WELL: MPF-62 LATITUDE: 70.505000 N LONGITUDE: 149.5 W SURVEY DATE: 2 JUNE 1996 SURVEY TYPE : MULTISHOT IN 3.5" TUBING DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 45.75 FT. 11750 SURVEY TIED ONTO: NA SURVEY INTERVAL: 100' FROM 0 - 11750' UTM CO-ORDINATES: TARGET DIRECTION: 347.16 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD SR347.DOC gyro/data, 3. OUTRUN SURVEY LISTING SR347.DOC A Gyroda t a D.i re c t i ona 1 Survey for B.P. EXPLORATION WELL: F PAD, WELL #MPF-62, 3.5" TUBING Location: ATLAS, MILNE POINT, AK ob Number: AK0696G347 un Date: 2-Jun-96 14:15:00 urveyor: TOM STODDARD 'alculation Method: MINIMUM CURVATURE urvey Latitude: 70.505000 deg. N iub-sea Correction from Vertical Reference: 45.75 ft. .zimuth Correction: Bearings are Relative to True North 'roposed Well Direction: 347.160 deg ~ertical Section Calculated from Well Head Location llosure Calculated from Well Head Location [orizon{al Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey .P. EXPLORATION ELL: F PAD, WELL #MPF-62, 3.5" TUBING ocation: ATLAS, MILNE POINT, AK ob Number: AK0696G347 EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH. SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -45.8 0.00 0.0 0.0 - 11750 FT. GYRO MULTISHOT SURVEY RUN INSIDE 3.5" TUBING .LL MEASURED DEPTHS ARE REFERENCED TO ATLAS R.K.B. OF 45'8" Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 115.0 .19 338.42 115.0 .2 69.2 .17 215.0 .20 333.29 215.0 .5 169.2 .02 315.0 .28 345.25 315.0 .9 269.2 .09 415.0 .38 348.84 415.0 1.5 369.2 .11 515.0 .42 357.92 515.0 2.2 469.2 .07 615.0 .47 .75 615.0 3.0 569.2 .05 715.0 .62 75.18 715.0 3.4 669.2 .67 815.0 .89 95.58 815.0 3.1 769.2 .38 915.0 .87 100.90 915.0 2.6 869.2 .09 1015.0 .95 147.79 1015.0 1.5 969.2 .73 1115.0 1.02 156.45 1114.9 -.2 1069.2 .16 1215.0 1.05 154.22 1214.9 -1.9 1169.2 .05 1315.0 1.06 73.14 1314.9 -2.7 1269.2 1.37 1415.0 3.93 31.15 1414.8 -.2 1369.1 3.22 1515.0 6.19 17.13 1514.4 6.9 1468.7 2.56 1615.0 6.58 10.58 1613.8 16.8 1568.1 .83 1715.0' 6.72 358.06 1713.1 27.9 1667.4 1.'45 1815.0 6.83 346.94 1812.4 39.5 1766.7 1.31 1915.0 6.98 346.21 1911.7 51.6 1866.0 .17 2015.0 8.00 350.16 2010.9 64.6 1965.1 1.14 .2 338.4 .18 N .07 W .5 336.7 .49 N .21 W .9 338.3 .88 N .35 W 1.5 341.7 1.44 N .48 W 2.2 345.4 2.13 N .55 W 3.0 349.1 2.91 N .56 W 3.5 359.4 3.45 N .04 W 3.7 19.7 3.52 N 1.26 E 4.3 40.2 3.30 N 2.78 E 4.7 58.3 2.45 N 3.97 E 4.9 79.0 .93 N 4.77 E 5.6 97.3 .71 S 5.52 E 6.9 100.6 1.27 S 6.81 E 9.7 78.5 1.93 N 9.46 E 16.3 52.0 10.01 N 12.82 E 25.9 36.2 46.3 56.9 69.0 36.6 20.80 N 15.46 E 26.8 32.28 N 16.32 E 18.6 43.92 N 14.77 E 12.2 55.62 N 11.98 E 7.8 68.37 N 9.34 E A Gyrodat a Di re c t iona i Survey P. EXPLORATION ~LL: F PAD, WELL ~MPF-62, 3.5" TUBING ~cation: ATLAS, MILNE POINT, AK ~b Number: AK0696G347 Page ~ASURED I N C L AZIMUTH VERTICAL VERTICAL )EPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet [115.0 10.52 351.97 2109.5 80.6 ~2!5.0 13.30 351.74 2207.4 101.2 2315.0 15.46 350.95 2304.2 126.0 !415.0 17.48 353.17 2400.1 154.2 5515.0 19.24 356.86 2495.0 185.4 2063.8 2.54 84.6 4.7 2161.6 2.78 104.8 2.2 2258.5 2.16 129.3 .1 2354.4 2.12 157.4 358.7 2449.3 2.10 188.8 358.1 84.28 N 6.88 E 104.71 N 3.95 E 129.25 N .20 E 157.33 N 3.68 W 188.70 N 6.37 W !615.0 21.52 .21 2588.8 219.5 !715.0 23.44 2.96 2681.2 256.5 ~815.0 25.78 3.99 2772.1 296.5 2915.0 29.20 3.31 2860.8 340.7 3015.0 32.39 3.10 2946.7 389.9 2.543.0 2.56 223.6 358.2 2635.4 2.19 261.8 358.7 2726.3 2.38 303.3 359.3 2815.0 3.44 349.3 359.9 2900.9 3.19 400.4 .3 223.50 N 7.21 W 261.70 N 6.11 W 303.26 N 3.57 W 349.32 N .64 W 400.44 N 2.21 E 3115.0 34.58 3.43 3030.1 442.9 3215.0 37.18 1.74 3111.1 499.4 3315.0 39.10 1.33 3189.7 559.3 3415.0 41.63 .95 3265.9 622.1 3515.0 43.92 359.95 3339.3 688.2 36!5.0 46.43 358.14 3409.8 757.6 3715.0 48.67 357.60 3477.3 830.1 3815.0 51.26 356.33 3541.6 905.5 3915.0 53.75 356.61 3602.5 983.8 4015.0 57.04 355.47 3659.3 1065.1 2984.3 3065.3 3144.0 3220.2 3293.6 3364.1 3431.5 3495.9 3556.7 3613.5 2.20 455.6 .7 2.78 514.1 .9 1.94 575.9 1.0 2.55 640.6 1.0 2.38 708.5 .9 2.82 779.4 .8 2.27 853.1 .5 2.76 929.5 .2 2.50 1008.7 359.9 3.42 1090.8 359.6 455.52 N 5.36 E 514.06 N 7.97 E 575.80 N 9.62 E 640.55 N 10.91 E 708.46 N 11.43 E 779.36 N 10.23 E 853.10 N 7.49 E 929.54 N 3.42 E 1008.73 N 1.46 W 1090.82 N 7.16 W 4115.0 60.14 352.06 3711.4 1149.9 4215.0 63.00 349.60 3759.0 1237.6 4315.0 66.24 347.49 3801.9 1327..9 4415.0 65.46 344.62 3842.8 1419.2 4515.0 65.46 344.54 3884.3 1510.0 3665.6 3713.2 3756.1 3797.0 3838.5 4.25 1175.7 359.2 3.58 1262.8 358.6 3.76 1351.8 357.9 2.73 1441.2 357.2 .07 1530.1 356.5 1175.63 N 16.47 W 1262.43 N 30.50 W 1350.96 N 48.46 W 1439.50 N 70.44 W 1527.20 N 94.63 W A Gyrod'a t a Dire c t ional Survey .P. EXPLORATION tELL: F PAD, WELL #MPF-62, 3.5" TUBING ,ocation: ATLAS, MILNE POINT, AK 'ob Number: AK0696G347 Page [EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 4615.0 66.13 344.42 3925.3 4715.0 65.64 344.30 3966.2 4815.0 65.64 344.29 4007.4 4915.0 65.41 344.64 4048.8 5015.0 64.80 344.86 4090.9 1601.1 1692.3 1783.3 1874.2 1964.8 3879.6 3920.4 3961.6 4003.1 4045.2 .68 1619.5 355.8 · 50 1709.0 355.2 · 01 1798.6 354.6 · 40 1888.2 354.1 · 64 1977.8 353.7 1615.08 N 1702.97 N 1790.67 N 1878.36 N 1965.87 N 119.04 W 143.65 W 168.31 W 192.69 W 216.55 W 5115.0 64.93 344.87 4133.4 5215.0 64.84 344.58 4175.8 5315.0 65.52 344.32 4217.8 5415.0 65.62 343.64 4259.2 5515.0 65.42 342.80 4300.6 2055.3 2145.8 2236.4 2327.3 2418.1 4087.6 4130.1 4172.1 4213 .4 4254.9 · 13 2067.3 353.3 .28 2156.8 353.0 .73 2246.6 352.6 · 63 2336.7 352.3 .79 2426.6 352.0 2053.26 N 2140.61 N 2228.05 N 2315.56 N 2402.70 N 240.18 W 264.04 W 288.37 W 313.50 W 339.77 W 5615.0 65.00 342.70 4342.5 5715.0 64.35 342.99 4385.3 5815.0 64.28 343.26 4428.6 5915.0 63.48 343.77 4472.7 6015.0 63.83 344.21 4517.0 6115.0 63.74 344.05 4561.2 6215.0 64.00 343.98 4605.3 6315.0 64.68 343.61 4648.6 6415.0 65.39 343.31 4690.8 6515.0 65.46 342.88 4732.4 2508.6 2598.8 2688.7 2778.3 2867.8 2957.3 3047.0 3137.0 3227.4 3318.1 4296.8 4339.6 4382.9 4426.9 4471.3 4515.5 4559.5 4602.8 4645.0 4686.6 .43 2516.'3 351.6 .70 2605.6 351.3 .26 2694.9 351.0 .92 2783.9 350.8 · 53 2872.9 350.6 .17 2962.1 350.4 .27 3051.3 350.2 .76 3140.9 350.0 · 75 3231.0 349.8 · 40 3321.3 349.7 2489.40 N 2575.77 N 2662.01 N 2748.10 N 2834.24 N 2920.53 N 3006.84 N 3093.40 N 3180.30 N 3267.31 N 366.69 W 393.35 W 419.52 W 445.00 W 469.72 W 494.25 W 518.97 W 544.12 W 569.94 W 596.39 W 6615.0 65.29 342.60 4774.0 , 6715.G 65.34 342.10 4815.8 6815.0 65.05 341.83 4857.7 6915.0 64.74 341.28 4900.2 7015.0 64.89 341.58 4942.7 3408.8 3499.3 3589.7 3679.8 3769.9- 4728.3 4770.0 4812.0 4854.4 4897.0 .31 3411.6 349.5 · 46 3501.7 349.3 .38 3591.8 349.1 · 58 3681.6 348.9 · 31 3771.3 348.7 3354.12 N 3440.71 N 3527.02 N 3612.93 N 3698.71 N 623.36 W 650.91 W 679.01 W 707.67 W 736.48 W A Gyroda t a Di re c t iona I Survey .P. EXPLORATION ~LL- F PAD, WELL ~MPF-62, 3.5" TUBING Dcation: ATLAS, MILNE POINT, AK Db Number: AK0696G347 Page EASURED I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. H O R I Z O N T A'L COORDINATES feet 7115.0 64.92 341.62 4985.1 3860.0 7215.0 65.21 342.07 5027.3 3950.3 '7315.0 64.95 342.33 5069.4 4040.7 74]_5.0 64.59 342.90 5112.1 4130.8 7515.0 64.46 343.18 5155.1 4220.9 4939.4 4981.5 5023.7 5066.3 5109.3 .05 3861.2 348.6 .50 3951.3 348.4 .35 4041.4 348.3 .63 4131.4 348.2 .28 4221.4 348.0 3784.64 N 3870.80 N 3957.14 N 4043.47 N 4129.82 N 765.06 W 793.32 W 821.05 W 848.08 W 874.42 W 7615.0 65.77 343.81 5197.2 4311.4 7715.0 66.22 344.14 5237.8 4402.6 7815.0 66.32 344.57 5278.1 4494.0 7915.0 66.21 344.83 5318.3 4585.5 80].5.0 65.88 344.93 5358.9 4676.8 5151.4 5192.1 5232.3 5272.6 5313.2 1.44 4311.8 347.9 .54 4402.9 347.9 .40 4494.3 347.8 .26 4585.7 347.7 .34 4677.0 347.7 4216.79 N 4304.59 N 4392.75 N 4481.04 N 4569.27 N 900.19 W 925.41 W 950.09 W 974.25 W 998.09 W 8115.0 65.48 345.02 5400.1 4767.9 8215.0 65.44 345.19 5441.6 4858.8 8315.0 65.40 345.38 5483.2 4949.7 8415.0 65.03 345.47 5525.2 5040.4 8515.0 64.78 345.56 5567.6 5130.9 8615.0 64.56 345.35 5610.4 5221.3 8715.0 64.22 345.18 5653.6 5311.4 8815.0 63.88 344.87 5697.3 . 5401.3 8915.0 64.76 344.93 5740.7 5491.3 9015.0 64.38 344.75 5783.6 5581.6 5354.4 5395.9 5437.5 5479.4 5521.8 5564.6 5607.8 5651.6 5694.9 5737.9 .41 4768.0 347.6 .16 4858.9 347.6 .18 4949.8 347.5 .37 5040.5 347.5 .27 5131.0 347.5 .29 5221.3 347.4 .37 5311.5 347.4 .44 5401.3 347.4 .88 5491.3 347.3 .41 5581.6 347.3 4657.28 N 4745.19 N 4833.15 N 4921.01 N 5008.70 N 5096.18 N 5183.39 N 5270.26 N 5357.27 N 5444.44 N 1021.71 W 1045.10 W 1068.20 W 1091.04 W 1113.70 W 1136.40 W 1159.34 W 1182.58 W 1206.05 W 1229.67 W 9115.0 64.94 344.80 5826.4 5671.9 , 9215.0' 64.75 344.61 5868.9 5762.3 9315.0 64.68 344.62 5911.6 5852.6 9415.0 64.37 344.30 5954.6 5942.8 9515.0 63.89 344.30 5998.3 6032.7 5780.7 5823.2 5865.9 5908.9 5952.5 .56 5671.9 347.2 .25 5762.3 347.2 · 07 5852.6 347.2 .42 5942.8 347.1 · 48 6032.7 347.1 5531.64 N 5618.95 N 5706.13 N 5793.10 N 5879.72 N 1253.40 W 1277.28 W 1301.27 W 1325.46 W 1349.81 W A Gyroda t a D i re c t i ona i Survey P. EXPLORATION ILL: F PAD, WELL ~MPF-62, 3.5" TUBING ~cation: ATLAS, MILNE POINT, AK ~b Number: AK0696G347 Page ]ASURED I N C L AZIMUTH VERTICAL VERTICAL )EPTH DEPTH SECTION feet deg. deg. feet feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES. feet )615.0 63.40 344.05 6042.7 6122.1 )715.0 62.04 344.00 6088.5 6210.9 7815.0 60.58 343.90 6136.5 6298.5 )915.0 58.34 343.99 6187.3 6384.5 )015.0 56.43 344.09 6241.2 6468.6 5996.9 .54 6122.2 347.0 6042.8 1.36 6210.9 347.0 6090.8 1.46 6298.5 346.9 6141.6 2.24 6384.5 346.9 6195.5 1.91 6468.6 346.9 5965.93 N 6051.37 N 6135.67 N 6218.44 N 6299.42 N 1374.24 W 1398.70 W 1422.96 W 1446.77 W 1469.93 W )115.0 54.87 344.32 6297.6 6551.0 )215.0 52.78 344.55 6356.7 6631.6 )315.0 51.37 344.88 6418.1 6710.4 )415.0 49.23 344.99 6482.0 6787.3 )515.0 47.15 345.20 6548.7 6861.8 6251.9 1.57 6551.1 346.8 6310.9 2.10 6631.8 346.8 6372.4 1.43 6710.6 346.8 6436.3 2.14 6787.5 346.8 6502.9 2.08 6862.0 346.7 6378.86 N 6456.62 N 6532.71 N 6607.00 N 6679.02 N 1492.40 W 1514.05 W 1534.85 W 1554.84 W 1574.01 W )615.0 45.79 345.98 6617.5 6934.3 )715.0 43.85 346.43 6688.5 7004.8 )815.0 43.59 346.38 6760.7 7073.9 )915.0 43.25 346.40 6833.4 7142.6 L015.0 42.87 346.16 6906.4 7210.9 [.115.0 42.22 344.88 6980.1 7278.4 L215.0 42.19 344.08 7054.2 7345.5 !.315.0 42.15 345.22 7128.3 7412.6 k415.0 42.18 345.05 7202.4 7479.7 k515.0 41.27 344.36 7277.1 7546.2 6571.8 1.47 6934.5 346.7 6642.7 1.97 7005.0 346.7 6715.0 .26 7074.1 346.7 6787.6 .34 7142.8 346.7 6860.7 .41 7211.1 346.7 6934.4 1.08 7278.7 346.7 7008.4 .53 7345.8 346.7 7082.6 .76 7412.9 346.7 7156.7 .12 7480.0 346.6 7231.3 1.02 7546.5 346.6 6749.24 N 6817.70 N 6884.87 N 6951.67 N 7018.00 N 7083.47 N 7148.19 N 7212.93 N 7277.81 N 7342.01 N 1592.06 W 1608.88 W 1625.13 W 1641.30 W 1657.50 W 1674.41 W 1692.38 W 1710.15 W 1727.36 W 1744.91 W t615 . 0 40 . 11 344 . 24 7352 · 9 7611 . 3 , t665.0' 38.65 341.30 7391.5 7642.9 t765 . 0 38 . 07 341 . 64 7469 . 9 7704 . 7 7307.1 1.17 7611.7 346.6 7345.8 4.73 7643.3 346.6 7424.2 .61 7705.1 346.6 7404.78 N 7435.07 N 7493.92 N 1762.56 W 1771'.94 W 1791.66 W ina! Station Closure: Distance: 7705.12 ft Az: 346.55 deg. A Gyrodat a Di re c t i onal Survey for B.P. EXPLORATION WELL: F PAD, WELL #MPF-62, 3.5" TUBING Location: ATLAS, MILNE POINT, AK 'ob Number: AK0696G347SS un Date: 2-Jun-96 14:15:00 urveyor: TOM STODDARD :alculation Method: MINIMUM CURVATURE urvey Latitude: 70.505000 deg. N ub-sea Correction from Vertical Reference: 45.75 ft. .zimuth Correction: .yro: Bearings are Relative to True North 'roposed Well Direction: 347.160 deg 'ertical Section Calculated from Well Head Location ~losure Calculated from Well Head Location iorizon{al Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t iona i Survey .P. EXPLORATION ELL: F PAD, WELL #MPF-62, 3.5" TUBING ocation: ATLAS, MILNE POINT, AK ob Number: AK0696G3475S SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSIIRE DIST. AZIMUTH feet deg. -45.8 0.00 0.00 0.0 0.0 0.00 0.0 0.0 - 11750 FT. GYRO MULTISHOT SURVEY RUN INSIDE '3.5" TUBING ~LL MEASURED DEPTHS ARE REFERENCED TO ATLAS R.K.B. OF 45'8" Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .19 336.84 145.8 .3 .12 200.0 .22 336.97 245.8 .7 .04 300.0 .31 346.35 345.8 1.1 .10 400.0 .39 351.64 445.8 1.7 .10 500.0 .43 358.79 545.8 2.4 .07 600.0 .51 23.65 645.8 3.1 .24 700.0 .70 81.46 745.8 3.3 .58 800.0 .89 97.22 845.8 3.0 .29 900.0 .89 115.33 945.8 2.3 .28 1000.0 .97 150.45 1045.8 1.0 .55 1100.0 1.03 155.76 1145.8 -.7 .13 1200.0 1.05 129.22 1245.8 -2.2 .46 1300.0 1.94 60.17 1345.8 -2.0 1.94 1400.0 4.63 26.79 1445.8 2.0 3.01 1500.0 6.31 15.06 1545.8 10.0 2.02 1600.0 6.63 6.55 1645.8 20.4 1.03 1700..0 6.75 354.41 1745.8 31.7 1.41 1800.0 6.88 346.69 1845.8 43.6 .93 1900.0 7.33 347.56 1945.8 56.0 .51 2000.0 8.89 350.80 2045.8 70.3 1.64 .5 337.9 .9 337.2 1.5 339.3 2.2 342.8 3.0 346.5 3.5 352.2 3.7 5.7 4.3 26.0 4.7 45.7 4.9 64.7 5.6 84.6 6.9 98.3 9.7 93.7 16.3 70.3 25.9 47.2 36.2 33.5 46.3 24.1 56.9 16.4 69.0 10.7 84.6 6.7 .27 N .11 W .61 N .25 W 1.05 N .39 W 1.65 N .50 W 2.37 N .56 W 3.08 N .40 W 3.47 N .41 E 3.45 N 1.73 E 3.04 N 3.15 E 1.98 N 4.22 E .86 S 5.00 E .88 S 5.92 E 1.47 N 7.63 E 4.44 N 10.50 E 13 . 42 N 13 . 65 E 24.50 N 15.74 E 36.11 N 15.81 E 47.85 N 13.84 E 60.00 N 11.08 E 74.00 N 8.47 E A Gyrodata P. EXPLORATION :LL: F PAD, WELL #MPF-62, 3.5" TUBING ~cation: ATLAS, MILNE POINT, AK lb Number: AK0696G347SS Direct i o n a 1 Survey Page ~UBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG )EPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL C 00 R.D I N A T E S feet 2100.0 11.55 351.89 2145.8 2200.0 14.15 351.43 2245.8 2300.0 16.33 351.91 2345.8 2400.0 18.33 354.94 2445.8 2500.0 20.47 358.67 2545.8 88.3 111.0 138.2 169.2 203.8 .63 .53 .15 .11 .35 104.8 3.7 129.3 1.3 157.4 359.5 188.8 358.4 223.6 358.1 91.84 N 5.79 E 114.43 N 2.46 E 141.40 N 1.71 W 172.40 N 4.97 W 207.52 N 6.82 W 2600.0 22.70 1.91 2645.8 2700.0 25.10 3.70 2745.8 2800.0 28.62 3.42 2845.8 2900.0' 32.36 3.10 2945.8 3000.0 35.09 3.10 3045.8 242.3 284.9 333.2 389.4 453.9 2.33 2.32 3 .26 3.19 2.31 261.8 358.5 303.3 359.1 349.3 359.8 400.4 .3 514.1 .7 247.05 N 6.53 W 291.22 N 4.30 W 341.51 N 1.14 W 399.88 N 2.20 E 466.85 N 5.86 E 3100.0 38.03 1.56 3145.8 3200.0 40.96 1.05 3245.8 3300.0 44.15 359.79 3345.8 3400.0 47'.63 357.85 3445.8 3500.0 51.43 356.35 3545.8 525 605 694 796 910 .8 .5 .5 .2 .9 2.41 2.38 2.42 2.53 2.75 575.9 .9 640.6 1.0 779.4 .9 853.1 .6 1008.7 .2 541.27 N 8.70 E 623.40 N 10.57 E 714.92 N 11.32 E 818.63 N 8.77 E 934.92 N 3.29 W 3600.0 56.25 355.74 3645.8 3700.0 62.21 350.29 3745.8 3800.0 65.46 344.61 3845.8 3900.0 65.89 344.36 3945.8 4000.0 65.43 344.61 4045.8 1045 1213 1425 1646 1867 .8 .2 .7 .8 .5 .20 .77 .54 .59 .37 1090.8 359.7 1262.8 358.8 1530.1 357.1 1709.0 355.5 1888.2 354.2 1071.28 N 1238.28 N 1445.80 N 1659.06 N 1871.85 N 5.8O W 26.59 W 72.18 W 131.35 W 190.88 W 4100.0 64.90 344.78 4145.8 4200.0' 65.59 343.86 4245.8 4300.0 64.95 342.73 4345.8 4400.0 63.97 343.46 4445.8 4500.0 63.77 344.11 4545.8 2081.6 2297.8 2515.4 2723.5 2926.0 .17 .66 .45 .51 .29 2156.8 353.2 2336.7 352.4 2605.6 351.6 2783.9 351.0 2962.1 350.5 2078.69 N 2287.16 N 2495.90 N 2695.46 N 2890.31 N 247.13 W 305.34 W 368.70 W 429.42 W 485.65 W A Gyroda t a D i re c t i ona I Survey .P. EXPLORATION ELL: F PAD, WELL #MPF-62, 3.5" TUBING ,ocation: ATLAS, MILNE POINT, AK 'ob Number: AK0696G347SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4600 . 0 64 . 64 343 . 64 4645 . 8 4700 . 0 65 . 41 342 . 79 4745 . 8 4800 . 0 65 . 14 341 . 90 4845 . 8 4900 . 0 64 . 89 341.59 4945 . 8 5000 . 0 65 . 09 342 . 18 5045 . 8 3131.1 3347.3 3563.9 3776.3 3989.9 .73 .37 .40 .29 .43 3140.9 350.0 3411.6 349.6 3591.8 349.2 3861.2 348.7 4041.4 348.4 3087.77 N 3295.21 N 3502.35 N 3704.86 N 3908.61 N 542.49 W 605.06 W 670.98 W 738.52 W 805.47 W 5100.0 64.49 343.12 5145.8 5200.0 66.24 344.23 5245.8 5300.0 65.99 344.90 5345.8 5400.0 65.44 345.21 5445.8 5500.0 64.91 345.51 5545.8 4201.3 4420.6 4647.2 4867.8 5084.4 .36 .51 .31 .16 .32 4221.4 348.1 4494.3, 347.9 4677.0 347.7 4949.8 347.6 5131.0 347.5 4111.09 N 4321.93 N 4540.62 N 4753.87 N 4963.59 N 868.71 W 930.26 W 990.35 W 1047.38 W 1102.04 W 5600.0 64.28 345.21 5645.8 5700.0 64.71 344.91 5745.8 5800.0 64.85 344.71 5845.8 5900.0 64.43 344.37 5945.8 6000.0 63.31 344.05 6045.8 6100.0 60.18 343.92 6145.8 6200.0 56.31 344.11 6245.8 6300.0 53.17 344.51 6345.8 6400.0 50.44 344.93 6445.8 6500.0 47.24 345.19 6545.8 5295.1 5502.0 5713.0 5924.1 6128.1 6314.1 6475.2 6616.7 6743.7 6858.5 .35 .82 .42 .35 .59 1.60 1.88 2.00 1.74 2.09 5311.5 347.4 5581.6 347.3 5762.3 347.2 5942.8 347.1 6210.9 347.0 6384.5 346.9 6551.1 346.9 6631.8 346.8 6787.5 346.8 6862.0 346.7 5167.61 N 5367.61 N 5571.37 N 5775.11 N 5971.64 N 6150.70 N 6305.79 N 6442.24 N 6564.84 N 6675.87 N 1155.19 W 1208.85 W 1264.27 W 1320.46 W 1375.88 W 1427.28 W 1471.73 W 1510.05 W 1543.49 W 1573.17 W 6600.0 45.02 346.16 6645.8 6700.[0 43.64 346.39 6745.8 6800.0 43.18 346.35 6845.8 6900.0 42.52 345.47 6945.8 7000.0 42.20 344.18 7045.8 6962.3 7059.5 7154.2 7246.9 7337.9 1.67 .62 .35 .77 .60 7005.0 346.7 7074.1 346.7 7211.1 346.7 7278.7 346.7 7345.8 346.7 6776.47 N 6870.94 N 6962.91 N 7052.93 N 7140.82 N 1598.75 W 1621.76 W 1644.05 W 1666.52 W 1690.33 W A Gyroda t a D i re c t iona I Survey P. EXPLORATION iLL- F PAD, WELL ~MPF-62, 3.5" TUBING ~cation: ATLAS, MILNE POINT, AK ~b Number: AK0696G347SS Page ~UBSEA I N C L AZIMUTH VERTICAL )EPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE . SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7100.0 42.16 345.18 7145.8 7200 . 0 41 . 65 344 . 65 7245 . 8 7300 . 0 40 . 22 344 . 25 7345 . 8 7400 . 0 38 . 25 341 . 54 7445 . 8 7424 . 2 38 . 07 341 . 64 7469 . 9 7428.4 .61 7480.0 346.7 7518.3 .64 7546.5 346.6 7605.2 1.15 7611.7 346.6 7685.6 1.88 7705.1 346.6 7704.7 .61 7705.1 346.6 7228.21 N 7315.08 N 7398.88 N 7475.77 N 7493.92 N 1714.20 W 1737.55 W 1760.90 W 1785.58 W 1791.66 W [nal Station Closure: Distance: 7705.12 ft Az: 346.55 deg. ,g, yro/data .4. QUALITY CONTROL SR347,DOC gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0696G347 TOOL NUMBER: 746 MAXIMUM GYRO TEMPERATURE: MAXIMUM AMBIENT TEMPERATURE: 76.57 C 60.3 C MAXIMUM INCLINATION: 66.55 AVERAGE AZIMUTH: 346.55 WIRELINE REZERO VALUE: 15 REZERO ERROR / K: 1.27 CALIBRATION USED FOR FIELD SURVEY: 1482 CALIBRATION USED FOR FINAL SURVEY: 1482 PRE JOB MASS BALANCE OFFSET CHECK: -.2 POST JOB MASS BALANCE OFFSET CHECK~ : CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: -.3 USED -.3 OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 11765 38.07 341.64 7469.9 7493.9N 1791.7W FINAL SURVEY 11765 38.07 341.64 7469.9 7493.92N 1791.66W SR347.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0696G347 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D.~ 1 2 3 4 5 11700 38.82 38.82 38.82 38.82 38.82 AZIMUTH M.D. ft 1 2 3 4 5 11700 341.32 341.48 341.68 341.27 341.79 SR347.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR347.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0696G347 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 746 GYRO SECTION A0119 DATA SECTION C0073 POWER SECTION C0065 BACKUP TOOL No. 706 GYRO SECTION A0004 DATA SECTION C0035 POWER SECTION C0033 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0222 A0085 A0079 A0035 A0246 A0107 A0029 A0071 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 7/32" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 15 FEET 2.5 INCHES TOTAL WEIGHT OF TOOL. 100 POUNDS SR347.DOC gyro/data CHRONOLOGICAL REPORT _JOB NUMBER: AK0696G347 05/31/96 06/01/96 STANDBY STANDBY O6/O2/96 08:00 13:00 13:15 14:00 14:15 ' 16:40 20:00 23:00 TO MILNE POINT TO LOCATION (F PAD) ARRIVED AT LOCATION MAKE UP TOOL R.I.H.-INRUN SURVEY (CONTINUOUS COMMENCE OUTRUN LAY DOWN TOOL PROCESS SURVEY AT MILNE POINTE CAMP 06/03/96 08:00 13:00 RETURN TO ATLAS TO ANCHORAGE SR347.DOC [::1 Ft I I...I-- I I~1 G WELL LOG TRANSMITTAL To: State of Alaska May 15, 1996 Alaska Oil and Gas Conservation Comm. Atm.: Records Keeper 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-62I AK-MM-951055 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 ,MPF-62I: 1 LDWG formatted LIS tape with verification listing. APIg: 50-029-22609-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company D I=t I I_1_ I I~1 (3 SEFIuIr'Es WELL LOG TRANSMITTAL To'. State of Alaska Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Dr. Anchorage, Alaska 99501 ~_~,, ~-- p ? / MWD Formation Evaluation Logs - MP F-62I, AK-MM-951055 February 27, 1996 The technical data listed below is being submitted herewith.. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs: 2"x 5" MD Neutron and Density Logs: 2" x 5" TVD Neutron and Density Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION · I LDWG TAPE+LIS 1 LDWG TAPE+LIS Date: 4 December 1995 RE: Transmittal of Data Sent by: HAND CARRY c 'Run # 1 6516.00 Run # 1 6517.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 63-7803 o Received~ Date: RECEIVED 9EC 1 4 1995 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. .Date: 12 November 1995 Transmittal of Data Sent by: US MAIL Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION I PFC/PERF FINAL BL&RF 1 PFC/PERF FINAL BL&RF 1 PFC/PERF FINAL BL&RF 1 SBT FINAL BL & RF ! PLS FINAI. BL & RF 1 PLS FINAL BL & RF ECC No. Run ~ 1 6511.01 Run # 1 6512.01 Run ~ 1 6516.00 Run # 1 Run # 1 6517.00 Run # 1 6518.00 Please sign and return to: Attn. Rodney D. Paulson " Atlas Wireline Services ~' %,,,,~. 5600 B Street Suite 201 ~ Anchorage, AK 99518 ~~.-- Received by//,"2,,z,"//,F'l,,~,&~' Date: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~ DATE- Chairmar~,~-~; THRU' FILE NO: Blair Wondzell, ~J2~~ P. !. Supervisor ¢~/5;4~- FROM- Bobby Foste~~'-¥ SUBJECT: Petroleum Inspector October 30, 1995 AWQIJ5CD.doc BOPE Test - Nabors 27E BPX - MPU - MP F-62 PTD # 95-0161 Milne Point Field Monday, October 30, 1995: I received a call from Rod Klepzig, Nabors Toolpusher, at 10:30 PM informing me that the rig would be ready to test BOPE's at approximately 1:00 AM - 10/31/95. Tuesday, October 31, !99.5: ! arrived at the rig at 00:30 AM and met with Tom Anglen, BPX rig foreman, and he said the crew would be ready in an hour +. I went to the rig floor at 2:45 AM and the crew was pressureing up on the BOPE. A leak was found at a Uniboit in the choke line. This was tightened and finally tested OK. The rig was clean and all equipment seemed to be in good working order. The location is quite crowded but therwas good access to all areas of the rig. Houston Contracting Co. is installing modules and tying in flow lines on this pad. Summary: I witnessed the BOPE test on Nabors rig 27E drilling MP F-62 at BPX's MPU. Test time 3 hours - 1 failure - Repaired. Attachment: AWQI5CD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: NABORS Rig No. 27E PTD# 95-0161 BPX Rep.: MPF-62 Rig Rep.: Set @ 6059' Location: Sec. Weekly Other DATE: 10/31/95 Rig Ph.# 659-4373 TOM ANGLEN RODNEY KLEPZIG 8 T. 13N R. IOE Meridian Um. Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 2 500/5, 000 P 1 500/5, 000 P 1 500/5, 000 P P 1 500/5, 000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 Test Press. 300/3, 000 'i 500/5, 000 I 500/5, 000 1 5oo/5,000 1 500/5, 000 2 500/5, 000 1 5OO/5, 000 N/A P/F P P MUD SYSTEM- Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES ,, CHOKE MANIFOLD: No. Valves 15 No. Flanges 42 Manual Chokes 2 Hydraulic Chokes Test Pressure 500/5, 000 500/5, 000 Functioned Functioned P/F P P , ,,, P P , ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained '/ Blind Switch Covers: Master: 3, I00 J P 1,600 P minutes 21 sec. , , minutes 41 sec. YES Remote: YES Nitgn. Btl's: 6 @ 2500Avg. Psig. Number of Failures: f'/ ,Test Time: 3.0 Hours. Number of valves tested 24 Repair or Replacement of Failed , Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 tf your call is not returned by the inspector within 12 hours please contact the P. 4. Supervisor at 279-1433 REMARKS: Failure: A Unibolt ring gasket leaked on the choke line - tightened and retested OK. Distribution: orig-Welt File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AWQIJ5CD~(I.S BOBBY D. FOSTER h a. r ;ed e !ces ............ r,.i I !. m n g TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPF-62i Modification for surface casing setting point APl # 50-029-22609 Blair; After a review of the well completion plans for the above mentioned well, we desire to set our 9-5/8" surface casing below the Schrader Bluff Sands. This will facilitate using the drilling rig to complete this well, and therefore allow bringing this pad on production. The 9-5/8" casing setting depth will go from 4592 MD ( 3913 TVD) to 6050 MD ( 4529 TVD). We also will increase the volume of lead cement for this deeper setting point from 896 sx to 1160 sx. The cement properties will not change. This deeper point had been the normal casing setting depth for Milne Point, however the shorter departure of MPF-62i allowed the shallow setting as in done in other Milne Point areas. Allowing the deeper setting will change the interval for annular injection from the Prince Creek to the Seabee intervals which also has been the accepted formation for wells drilled at MP F pad. Approval of this modification will allow us to complete this well in a more timely manner and will be greatly appreciated. Chris West Drilling Operations Engineer Nabors 27E 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 X Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5, Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 4. Location of well at surface 2141' NSL, 2627' WEL, SEC 06, T13N, RIOE 6. Datum elevation (DF or KB) Plan RTE = 45 feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPF-62 At top of productive interval 9. 4125' NSL, 4242' WEL, SEC 31, T14N, RIOE At effective depth 10. At total depth 4394' NSL, 4314' WEL, SEC 31, T14N, RIOE Permit number 95-161 APl number 50- 029-22609 11. Field/Pool Mi/ne Point Unit / Kuparuk Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth OCT 2 '/ i995 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation October26, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended__ 17. I hereby certify that the foregoir~g is true and correct to the best of my knowledge. Signed ~ ~i~l ¢' , Title Senior Drilling Engineer // FOR COMMISSION USE ONLY Conditions of approval: Notify ComMission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ (~~~ ~'1~luired lO- David W. Johnston Approved by order of the Commission Date · .&pproveaj A~ppr°val N°'~'~/~''~'~'~~,upy - _ Returned,, Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 13, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-62 BP Exploration (Alaska), Inc. Permit No 95-161 Surf Loc. 2141'NSL, 2627'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc. 4394'NSL, 4314'WEL, Sec. 31, T14N, R10E, UM Dear Mr. Schofield: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. David W. J~hnston Chairman ~ BY ORDER OF THE COMMISSION /enci c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryr-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 45 feet Milne Point/Kuparuk River 3. Address 6. Property Designation P. O. Box 196612. Anchorage. Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2141' NSL, 2627' WEL, SEC 06, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 4125' NSL, 4242' WEL, SEC 31, T14N, RIOE MPF-62 2S100302630-277 At total depth 9. Approximate spud date Amount 4394' NSL, 4314' WEL, SEC 31, T14N, RIOE 10/17/95 $200,000.00 12. Distance to nearest !13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 355017 4314 feet No Close Approach feetl 5083 11807 MD / 7521' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~25o feet Maximum hole angle 65 o Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 4561' 31' 31' 4592' 3913' 896 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 11774' 30' 30' 11804' 7519' 254 Class 'G', 238 Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 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 !; ~ · ~ Surface '~ ~ ,,L. J . ~ Intermediate Production OCT 'iz i995 Liner Perforation depth: measured Alas~.0JJ& Gas 00ns. C0~n]issior~ true vertical ' ~,nch0rage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify~hat ~f. gr~oi?j1~ue and correct to the best of my knowledge FZ'/q Signed -'/~:~ __-'"'~¢'.~"~ Title Senior Drilling Engineer Date J £. ' // Commission Use Only Permit Number IAPi~number _ IApproval date See cover letter ~,~._/x~'/ J50-~::~_~- Z-.~-~'4:::) ~ J lC)' I~. c~-' for other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE [] 2M; [-I3M; J~JSM; E]10M; []15M; Other: Original Signed By. by order of Approved by David W. Johnston Commissioner tne commission Date/~/~'-' Form 10-401 Rev. 12-1-85 Submit in t~ plicate I Well Name: l MPF-62i I Well Plan Summary [Type of Well (producer or injector): I Kuparuk Injector I Surface Location: 2141' FSL 2627' FEL Sec 06 T13N R10E UM., AK. Target Location: 4125' FSL 4242' FEL Sec 31 T14N R10E UM., AK. Bottom Hole 4394' FSL 4314' FEL Sec 31 T14N R10E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: 1330201 I I Rig: I Nabors 27E I IEstimated Start Date: Oct 17, 1995 IuD: I 11807' I I TVD: 17521'BKB I IKBE: I46. I IWell Design (conventional, slimhole, I Ultra Slimhole, 7" Longstring etc.): Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1794 1794' n/a NA (Top Schrader) 4738' 3974' 1653 psig / 8.0 ppg OA ' 4194' 1744 psig / 8.0 ppg Base Schrader Bluff 5850' 4444' 1848 psig / 8.0 ppg Top HRZ 10939' 6788' n/a Base HRZ ' 6847' n/a Kupark D Shale 11137' 7007' n/a Kuparuk C ' 7156' 3598 psig / 9.6 ppg Target KUP A3 11374' 7189' 3616 psig / 9.6 ppg Total Depth 11807' 7521' n/a Casing/Tubing Program: Hole '~ Csg/ -Wt/Ft- Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NTSOLHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 4561' 31/31 4592/3913 8 1/2" 7" 26# L-80 btrc 11774' 30/30 11804/7519 N/A (tbg) 3-1/2" 9.3# L-80 EUE 11246' 29/29 11275/7130 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. Logging Prol ~en Hole Logs: Surface Intermediate Final ICased Hole Logs: ,ram '. LWD GR/Resistivity None LWD OR/Resistivity/Neutron/Density None OCT '! / !99~ AlaSka 0il & 6as Cons. Co Anchorage missio~ A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. API# 50- October 11, 1995 onsiderations ~ud. Special attentio' '~n to gravel and coal in -[ the .su ,rface.hol_e: with appropriate viscosity and weight to con, tr, olea.ch. The use of frequent short trips as per the updated] ~pad data sheet are encouraged. roperties: : 1-~ ensity P2~ ensity to Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: Maximum Hole Angle: 'Maximum Dog Leg: inclination in target: Close Approach Well: 65 degrees < 4 degrees 40 Degrees No - See Traveling Cylinder report There are no close approach wells for drilling MPF-62i. There are other well in the area but do not enter a close approach condition . The well path should be followed as close as possible to ensure we do not compromise the proximity toleranxces. · , ~aska Oil & Gas Cons. Cornmissior~ Anchorage API# 50- October 11, 1995 Disposal: Cuttings Handling: pit can be opened Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request 1. 2. to AOGCC for Annular Pumping Approval for MPF-62i: Approval is requested for Annular Pumping into the MPF-62i, 9-5/8" x 7" casing annulus. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 4592' md (3900' tvd) which is above the Schrader Bluff Sands and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 12.0 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2601 psi for a 10.4 ppg fluid in this well. MASP -- 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permiability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (aBE) VOL (aBE) Milne Point F-1 0 35,000 1/1/95 - 12/31/95 Milne Point F-13 684 35,000 1/1/95 - 12/31/95 Milne Point F-25 230 35,000 1/1/95 - 12/31/95 Milne Point F-37 0 35,000 1/1/95 - 12/31/95 Milne Point F-45 0 35,000 1/1/95 - 12/31/95 Milne Point F-53 0 35,000 1/1/95 - 12/31/95 Milne Point F-61 0 35,000 1/1/95 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. OCT i8 $ Gas Cons. Commission Anchorage API# 50- October 11, 1995 DRILLING HAZARDS AND RISKS: See both the updated Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the BHA, rather than formation drilling problems. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F- pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells F-69, F-61, AND F-53 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.2 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3594 psi @ 7200' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. WATER USAGE Have the water truck drivers track the water usage on a daily Icg. Send a copy of this Icg to Dennise Casey in the Anchorage Office on a monthly basis. ,, ,-¢ ,. "c~!~ ~,,~as,k~ ul~ & Gas Cons. Commis¢or~ Anchorage AP1 # 50- October 11, 1995 MP F-62i Proposed Summary of Operations I o Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. . Drill a 12-1/4" surface hole to 4592' md (3913' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. 8. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. . RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. 10. Drill 8-1/2" hole to TD at 11804' MD (7519' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). 11. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. 12. ND BOPE and NU dry hole tree. Release rig to MPF-38i. Note: This well will be perforated, cleaned out with a completion rig and prior to running the injection completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine / Freeze protection in the wellbore. 13. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. 14. PU and RIH with 3-1/2" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. 15. RIH with injection packer completion on 3-1/2" EUE 8rd tubing. 16. 17. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. ¥~ ~ OCT '~ '~ ~995 Ataska Oft & Gas Cons, Commission Anchorage POST RIG WORK , Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. , A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. o An adequate volume to cover 2000' of diesel needs to be injected down the 7"X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. , The rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. API# 50- October 11, 1995 MPF-62 Cement Calculator Milne Point Cement and Centralizer Calculations Well MPF-62i, Surface (1 Stage) Cement Job cement TypeI E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF O.O558 BPF + 30% 0.0725 BPF + 100% 0.1116 ........... ~.~..p.,,..!~ BBLS Cu. Ft. Sacks Top of Cement Shoe Depth i!!i!i~!~ii~!i~i! Calculated G Tail Volume 623 51.2 288 250 3969 E Lead Volume 1500 167.3 940 433 2469 E Tail Volume 2469 179.0 1005 463 0 Total E 8 96 Total G 2 5 0 9-5/8" Bows I 0 r Production 2-Stage Cement Job Cement yeild Hole Size 8.5 G ST1 Slurry 1.15 Casing Size 7 G ST2 Slurry 1.15 BPF O.O226 BPF + 30% 0.0294 Stage 1 BBLS Cu. Ft. Sacks Formation Top i! ~?i!!iii?i;iii,li~iiiiii!~i~ii~ 52 292 254 I Centralizers 4 6 Turbulators Stage 2 N A Top ~iiii~ii'iii! :ii!:i~iiii'iii~i~::::~:!~ i 4 9 2 7 4 2 3 8 i Centralizers 3 4 ! Total G ST1 2 5 4 I Total G ST2 238 Total ST Blade,' 3 5 I uti ~ Gas Cons. Commission Anchorage Page 1 MPF-62i WELL 9-5/8" Shallow Set SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES- Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS' 896 TmCK~N~NO Tm~: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaC12 WEIGHT: 15.8 ppg Premium G YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX #SACKS: 250 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 · oe xw : Permafrost E ADDITIVES' Retarder WEIGHT: 12.0 ppg APPROX NO SACKS' 250 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing required). 2. Place all centralizers in middle of joints using stop collars. (15 OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 250 sacks. API# 50- October 11, 1995 RECOMMENDED PRACTICES FOR PRODUCTION HOLE - Long string Refer to the Recommended Practices Manual for Shared Services Drilling. Special Notes: IHR: In Hole Reference is required after setting and cementing the 9- 5/8" casing· This can be done during the nipple up of the BOP stack. Casing: Dope Pin Ends only when running production Casing. The ES cementer should be placed 50 feet below the base of the Schrader Bluffs Cementing: 1.0 Perform Two Stage Cement Job as follows: a · c· · e o h · j. k. l · Pump 10 bbls of fresh water to clear the Cement Lines. Safety Reminder: Have all personnel vacate the Rig Floor and all areas of High Pressure Lines when pressure testing. Test Cement Lines to 3500 psig. Bleed Pressure off all lines and Load the Bypass Cement Plug (Bottom Plug). Pump Bottom Plug out of Head with 10 bbls of fresh water. Shut down and load Shut-Off Plug. Pump 70 bbls Alpha Spacer weighted 1 ppg above the mud weight as listed on the cement page of the Well Plan. Pump Cement as per Cementing Page. Drop top plug-- verify that the positive indicator shows plug leaving the cement head. Switch to rig pumps and Displace cement with 300 bbls source water followed by 200 bbls of mud at 6-8 bpm once plug catches cement. As the plug approaches the landing collar (within 5 bbls), slow down to 3 bpm. Pump until the plug is bumped -- adjust rate to not exceed 2500 psig. Release pressure slowly and check floats-- If the floats do not hold, hold 1500 psig on casing for minimum of 4 hours and recheck floats. 2.0 After successfully checking floats, bleed off all pressure and load the closing plug for the ES Cementer -- before shearing ES tool open. Pressure up and shear the ES Cementer open with +/-2800 psig pressure. If the ES Cementer does not hydraulically open, there is an opening bomb available with the tool -- at high hole angles, it may be necessary to push the bomb down with drill pipe. 3.0 Circulate a minimum of two annular volumes. Perform Stage 2 of the production cement job as per the cementing program. Drop the ES Cementer closing plug and displace the plug to the ES Cementer with 85 bbls of diesel followed by source water at 6 to 8 BPM. Pressure up and shear the ES Cementer closed. Bleed off the pressure and confirm that the ES Cementer closed. 4.0 Immediately after checking floats, drain and flush the stack with water via annulus valve. Back out the 7" landing joint and rig down the cementers and casing crew equipment. OCT 'i Oi a Gas Oons. Oommission Anchorage API# 50- October 11, 1995 MPF-62i 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 254 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60° F BHST 80 deg F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg current mud weight. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS' 238 THICKENING TIME: 4 hours @ 50 FLUID LOSS' 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casi: total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6550' - 5700' to cover the S Bluffs Sands (35 Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 81. OTHER CONSIDERATIONS: compatibility prior to pumping job. requirement. Displace at 8-10 bpm. Perform lab tests on mixed cement/spacer/mud program and Ensure thickening times are adequate relative to pumpU Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 1000' above the NA Top with 30% excess. OCT '!'z i99 APl # 50- Alaska Oit & Gas Cons. Commission Anchorage October 11, 1995 BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt · MPF MPF-62 MPF-62 Wp2 VERTICAL VIEW SCAL~ 500 ft. / DIVISION VERTICAL SECTION REF: WELL.AD 0.00' e 0 ~DTIE IN 500 1o0o t500 1550 -- i716 i795 -- t915 -- 2000 3000 3316 3500 3828 39[3 4195 4335 4445 4500 687 0.00' E i250 MD KOP / START DF BUILD E i. OO'/lO0 Ft 3.00' ~ t550 MD START DF BUILD 8 1.50'/100 Ft 5.50' E 1717MD END DF BUILD 5.50' ~ i796ND B. PermmFrost 5.50' E t917HD START DFCURVE~ 2.50'/k00 Ft i0. SO' E 2[17 MD [5.58' 8 23[7 MD 20.50' 8 2§i7 MD 25.50' ~ 27L7 ND 30.50' ~ 2917 MD 35.50' ~ 3[[7 ND 40.50' e 33~7 ~ 45.00' ~ 3497 MD START OF CURVE ~ 8.50'/I00 Ft 49.35' 8 3697 ND 53.78' ~ 3897 ND OF CURVE 4t2 MD, 39L3 TVD 65.00' E 473l HD NA Sands 1786 2t98 65.00' E 5259 MD DA Smn~s 2500 65.00' E 5592 MD 2734 65.00' E 5050 MD B. Schrm~er 5000 CRITICAL POINT DATA MD [nc Azl. TVD N/S E/W TIE IN O O. OO' O. OO' 0 0 N 0 E KDP / START 1250 0.00' 0.00' 1850 0 N 0 E OF BUILD E t,O0'/tO0 Ft START DF BUILD 1550 3.00' 0.00' 1550 B N 0 E ~ 1.50'/tO0 END OF BUILD START DF CURVE e 2.50'/100 Ft START DF CURVE e 2.50'/100 Ft END DF CURVE NA S~nd$ B. Schrader START DF CURVE E 2. O0'/tO0 Ft END DF CURVE THRZ BHRZ TKUD T~rge~ 9128/95 / TKUA3 TMLV t717 5.50' 0.00' 1716 20 N 0E 1796 5.50' 0.00' 1795 88 N 0E 19t7 5.50' 0.00' 1915 39 N 0E 3497 45.00' 358.00' 3316 700 N 20 W 4398 65.00' 345.58' 3828 L4IBN L34 459865.00' 348.88' 3913 1594N 179 459265,00' 345.58' 3913 1594N 179 473865.00' 345.58' 3975 1728N 212 525965.00' 345.58' 4195 8179N 389 559865.00' 345.58' 4335 2471N 405 559865.00' 345.58' 4336 2472N 405 585065.00' 345.58' 4445 2698N 463 959065.00' 345.58' 6025 5981N 1307 10840 40.00' 345.00' 6780 6933 N 1556 iOBSO 40.00' 345.00' 6788 6939 N 1558 t0928 40.00' 345.00' 6848 6987 N 1571 11137 40.00' 345.00' 7008 7ll7 N t605 11375 40.00' 345.00' 7190 7265 N L645 t1504 40.00' 345.00' 7289 7345 N t666 W T~rget Nmme TVD NS EW Grl~ X Grin Y m T~rget 9/28/95 7190 7265 N 1645 W 540250 6042848 CASING POINT DATA OD MD [nc Azl TVD N/S E/V 9 5/B In 4592 65,00' 345,58' 39t3 15~4 N t79 W 7 In tlB04 40.00' 343.00' 7519 7331N 1716 W OCT i .... Alaska Oil & G~s Cons. Commissio~ Anchorage 5500 60OO 6025 6503 6783 ~. 7000 7008~' 7190 7289 BO00 -500 6188 7296 7784 65.00' E 9590 MD START DF CURVE E 2.00'/100 F± 59,00' E 9890 MD 53.00' ~ tOtDO MD 49,00' E 10390 MD 45.00' e tosgo MD E 10840 MD END OF CURVE 40.00' E 10850 MD THRZ 40.00' E t0928 ND BHRZ 40.00' E tt137 HD TKUD 40.00' E [1375 ND T~Oe~ 9/28/95 / TKUA3 40.00' E t1504 ND TH~V 40,00' ~ t[804 ND 7 In DO, E ttB04 ND, 7519 TVD HORIZONTAL VIEW (TRUE NORTH) SCALE 500 ft./ DIVISION SURVEY REF: W~LLHEAD oOB' 3~5'~T .3&5 B&B 3A5.~0'. I 65~b 3~5.3~, ~ 3~5.58' AAA5 · - 3&5.58 ~ - 3A5.58 ~ ~ ~- 3~5'5~' g~ _ _ 3A5.58' ~B~ 3~7. B~' 3634 __ 350.3~' 35i6 - ~ 3386 - 356.~5' ~ 3859 - 358. ~ 3t06 - 358.06' ~944 - ~ 8688 - 358.83' .5 ~308 - 358.56' ...... 0 5gO tOOO 1500 2000 2500 3OD0 3500 4000 4500 5000 5500 6000 6500 7000 7500 BO00 tO/It/95 9, 17 h.~:':_l BJRT2N VERTICAL SI~CTION PLA.N~: 34,7,10' ---5500 ---5000 ---4500 ---4000 ---3500 --3000 ---~500 --HO00 --1500 --tO00 500 tODD [593 PROPOSED BHL TVD 7518.51 liD 11804.04 vs N/S 7531.12 E/W 1716.34 D~:e P~otte~ , .}0/It { Checkec~ By' A;:>~,-,ove,~ By Ig~te AB Pa>t~a~o /~t Pa~oa ~0 pa~-1-o~ a:~(I No±~nEIqgWH KOISIAIO / '~ C~ 3WOS 't7 c3 UQ7 6U!ll!~Q 89-ilH :aUeld a%e%S 'o>-is'o1¥ SaD!A aSS pa aeqS-Xd$ Survey Reference: WELLHEAD Refexence World Coordinates: Lat. 70.30.29 N - Long. 149.39.25 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6035593.31 N 541934.94 E North Aligned To: TRUE NORTH Vecdcal Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD BPX-Shared Services Drilling Alaska State Plane: ZoneA Milne Pt: MPF MPF-62 MPF-62 Wp2 Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2. I.B Vertical Section Plane: 347.16 deg. Alaska 0it & Gas ~,~ns. Commission Anchorage Page I Date: 10/11/95 Time: 9:43 am Wellpath ID: MPF-62 Wp2 Last Revisioa: I0/11/95 Measured Incl Drift Subsea TVD Depth Dir. Depth (ft) (deg.) (deg.) (ft) (ft) TIE IN 0.00 0.00 0.00 44.70 0.00 KOP / START OF BUILD @ 1.00 deg/100 ft ! 250.00 0.00 0.00 1205.30 1250.00 1350.00 1.00 0.00 1305.29 ! 349.99 1450.00 2.00 0.00 1405.26 1449.96 START OF BUILD @ ! .50 deg/100 ft 1550.00 3.00 0.00 1505.16 1549.86 1650.00 4.50 0.00 1604.95 1649.65 END OF BUILD 1716.67 5.50 0.00 1671.36 1716.06 B. Permafrost 1795.67 5.50 0.00 1750.00 1794.70 STARTOF CURVE@2.50deg/100R 1916.67 5.50 0.00 1870.44 1915.14 Course (ft) 1250.00 100.00 100.00 100.00 100.00 66.67 '79.01 120.99 2016.67 8.00 359.30 1969.74 2014.44 100.00 2116.67 10.50 358.94 2068.43 2113.13 100.00 2216.67 13.00 358.71 2166.33 2211.03 100.00 2316.67 15.50 358.56 2263.24 2307.94 100.00 2416.67 18.00 358.44 2358.99 2403.69 100.00 2516.67 20.50 358.36 2453.40 2498.10 100.00 2616.67 23.00 358.29 2546.27 2590.97 100.00 2716.67 25.50 358.23 2637.44 2682.14 100.00 2816.67 28.00 358.19 2726.74 2771.44 100.00 T O T A L GRID Co<~dinates Rectangular Offsets Northing Easting (ft) (ft) (ft) (ft) 0.00N 0.00E 6035593.31 541934.94 0.00N 0.00E 6035593.31 541934.94 0.87N 0.00E 6035594.19 541934.94 3.49N 0.00E 6035596.80 541934.92 7.85N 0.00E 6035601.16 541934.90 14.39N 0.00E 6035607.70 541934.86 20.20N 0.00E 6035613.51 541934.83 27.77N 0.00E 6035621.09 541934.79 39.37N 0.00E 6035632.68 541934.72 51.12N O.O~N 6035644.43 541934.57 67.19N 0.34W 6035660.49 541934.23 87.55N 0.7C6/ 6035680.84 541933.69 112.15N 1.3~ 6035705.44 541932.96 140.95N 2.11W 6035734.24 541932.04 173.90N 3.02W 6035767.18 541930.93 210.93N 4.11W 6035804.20 541929.64 251.98N 5.3Ohr 6035845.23 541928.16 296.95N 6.77W 6035890.20 541926.50 Closure Vertical Build Dist. Dir. Section Rate (fi) (deg.) (ft) (dg/100ft) Walk DLS Cunt Rate Dogleg (dg/10Oft) (dg/100ft) (deg) 0.00@ 0.00 0.00 0.00 0.00 0.00 0.00@ 0.00 0.00 0.00 0.00 0.00 0.87@ 0.00 0.85 1.00 0.00 1.00 3.49@ 0.00 3.40 1.00 0.00 1.00 7.85@ 0.00 7.66 1.00 0.00 1.00 14.39@ 0.00 14.03 1.50 0.00 1.50 20.20@ 0.t30 19.70 1.50 0.00 1.50 27.77@ 0.00 27.08 0.00 0.00 0.00 39.37@ 0.00 38.39 0.00 0.00 0.00 51.12@359.91 49.86 2.50 -0.70 2.50 67.19@359.71 65.59 2.50 -0.37 2.50 87.55@359.50 85.53 2.50 -0.23 2.50 112.16@359.31 109.64 2.50 -0.15 2.50 140.97@359.14 137.89 2.50 -0.11 2.50 173.93@359.00 170.22 2.50 -0.09 2.50 210.97@358.88 206.57 2.50 252.03@358.78 246.87 2.50 297.03@358.69 291.03 2.50 -0.07 2.50 -0.06 2.50 -0.05 2.50 Expected Total Max Hot Min Hot Dh'. Veal Rectangular Coords Error Error Max Err Error (ft) (ft) (ft) (ft) (deg.) (ft) 0.0 0.00N 0.00 E 0.00 0.00 0.00 0.0 0.00N 0.00 E 3.74 3.74 0.00 1.0 0.87 N 0.00 E 3.96 3.96 90.00 2.0 3.49N 0.00E 4.19 4.19 90.00 3.0 7.85 N 0.00 E 4.43 4.42 90.00 4.5 14.39 N 0.00 E 4.70 4.65 90.00 5.5 20.20N 0.00 E 4.89 4.80 90.00 5.5 27.77N 0.00 E 5.13 4.99 90.00 5.5 39.37 N 0.130 E 5.51 '5.29 90.00 8.0 51.12N 0.09N 5.89 5.52 89.77 10.5 67.19 N 0.34W 6.36 5.75 89.53 13.0 87.55 N 0.7~V 6.94 5.98 89.32 15.5 112.15N 1.37W 7.65 6.21 89.14 18.0 140.95N 2.1~W4 8.50 6.44 89.00 20.5 173.90 N 3.0~W 9.51 6.68 88.87 23.0 210.93N 4.2CW 10.67 6.92 88.77 25.5 251.97N 5.48W 12.00 7.17 88.69 28.0 296.95 N 6.9..~W 13.48 7.43 88.61 Survey Tool 0.00 BPHG-PBD 1.81 BPHM-PBD 1.96 BPHM-?BD 2.27 BPHM-PBD 2.43 BPHM-PBD 2.54 BPHM-PBD 2.66 BPHM-PBD 2.84 BPHM-PBD ". 3.04 BPHM-PBD 3.26 BPHM~PBD 3.49 BPHM-PBD 3.75 BPHM-PBD 4.03 BPHM-PBD 4.34 BPHM-PBD 4.67 BPHM-PBD 5.03 BPHM-PBD 5.42 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 10/11/95 Wellpa~h ID: MPF-62 Wp2 Measured Incl Drift Subsea TVD Course T O T A L GRID Coordinates Closure Vertical Build Walk DLS Cunt Expected Total Max Hor Mia Hot Dk. Vat Survey Tool Depth Dir. Depth Length Rectangular Offsets Norlhiag Eastiag Dist. Dir. Section Rate Rate Dogleg Rectangular Coorcls Error Error Max Err Error (ft) (deg.) (deg.) (ft) (ft) (fl) (ft) (fl) (ft) (ft) (ft) (deg.) (ft) (dg/100ft) (dgtl0Oft) (clg/100ft) (deg) (ft) (fl) (ft) (ft) (deg.) (fi) 2916.67 30.50 358.15 2813.98 2858.68 100.00 345.78N 8.3.'3~V 6035939.01 541924.66 345.88@358.62 338.99 2.50 -0.04 2.50 30.5 345.78N 8.5.q~/ 15.11 7.70 88.55 5.83 BPHM-PBD 3016.67 33.00 358.12 2899.01 2943.71 1130.00 398.37N 10.05W 6035991.58 541922.65 398.49@358.56 390.64 2.50 -0.03 2.50 33.0 398.36N 10.32W 16.88 7.98 88.49 6.27 BPHM-PBD 3116.67 35.50 358.09 2981.67 3026.37 100.00 454.61N ll.91W 6036047.80 541920.47 454.76@358.50 445.89 2.50 43.03 2.50 35.5 454.60N 12.2CN 18.80 8.27 88.44 6.75 BPHM-PBD 3216.67 38.00 358.06 3061.79 3106.49 100.130 514.40N 13.9Z¥ 6036107.57 541918.12 514.58@358.45 504.63 3316.67 40.50 358.04 3139.23 3183.93 100.00 577.62N 16.0ght 6036170.78 541915.61 577.84@358.41 566.75 3416.67 43.00 358.02 3213.83 3258.53 100.00 644.16N 18.39W 6036237.29 541912.94 644.42@358.37 632.14 2.50 43.03 2.50 -0.02 2.50 -0.02 2.50 38.0 514.38N 14.33~/ 20.86 8.57 88.40 7.26 BPHM-PBD 2.50 40.5 577.60N 16.599/ 23.04 8.88 88.36 7.80 BPHM-PBD 2.50 43.0 644.14N 18.983/ 25.35 9.19 88.32 8.37 BPHM-PBD START OF CURVE @ 2.50 deg/100 ft 3496.82 45.00 358.00 3271.49 3316.19 80.15 699.80N 20.31W 6036292.91 541910.69 700.09@358.34 686.81 3596.82 47.16 356.25 3340.85 3385.55 100.00 771.73N 23.94W 6036364.82 541906.65 772.10@358.22 757.75 3696.82 49.35 354.63 3407.43 3452.13 1130.00 846.09N 29.8~W 6036439.14 541900.29 846.62@357.98 831.58 2.50 ~0.02 2.16 -1.75 2.19 ~1.63 2.50 45.0 699.77N 21.(KW 27.28 9.44 88.30 8.86 BPHM-PBD 2.50 47.5 771.69N 24.8~qhr 29.78 9.78 88.02 9.47 BPHM-PBD 2.50 50.0 846.02N 31.1gAt 32.38 10.12 87.65 10.11 BPHM-PBD 3796.82 51.55 353.11 3471.10 3515.80 100.00 922.74N 38.14W 6036515.74 541891.60 923.53@357.63 908.15 3896.82 53.78 351.67 3531.75 3576.45 100.00 1001.55N 48.6gh/ 6036594.47' 541880.62 1002.73@357.22 987.33 3996.82 56.02 350.32 3589.25 3633.95 100.00 1082.34N 61.5CW 6036675.19 541867.35 1084.09@356.75 1068.95 2.21 -1.52 2.23 -1.43 2.24 -1.35 2.50 52.5 922.62N 39.82W 35.08 10.46 87.20 10.79 BPHM-PBD 2.50 55.0 1001.34N 50.94W 37.86 10.79 86.71 11.51 BPHM-PBD 2.50 57.5 1082.02N 64.45W 40.74 11.12 86.18 12.25 BPHM-PBD 4096.82 58.28 349.04 3643.49 3688.19 100.00 1164.98N 76.5tW 6036757.73 541851.82 1167.513@356.24 1152.87 4196.82 60.55 347.82 3694.37 3739.07 100.00 1249.31N 93.84W 6036841.95 541834.07 1252.83@355.70 1238.93 4296.82 62.82 346.65 3741.80 3786.50 100.00 1335.16N 113.3CW 6036927.68 541814.13 1339.95@355.15 1326.95 2.26 - 1.28 2.27 -1.22 2.28 -!.17 2.50 60.0 1164.50N 80.37W 43.71 11.43 85.62 13.03 BPHM-PBD 2.50 62.5 1248.62N 98.53V 46.77 11.73 85.03 13.84 BPHM-PBD 2.50 65.0 1334.21N 119.12NV 49.92 12.02 84.43 14.68 BPHM-PBD END OF CURVE 4391.91 65.00 345.58 3783.62 3828.32 95.10 1418.06N 133.8CW 6037010.46 541793.16 1424.36@354.61 1412.34 CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 4592.00 65.00 345.58 3868.18 3912.88 200.09 1593.69N 178.9ON 6037185.81 541747.03 1603.71@353.59 1593.61 2.29 -1.12 0.00 0.00 2.50 67.4 1416.82N 140.77W 52.99 12.28 83.86 15.51 BPHM-PBD 0.00 67.4 1591.82N 188.3~'AV 59.53 13.11 82.93 17.02 BPHM-PBD 4592.25 65.00 345.58 3868.29 3912.99 0.25 1593.91N 179.0TN 6037186.03 541746.97 1603.93@353.59 1593.84 0.00 0.00 0.00 67.4 1592.04N 188.41W 59.53 13.11 82.93 17.02 BPHM-PBD NA Sands 4738.28 65.00 345.58 3930.00 3974.70 146.03 1722.08N 211.97W 6037314.01 541713.30 1735.08@352.98 1726.13 0.00 0.00 OA Sands 5258.84 65.00 345.58 4150.00 4194.70 520.56 2179.01N 329.40,V 6037770.23 541593.27 2203.78@351.40 2197.75 0.00 0.00 5592.00 65.00 345.58 4290.80 4335.50 333.16 2471.45N 404.6~qhr 6038062.21 541516.46 2504.35@350.70 2499.58 0.00 0.00 5592.25 65.00 345.58 4290.90 4335.60 0.25 2471.67N 404.71W 6038062.42 541516.40 2504.58@350.70 2499.80 0.00 0.00 B. Schrader 5850.39 65.00 345.58 4400.00 4444.70 258.14 2698.25N 462.97W 6038288.66 541456.88 2737.68@350.26 2733.67 0.00 0.00 START OF CURVE @ 2.00 deg/100 fl 9590.03 65.00 345.58 5980.44 6025.14 3739.64 5980.75N 1306.9.q;V 6041566.12 540594.90 6121.89@347.67 6121.64 0.00 0.00 9690.03 63.00 345.55 6024.28 6068.98 100.00 6067.79N 1329.3tqV 6041653.03 540572.02 6211.70@ 347.64 6211.48 -2.00 4).03 9790.03 61.00 345.51 6071.22 6115.92 1130.00 6153.28N 1351.42~r 6041738.39 540549.50 6299.94@347.61 6299.74 -2.00 -0.04 9890.03 59.00 345.47 6121.22 6165.92 100.00 6237.12N 1373.17vV 6041822.10 540527.35 6386.48@347.58 6386.30 -2.00 -0.04 9990.03 57.00 345.43 6174.20 6218.90 100.00 6319.20N 1394.4229/ 6041904.05 540505.61 6471.22@347.56 6471.06 -2.(X) -0.04 10090.03 55.00 345.39 6230.12 6274.82 100.130 6399.43N 1415.303/ 6041984.16 540484.29 . 6554.06@347.53 6553.93 -2.00 -0.04 10190.03 53.00 345.35 6288.89 6333.59 100.00 6477.70N 1435.7~%V 6042062.32 540463.44 6634.90@ 347.50 6634.79 -2.00 -0.04 10290.03 51.00 345.31 6350.45 6395.15 100.00 6553.93N 1455.68'W 6042138.43 540443.07 6713.65@)347.48 6713.55 -2.(X) -0.04 0.00 67.4 1719.76N 223.17W 64.34 13.72 82.37 18.16 BPHM-PBD 0.00 67.4 2175.07N 346.92W 81.65 15.92 80.89 22.36 BPHM-PBD 0.00 67.4 2466.47N 426.1~W 92.81 17.34 80.24 25.14 BPHM-PBD 0.00 67.4 2466.69N 426.2CW 92.82 17.34 80.24 25.14 BPHM-PBD 0.00 67.4 2692.47 N 487.5~/ 101.50 18.45 79.83 27.32 BPHM-PBD 0.00 67.4 5963.33N 1376.8JW 228.35 34.63 77.44 59.99 BPHM-PBD 2.00 69.4 6050.07 N 1400.4£W 231.69 35.33 77.42 60.71 BPHM-PBD 2.00 71.4 6135.27N 1423.6CW 234.96 36.07 77.39 61.39 BPHM-PBD 2.00 73.4 6218.82N 1446.3~'W 238.16 36.83 77.36 62.03 BPHM-PBD 2.00 75.4 6300.63N 1468.%aW 241.29 37.62 77.34 62.63 BPHM-PBD 2.00 77.4 6380.60N 1490.61W 244.34 38.44 77.31 63.19 BPHM-PBD 2.(X) 79.4 6458.63N 1511.91,~h/ 247.30 39.27 77.29 63.72 BPHM-PBD 2.(X) 81.4 6534.62N 1532.8.,%V 250.18 40.11 77.27 04.20 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 3 . - Date: 10/11/95 .Wellpath ID: MPF-62 Wi~2 Measured lncl Drift Subsea TVD Course T O T A L Depth Dir. Deplh Length Rectangular Offsets (ft) (deg.) (deg.) (fl.) (ft) (1~) (ft) (ft) GRID Co(ndinates Northing Fasting (ft) (it) Cloaure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hot Dff. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Erro~ Erro~ Max Err Erro~ (ft) (deg.) (ft) (dg/100ft) (dg/10Oft) (dg/100ft) (deg) (ft) (ft) (ft) (fi) (deg.) (ft) Survey Toot 10390.03 49.00 345.26 6414.73 6459.43 100.00 6628.02N 1475.1_'%V 6042212.40 540423.21 6790.19@347.45 6790.11 -2.00 -0.05 10490.03 47.00 345.21 6481.63 6526.33 100.00 6699.88N 1494.09W 6042284.15 540403.88 6864.45@347.43 6864.38 -2.00 -0.05 10590.03 45.00 345.15 6551.09 6595.79 100.00 6769.42N 1512.4W~/ 6042353.58 540385.11 6936.33@ 347.41 6936.27 -2.00 -0.05 2.00 83.4 6608.48N 1553.17W 252.97 40.97 77.25 64.64 BPHM-PBD 2.00 85.4 6680.13N 1572.976/ 255.67 41.83 77.23 65.05 BPHM-PBD 2.00 87.4 6749.47N 1592.0W~r 258.27 42.70 77.21 65.41 BPHM-PBD 10690.03 43.00 345.10 6623.02 6667.72 100.00 6836.56N 1530.32W 6042420.62 540366.91 7005.74@ 347.38 7005.69 -2.00 -0.06 10790.03 41.00 345.03 6697.32 6742.02 100.00 6901.21N 1547.5e'W 6042485.17 540349.32 7072.60@ 347.36 7072.56 -2.00 -0.06 END OF CURVE 10840.23 40.00 345.00 6735.50 6780.20 50.20 6932.71N 1555.9~N 6042516.62 540340.72 7105.18@347.35 7105.14 -2.00 -0.07 2.00 89.4 6816.42N 1610.61W 260.77 43.57 77.19 65.73 B'PHM-PBD 2.00 91.4 6880.90 N 1628.51W 263.17 44.43' 77.17 66.02 B PHM-PB D 2.00 92.4 6912.31N 1637.2C'W 264.35 44.86 77.16 66.16 BPHM-PBD THRZ 10850.03 40.00 345.00 6743.00 6787.70 9.79 6938.79 N 1557.62AV 6042522.69 540339.06 7111.47@ 347.35 7111.43 0.00 0.00 BHRZ 10928.35 40.00 345.00 6803.00 6847.70 78.33 6987.42N 1570.65W 6042571.24 540325.77 7161.78@347.33 7161.')4 0.00 0.00 TKUD 11137.22 40.00 345.00 6963.00 7007.70 208.87 7117.10N 1605.4CW 6042700.72 540290.32 7295.92@ 347.29 7295.90 0.00 0.00 Target '9/28/95 ! TKUA3 11374.80 40.00 345.00 7145.00 7189.70 237.58 7264.62N 1644.9~wq 6042848.00 540250.00 7448.52@ 347.24 7448.51 0.00 0.00 TMLV ! 1504.04 40.00 345.00 7244.00 7288.70 129.24 7344.86N 1666.423~r 6042928.12 540228.07 7531.53@ 347.22 7531.52 0.00 0.00 CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/fl. 11804.03 40.00 345.00 7473.81 7518.51 299.99 7531.12N 1716.34W 6043114.09 540177.16 7724.22@347.16 7724.22 0.00 0.00 0.00 92.4 6918.38N 1638.9~ 264.58 44.91 77.16 66.20 BPHM-PBD 0.00 92.4 6966.87N 1652.4~N 266.42 45.35 77.14 66.57 BPHM-PBD 0.00 92.4 7096.20N 1688.54W 271.32 46.50 77.10 67.57 BPHM-PBD 0.00 92.4 7243.31 N 1729.579/ 276.90 47.81 77.06 68.69 BPHM-PBD 0.00 92.4 7323.33N 1751.8~V 279.93 48.53 77.04 69.31 BPHM-PBD 0.00 92.4 7531.12N 1716.34W 0.00 0.00 0.00 0.00 BPHM-PBD 11804.04 40.00 345.00 7473.81 7518.51 0.01 7531.12N 1716.34W 6043114.09 540177.16 7724.22@347.16 7724.22 0.00 0.00 0.00 92.4 7509.09N 1803.6gW 286.98 50.19 76.99 70.73 BPI-[M-PBD OCT '~ ~ t$~ Aiaaka 0il & aas Cor~s. Commission Anchorage WELL PERMIT CHECKLIST INIT CLASS WELL NAME GEOL AREA UNIT# PROGRAM: exp [] // ~_/ dev [] redrll [] serv~ ON/OFF SEORE ~ ~%J ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. ~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ..... iQ N 19. Casing designs adequate for C, T, B & permafrost. ~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndrunnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip lis~ adequate .~ N 25. BOPEs adequate ~~ N 26. BOPE press rating adequate; test to psig N 27. Choke manifold complies w/~I ~-53 (May 84) ...... 28. Work will occur without operation shutdo~ ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/~ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ......... 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: TAB HOW/jo - A:tFORMS%cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is Part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LzS TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 6597.00 M. WORDEN T. ANGLEN ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 500292260900 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 03-MAY-96 MWD RUN 2 M. WORDEN T. ANGLEN MWD RUN 3 M. HANIK J. GAFFANEY 6 13N 10E 2141 2627 45.75 12.00 M C OF LMED WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DR~._P_S BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 110.0 12.250 9.625 6058.0 8.500 11910.0 MWD - DGR/EWR4/CNP/SLD. ALL DEPTHS ARE MEASURED BIT DEPTHS. ALL GAMMA RAY DATA WAS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TUBE DETECTORS (DGR/SGRC). MWD RUNS 1 & 2 WERE DIRECTIONAL WITH GAMMA RAY (DGR), & ELECTROMAGNETIC 4-PHASE WAVE RESISTIVITY (EWR4). MWD RUN 3 WAS DIRECTIONAL WITH GAMMA RAY (DGR), ELECTROMAGNETIC 4-PHASE WAVE RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP), & STABILIZED LITHO DENSITY (SLD) . ENVIRONMENTAL FACTORS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE = 8.5" ,, ....... MUD WEIGHT = 8.4 - 10.3 ppg - MUD FILTRATE SALINITY 500 700 ppm ~ i '-~ FORMATION WATER SALZNITY = 14545 ppm ~ .... FLUID DENSITY = 1.0 g/cc ,,~.:::~,~.(~::a..i~=(Z ~', MATRIX DENSITY = 2 65 g/cc LITHOLOGY = SANDSTONE FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE CURVE SHIFT DATA .5000 START DEPTH 186.0 176.0 5993.0 6051.0 FOR SHIFTS: GRCH (MEASURED DEPTH) BASEL 151 9806 9955 10011 10160 10259 10312 10408 10504 10507 10510 10530 10597 10771 10781.0 10880.5 10930.5 10936.0 10970.0 10979.5 10991.5 11004.5 11022.0 11051.5 11061.0 11087.5 11091.5 11094.0 11139.5 11160.0 11193.5 11211.5 11239.0 11244.5 11265.5 11276.5 11293.0 11300.5 11350.0 11367.5 11378.5 INE DEPTH .5 .0 .0 .5 .0 .0 .0 .0 .0 .5 .0 .0 .5 .0 GR 150.0 9804.5 9954.5 10009.5 10161.0 10260.0 10312.5 10408.5 10506.0 10509.0 10512.0 10529.5 10599.0 10772.0 10782.5 10880.5 10933.0 10936.5 10971.0 10976.5 10993.0 11004.5 11023.5 11053.5 11063.0 11089.5 11093.0 11095.5 11141.0 11161.5 11194.0 11211.5 11241.0 11246.0 11267.5 11278.5 11294.5 113'02.5 11351.5 11368.5 11379.0 all bit runs merged. STOP DEPTH 11849.0 11822.0 11830.0 11838.0 (WALS, 07-NOV-95) EQUIVALENT UNSHIFTED DEPTH 11383.0 11384.5 11390.0 11390.0 11410.0 11411.5 11421.0 11422.0 11436.5 11438.0 11452.0 11452.5 11461.0 11462.0 11463.0 11464.0 11469.5 11471.0 11481.5 11483.5 11489.0 11491.0 11494.0 11496.5 11515.0 11516.5 11521.0 11524.5 11525.5 11527.5 11541.0 11542.0 11561.0 11563.0 11574.5 11574.5 11659.5 11662.0 11668.5 11669.0 11699.0 11701.5 11709.5 11711.0 11732.0 11731.5 11910.5 11910.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 $ REMARKS: MERGE TOP 230.0 5579.0 6080.0 MERGE BASE 5579.0 6080.0 11910.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. /? ?SHIFT. OUT $ CN : BP EXPLORATION WN : MPF-62I FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 CurveS: Name Tool 1 GR MWD 2 RPX MWD Code Samples Units 68 1 AAPI 68 1 OHMM Size 4 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 DRHO MWD 68 1 G/C3 4 9 PEF MWD 68 1 BN/E 4 10 ROP MWD 68 1 FPHR 4 11 FET MWD 68 1 HR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1121 4 90 120 46 4 90 120 46 4 90 120 46 4 90 890 01 4 90 350 01 4 90 356 99 4 90 358 01 4 90 810 01 4 90 180 01 Tape File Start Depth = 11911.000000 Tape File End Depth = 150.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 282277 datums Tape Subfile: 2 1283 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 184.0 EWR4 175.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5531.0 5523.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 29-0CT-95 ISC 2.12 / MPDS 1.22 3.94 MEMORY 5579.0 230.0 5579.0 0 .3 65.8 TOOL NUMBER P0404CGR8 P0404CGR8 12.250 110.0 SPUD 9.10 118.0 8.5 1100 9.8 3.000 1.580 2.800 4.400 60.0 120.0 60.0 60.0 .00 .000 .0 0 REMARKS: MWD RUN 1. $ CN : BP EXPLORATION WN : MPF-62I FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR 7 FET MWD 68 1 HR * DATA RECORD (TYPE# 0) Total Data Records: 351 API API API API Log Crv Crv Size Length TIP TIP Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 998 BYTES * Tape File Start Depth = 5580.000000 Tape File End Depth = 150.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 86889 datums Tape Subfile: 3 416 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5532.0 EWR4 5523.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 6031.0 6023.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OPIMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 30-0CT-95 ISC 2.12 / MPDS 1.22 3.94 MEMORY 6080.0 5579.0 6080.0 0 63.6 65.1 TOOL NUMBER P0404CGR8 P0404CGR8 12.250 110.0 SPUD 9.40 73.0 8.5 1000 0.4 3.000 1.750 2.800 4.400 60.0 100.0 60.0 60.0 .00 .000 .0 0 REMARKS: MWD RUN 2. $ CN : BP EXPLORATION WN : MPF-62I FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 37 Tape File Start Depth = 6085.000000 Tape File End Depth = 5520.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 291326 datums Tape Subfile: 4 102 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6011.0 11849.0 EWR4 5983.0 11822.0 CNP 5991.0 11829.0 SLD 6050.0 11838.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 04-NOV-95 ISC 2.12 / MPDS 1.22 3.94 MEMORY 11910.0 6080.0 11910.0 0 37.3 66.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STAB. LITHO DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0428CRNSLDG6 P0428CRNSLDG6 P0428CRNSLDG6 P0428CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 6058.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND-LT 10.30 41.0 9.5 5OO 4.2 1.700 .690 1.620 2.500 64.0 167.0 64.0 64.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN/ : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 3. $ CN : BP EXPLORATION WN : MPF-62I FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA 8 · b,.,O .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 RHOB MWD 68 1 G/C3 4 8 DRHO MWD 68 1 G/C3 4 9 PEF MWD 68 1 BN/E 4 10 ROP MWD 68 1 FPHR 4 11 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 810 01 1 4 90 180 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 565 Tape File Start Depth = 11912.000000 Tape File End Depth = 5980.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 229270 datums Tape Subfile: 5 634 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS 96/ 5/ 3 O1 **** REEL TRAILER **** 96/ 5/ 3 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 3 MAY 96 4:49a Elapsed execution time = 8.12 seconds. SYSTEM RETURN CODE = 0 MPF- 62 MILNE POINT Run 1: 07 - NOV- 1995 Marked Line GR Cased Hole .... , ...... :e: :: .:~ . :::::::::::::::::::::::::::::::: ...... ATLAS Logging Service~ 11742 Tape Subfile 2 is type: _S TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF - 62 500292260900 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 02-DEC-95 6516.00 K. RICHARDS J. GAFFNEY 6 13N 10E 2141 2627 33.75 14.90 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 6058.0 40.00 PRODUCTION STRING 7.000 11896.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS GR GRCH 1 1 07-NOV-95 WESTERN ATLAS LOGGING SERVICES PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH GRCH REMARKS: GR/SBT - MARKED LINE. MAGNETIC MARKS USED FOR DEPTH CONTROL. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER' FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9788.0 11742.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 62 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 47 1014 BYTES * Tape File Start Depth = 9785.000000 Tape File End Depth = 11745.000000 Tape File Level Spacing = 0.500000 Tape File Depth Un~ ~ = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11764 datums Tape Subfile: 2 139 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 i~ type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 11386.0 BASELINE DEPTH GRCH 11391.0 11391.5 11409.5 11411.0 11425.0 11426.5 11427.0 11428.0 11436.5 11437.5 11438.5 11439.0 11439.5 11440.0 11440.0 11441.0 11445.0 11446.0 11446.0 11446.5 11450.0 11450.5 11452.5 11453.5 11461.5 11462.5 11465.5 11466.0 11471.5 11472.0 11473.5 11474.5 11476.0 11477.0 11481.0 11481.5 11484.5 11485.0 11485.0 11486.0 11505.0 11506.0 11506.0 11506.5 11506.5 11507.0 11509.5 11510.5 11526.0 11526.0 11540.5 11541.0 11558.0 11558.5 11566.0 11567.0 11578.0 11579.5 11578.5 11580.0 11586.0 11586.5 11605.0 11605.5 11616.0 11617.0 11628.5 11629.0 11647.5 11648.5 11657.5 11658.0 11668.0 11669.5 11674.0 11674.0 STOP DEPTH 11742.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 11688.0 11700.5 11701.5 11702.0 11718.0 11732.0 $ REMARKS: llt ,.5 11701.5 11702.5 11703.0 11718.0 11732.5 PASS 2 (REPEAT PASS). TENS SHIFTED WITH GRCH / ? ?MATCH2A . OUT $ CN : BP EXPLORATION WN : MPF - 62 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB * DATA RECORD (TYPE# 0) Total Data Records: API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 1014 BYTES * Tape File Start Depth = 11385.000000 Tape File End Depth = 11745.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2164 datums Tape Subfile: 3 86 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 i's type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9788.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 11756.5 07-NOV-95 FSYS REV. J001 VER. 1.1 811 07-NOV-95 11791.0 11780.0 9820.0 11742.0 360.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330NA 1309XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 11896.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): FILTERED BRINE 10.20 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RA% NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORI~LIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN) : .0 REMARKS: PASS 1 (MAIN PASS). $ CN : BP EXPLORATION WN : MPF - 62 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 CCL SBT 68 1 4 3 SPD SBT 68 1 F/MN 4 4 TTEN SBT 68 1 LB 4 5 TEN SBT 68 1 LB 4 4 81 310 01 1 4 81 150 01 1 4 81 636 99 1 4 81 635 99 1 4 81 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 189 Tape File Start Depth = 9785.000000 Tape File End Depth = 11760.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59171 datums Tape Subfile: 4 265 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11386.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11759.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAPIMA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : 07-NOV-95 FSYS REV. J001 VER. 1.1 648 07-NOV-95 11791.0 11780.0 9820.0 11742.0 360.0 YES TOOL NUMBER 2330NA 1309XA 1633XA 1424XA 1424PA .000 11896.0 .0 FILTERED BRINE 10.20 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RA% NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPF - 62 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 CCL SBT 68 1 4 3 SPD SBT 68 1 F/MN 4 4 TTEN SBT 68 1 LB 4 5 TEN SBT 68 1 LB 4 4 81 310 01 1 4 81 150 01 1 4 81 636 99 1 4 81 635 99 1 4 81 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 36 Tape File Start Depth = 11385.000000 Tape File End Depth = 11760.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11171 datums Tape Subfile: 5 112 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 95/12/ 1 01 **** REEL TRAILER **** 95/12/ 1 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 1 DEC 95 10:52a Elapsed execution time = 13.73 seconds. SYSTEM RETURN CODE = 0