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Home My WebLink About203-0311a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: 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:17. Field / Pool(s): GL: 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 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 9-5/8" L-80 2602' 7" L-80 5213' 3-1/2"6005' 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 315 sx Class G6-1/8" TUBING RECORD 169 sx Class G8-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 5/17/2023 203-031/ 322-429 2551' FNL, 1207' FEL, Sec. 18, T12N, R8E, UM 2030' FSL, 690' FEL, Sec. 24, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476052 5993865 2196' FSL, 573' FEL, Sec. 24, T12N, R7E, UM SURFACE 9857' MD/ 6009' TVD ADL0025544, ADL0380107 ALK 2639 50-103-20452-00-00 KRU 3S-21 March 21, 2003 April 3, 2003 9. Ref Elevations: KB: 29' Kuparuk River Field/ Kuparuk River Oil Pool AMOUNT PULLED 471860 471742 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BOTTOM N/A 1678' MD/ 1539' TVD N/A 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, CASING If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE CEMENTING RECORD 5988068 SETTING DEPTH TVD 5987900 TOP HOLE SIZE 8391' 3-1/2" 30'582 sx Class G, 326 sx Class G 42" 9.3# 30' 8338' 3664'30' 30' 40-94' MD (all) PLUGGED AND ABANDONED Perforations: 9594-9624' MD and 5842-5861' TVD (Cemented) 8509' SIZE DEPTH SET (MD) 9851' 27' 5123' 62.5# 40# 108' 27' 8351' MD/ 5129' TVD PACKER SET (MD/TVD) PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 250 bbls 15.8 ppg Class G Cement40-6500' MD (PC) 40'-3644' MD 122 bbls 15.8 ppg Class G Permafrost Cement down OA 12-1/4" 80 sx ArcticCrete Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: Gas-Oil Ratio:Choke Size: 3.6 bbls 15.8 ppg Portland Type I/II Class G Cement Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment L-80 By Grace Christianson at 8:11 am, Jun 16, 2023 Abandoned 5/17/2023 JSB RBDMS JSB 062723 xG DSR-6/29/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD SurfACe Surface 1678' 1539' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations, Final PA Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Dusty Ward Digital Signature with Date:Contact Email: dusty.ward@conocophillips.com Contact Phone:(907) 265-6531 Senior CTD/RWO Engineer 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: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - ABANDONED Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - ABANDONED Authorized Name and Formation Name at TD: 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. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,424.0 3S-21 8/12/2022 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason; P&A'd 10.1' below OG. Site clearance requested 5/14/23 post backfill operations. 3S-21 5/17/2023 mouser Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.0 3,643.8 2,602.1 40.00 L-80 BTC PRODUCTION 7 6.28 40.0 8,508.7 5,212.9 26.00 L-80 BTCM LINER 3 1/2 2.99 8,337.6 9,851.0 6,005.5 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.8 Set Depth … 8,391.0 Set Depth … 5,150.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.8 24.8 0.00 HANGER 8.000 FMC GEN 5 TUBING HANGER 3.500 512.3 510.0 10.24 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 8,268.0 5,086.1 58.30 GAS LIFT 5.968 CAMCO MMG 2.992 8,313.8 5,110.1 58.48 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 8,352.1 5,130.1 58.49 LOCATOR 5.000 BAKER G-22 LOCATOR SUB BAKER G-22 3.000 8,353.3 5,130.7 58.49 SEAL 3.980 BAKER GBH-22 CSG SEAL ASSEMBLY BAKER GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 40.0 40.0 0.00 MARKER PLATE 30" Diameter marker plate 1/4" thick welded to insulated jacket, covering 16" Conductor and 9.625 &7" casings. cement @ surface. 5/13/2023 0.000 6,501.0 4,131.1 56.99 PLUG Baker Hughes 3BB K1 CIBP (OAL = 1.98'), MOE @ 6052' RKB Baker Hughes 3BB K1 9/7/2022 0.000 7,025.7 4,415.8 56.08 PLUG Baker Hughes 3BB K1 CIBP (OAL = 1.98'), MOE @ 7026'7' RKB Baker Hughes 3BB K1 9/7/2022 0.000 8,297.0 5,101.3 58.47 CUT TUBING CUT AT 8297' RKB W/ 238 WELLTEC MECHANICAL CUTTER 8/19/2022 2.992 8,424.0 5,167.8 58.09 PLUG Pumped 25.4 bbls of 15.8 ppg cement. 16.4 bbls below retainer, 9 bbls above. 8/12/2022 0.000 9,200.0 5,598.5 53.17 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/28/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,268.0 5,086.1 58.30 1 GAS LIFT OPEN RKP 1 1/2 0.0 8/12/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,337.6 5,122.5 58.48 TIEBACK 5.750 TIEBACK SLEEVE, LENGTH 13.39' 5.250 8,351.0 5,129.5 58.49 PACKER 7.000 BAKER ZXP LINER TOP ISOLATION PACKER w/ HR PROFILE BAKER ZXP 5.000 8,355.7 5,132.0 58.49 NIPPLE 5.530 BAKER RS NIPPLE w/ COLLARS BAKER RS 4.250 8,387.8 5,148.8 58.36 XO THREAD 5.000 4.000 9,750.8 5,941.0 50.29 LANDING COLLAR 3.500 BAKER LANDING COLLAR BAKER 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,332.0 6,482.0 4,037.3 4,120.7 9/12/2022 21.0 APERF 4.72" HSD, PowerFLow 4621, RDX (19g, 21 spf, 60° PHASE, API: 5.9 PEN, 0.83" EH). (9/11/22) 9,594.0 9,624.0 5,841.6 5,860.6 C-4, 3S-21 4/18/2003 6.0 IPERF 2.5" HSD PJ, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,142.0 6,502.0 3,932.5 4,131.6 Plug – Plug Back / Abandonment Plug 36 bbls 15.8 ppg HES Cement plug in production casing through fancy HydaWell tool. 9/14/2022 40.0 3,644.0 40.0 2,602.2 Surface String Cement OA Downsqueeze. 122 BBLs 15.8 ppg Class G Permafrost Cement. 10/14/2022 3S-21, 6/13/2023 4:00:09 PM Vertical schematic (actual) LINER; 8,337.6-9,851.0 IPERF; 9,594.0-9,624.0 CEMENT RETAINER; 9,200.0 PLUG; 8,424.0 PRODUCTION; 40.0-8,508.7 CUT; 8,297.0 PLUG; 7,025.7 PLUG; 6,501.0 APERF; 6,332.0-6,482.0 Plug – Plug Back / Abandonment Plug; 6,142.0 ftKB SURFACE; 40.0-3,643.8 Surface String Cement; 40.0 ftKB CONDUCTOR; 40.0-108.0 MARKER PLATE; 40.0 Cement Plug; 40.0 ftKB Plug – Plug Back / Abandonment Plug; 40.0 ftKB KUP INJ KB-Grd (ft) 34.05 RR Date 4/6/2003 Other Elev… 3S-21 ... TD Act Btm (ftKB) 9,851.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045200 Wellbore Status INJ Max Angle & MD Incl (°) 66.08 MD (ftKB) 2,555.35 WELLNAME WELLBORE3S-21 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.0 6,500.0 40.0 4,130.5 Plug – Plug Back / Abandonment Plug 250 BBLs of 15.8 ppg Class G Cement laid from 6500' to surface. 10/17/2022 40.0 94.0 40.0 94.0 Cement Plug Topped off Cement w/ 15.8 ppg Portland Type I/II Class G Cement 5/12/2023 3S-21, 6/13/2023 4:00:10 PM Vertical schematic (actual) LINER; 8,337.6-9,851.0 IPERF; 9,594.0-9,624.0 CEMENT RETAINER; 9,200.0 PLUG; 8,424.0 PRODUCTION; 40.0-8,508.7 CUT; 8,297.0 PLUG; 7,025.7 PLUG; 6,501.0 APERF; 6,332.0-6,482.0 Plug – Plug Back / Abandonment Plug; 6,142.0 ftKB SURFACE; 40.0-3,643.8 Surface String Cement; 40.0 ftKB CONDUCTOR; 40.0-108.0 MARKER PLATE; 40.0 Cement Plug; 40.0 ftKB Plug – Plug Back / Abandonment Plug; 40.0 ftKB KUP INJ 3S-21 ... WELLNAME WELLBORE3S-21 SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-21 Plug and Abandonment May 22, 2023 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-21, commencing operations on August 19, 2022 and completing the Plug and Abandonment on May 17, 2023. Tubing was cut at 8,297ft KB and rig operations performed to remove tubing from cut depth to surface. After the rig moved off, a bond log was run to determine top of cement in the 7” x OH annulus and to establish intervals for the Perf/Wash/Cement operation. A CIBP was set at 6,502ft KB, the production casing was perforated from 6,332ft to 6,482ft KB, then wash and cement operations were performed across the interval. Cement in the production casing was milled to the CIBP and a bond log run to validate that adequate cement had been placed in the 7” x OH annulus. After this step, the well was cemented to surface inside both the 7” production casing and 7” x 9-5/8” annulus. The well was then excavated below original ground level and the tree and wellhead removed. Contaminated cement was discovered inside the production casing, and subsequently removed by air drilling to a depth of 96ft SLM. After good cement was found, a top job was performed, to bring cement back to surface. After inspection, the well was capped with a marker plate and the excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report Summary is attached. Page 1/5 3S-21 Report Printed: 6/13/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/29/2022 12:00 8/29/2022 18:00 6.00 MIRU, MOVE MOB P Prep rig and around rig for move to 3S - 21 Simops Welders work on Hole fill header line , Install guards on Gen stacks in boiler room , M/P #1 suction flange Electricians work on PFC , Prep Rock washer for move - Get portable Gen set fired up and on line for move - Transfer house power supply Rig Crew prep for rig move - Work on rig move checklist - Prep pad and Equipment around rig for move - Move Rock washer - R/D welding machines not being used - Change out heater core on rig floor 0.0 0.0 8/29/2022 18:00 8/30/2022 00:00 6.00 MIRU, MOVE MOB P Work on 3S - 21 Cellar prep - Move pipe shed Tioga - Move pipe shed back - Move motor complex to the end of the pad - Lay herculite out - Spot rig mats for sub base - Troubleshoot pits moving system Electricians - Unhook rig modules for rig move - swap to cold start power - trouble shoot pit moving system 0.0 0.0 8/30/2022 00:00 8/30/2022 03:00 3.00 MIRU, MOVE MOB P Finish moving motors to the end of the pad - Lay herculite for sub and pits - Berm cellar area Spot rig mats for sub/pits/motors Simops - trouble shoot pits moving system 0.0 0.0 8/30/2022 03:00 8/30/2022 07:00 4.00 MIRU, MOVE MOB P Move pits to end of pad - Cont setting rig mats - Spot tree , flow box , spool and adaptor flange for BOP stack in front of well 3S -21 0.0 0.0 8/30/2022 07:00 8/30/2022 11:00 4.00 MIRU, MOVE MOB P Skid rig floor - Raise stompers , stairs on sub base - Move sub off rig mats to 3S -21 Mentor hands on sub moving Had a Hyd hose leak on skate cattle chute while moving 0.0 0.0 8/30/2022 11:00 8/30/2022 13:30 2.50 MIRU, MOVE MOB T Shut down clean up Hyd. fluid on rig floor , Mezz , sub walls , Pipe shed and ground - Fill rig Hyd tank - Start gen 5 back up - Check Hyd system Simops - Spot Tree , Cellar tote , Spacer spool and Adaptor flange in cellar 3 Gallons on to pad 0.0 0.0 8/30/2022 13:30 8/30/2022 15:30 2.00 MIRU, MOVE MOB P Cont to spot sub base onto mats to 3S - 21 0.0 0.0 8/30/2022 15:30 8/30/2022 18:00 2.50 MIRU, MOVE MOB P PJSM - Spot sub base over 3S -21 , level up shim as needed - Set stompers - Secure stompers rams - Lower windwalls 0.0 0.0 8/30/2022 18:00 8/30/2022 19:00 1.00 MIRU, MOVE MOB P PJSM - Skid rig floor into position - Install handrails - Clean up residul Hyd oil from sub roof 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/4/2022 Page 2/5 3S-21 Report Printed: 6/13/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/30/2022 19:00 8/31/2022 00:00 5.00 MIRU, MOVE MOB P Prep pits/motors complex's for mating up - Move pits/motors mate up to sub base shim as needed - Cont. matting for pipe shed - Spot pipe shed shim as needed - Start on rig acceptance check list 0.0 0.0 8/31/2022 00:00 8/31/2022 06:00 6.00 MIRU, MOVE MOB P Cont work on rig acceptance list - M/U service lines , Mud lines , Hole fill line discharge manifold , Drain lines Welders patch dog house roof Prep to spot rock washer - Prep pad to move shop 0.0 0.0 8/31/2022 06:00 8/31/2022 12:00 6.00 MIRU, MOVE MOB P Cont Rig acceptance checklist - Spot and Berm Rockwasher - Move Shop and Elec shack - Replace fitting on transfer pump house - Repair transfer pump - Work on gas alarms and Gai- Tronics - Set scaffolding for tree work - Install mount for pits air compressor - Install gauges on filter pods in pits - Plug in Rockwasher 0.0 0.0 8/31/2022 12:00 8/31/2022 16:00 4.00 MIRU, MOVE MOB P Cont rig acceptance list - Verify all hoses hooked up correct - Post permit for well - Inspect all handrails and landings are in place - Install plugs in centrifugal pumps - Spot cuttings tank under rockwasher - Spot pipe shed heater - pits ready to bring on fluid - Obtain RKB's 0.0 0.0 8/31/2022 16:00 8/31/2022 17:30 1.50 MIRU, WELCTL OTHR P PJSM - Bring on Seawater to pits - Prime mud pumps - check for leaks - Function #1 M/P 0.0 0.0 8/31/2022 17:30 8/31/2022 20:00 2.50 MIRU, WELCTL MPSP P R/U to pull BPV - Notice PSI on OA - Rig up bleed trailer bleed off gas F/70 PSI to 0 PSI - Shut in monitor PSI - Zero PSI - Pull BPV 0.0 0.0 8/31/2022 20:00 8/31/2022 21:00 1.00 MIRU, WELCTL CIRC P R/U Circulating lines F/IA to open top tank - From M/P to Secodary kill line to top of tree with #1 M/P 0.0 0.0 8/31/2022 21:00 8/31/2022 22:30 1.50 MIRU, WELCTL CIRC P PJSM - Flood lines with seawater from pumps to open top tank - test surface lines to 3500 PSI Simops cont take on seawater to pits - build high vis spacer 0.0 0.0 8/31/2022 22:30 8/31/2022 23:45 1.25 MIRU, WELCTL CIRC P Circ seawater at 6 BPM 1675 PSI- Pump 40 BBl Hi-vis spacer chase with 288 BBLS seawater for 330 BBLS total return 330 BBLS to open top tank 0.0 0.0 8/31/2022 23:45 9/1/2022 00:00 0.25 MIRU, WELCTL OWFF P Flow check 0.0 0.0 9/1/2022 00:00 9/1/2022 00:30 0.50 MIRU, WELCTL OWFF P Flow Check 0.0 0.0 9/1/2022 00:30 9/1/2022 02:00 1.50 MIRU, WELCTL CIRC P PJSM - B/D and R/D Lines On TBG and To Tank 0.0 0.0 9/1/2022 02:00 9/1/2022 02:30 0.50 MIRU, WHDBOP MPSP P Set BPV - Test To 1000 PSI In Direction Of Flow 0.0 0.0 9/1/2022 02:30 9/1/2022 05:15 2.75 MIRU, WHDBOP DHEQ P PJSM - B/D Lines and R/D Lines - R/D Tree Scaffolding - Prep To Pull Tree - Pull Tree Off 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/4/2022 Page 3/5 3S-21 Report Printed: 6/13/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/1/2022 05:15 9/1/2022 06:30 1.25 MIRU, WHDBOP NUND P Check Hanger Threads , Look Good - Install Blanking Plug - Lock DN Screws 3 3/4" In and 4 3/4" Fully Out - Clean Face and Debris F/Top Of Hanger Simops Clean Flange Faces On The 11" x 13 5/8" Adaptor and 13 5/8" Drilling Spool 0.0 0.0 9/1/2022 06:30 9/1/2022 12:00 5.50 MIRU, WHDBOP NUND P N/U BOP and 13 5/8" Drilling Spool and 11" x 13 5/8" Adapter Flange To Well Head - Install Turn Buckles - Grease Choke Simops Help Welders In Pits and Centrifugal Room , Clean Up Around Pad 0.0 0.0 9/1/2022 12:00 9/1/2022 17:00 5.00 MIRU, WHDBOP NUND P Cont N/U BOP - Install Flowline - M/U Flowbox , Low PSI Bleed Off Line , Hole Fill , Mud Bucket Line - Install Trip Nipple (Have To Cut 1' Off Nipple) - Finish Greasing HCR's and Manual Choke/Kill Valves 0.0 0.0 9/1/2022 17:00 9/1/2022 19:15 2.25 MIRU, WHDBOP RURD P Rig Up To Test BOP - Make Up Acme Cross Over To 3 1/2" Test JT - Make Up To Blanking Plug - R/U Testing Manifold and TQ Up Floor Valves - Flood Lines Remove Air From Choke Manifold and Stack - PSI Up To 2500 Fix Leaks On Test Pump - Bring Shell Test To 5000 PSI Leak Under Floor On Choke Line 0.0 0.0 9/1/2022 19:15 9/1/2022 19:45 0.50 MIRU, WHDBOP SVRG P Service rig 0.0 0.0 9/1/2022 19:45 9/1/2022 23:30 3.75 MIRU, WHDBOP RGRP T Fix Leaks As Needed - Tighten Oteco Clamp Under Floor - Attempt Shell Test To 5000 PSI Again Choke Line Under Floor Still Leak Change Out Oteco Ring - Flood Lines Again Shell Test To 5000 PSI Leak - Change Out Oteco Ring and Clamp - Shell Test To 5000 PSI Good Test 0.0 0.0 9/1/2022 23:30 9/2/2022 00:00 0.50 MIRU, WHDBOP BOPE P Test BOP With 3 1/2" Test JT - Test Bag , 4" Demco Kill , Choke Valves 1,12,13,14 , Auto IBOP - Top 3 1/2" x 6" Pipe Rams , HCR Kill , Choke Valves 9,11 , Manual IBOP , Needle Valve On #1 Choke Valve All Test To 250/5000 PSI For 5 Min Each AOGCC - Kam St. John Witness BOP Test 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/4/2022 Page 4/5 3S-21 Report Printed: 6/13/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/2/2022 00:00 9/2/2022 03:45 3.75 MIRU, WHDBOP BOPE P Test BOP - Test With 3 1/2" Test JT To 250/5000 PSI F/5 Min Each - Test Choke Valves #5,8,10,4,6,7,2, - Manual Choke/Kill - XT-39 Dart and TIW Valves - 3 1/2" x 6" BTTM Rams - Blind Rams - Manual and Super Choke - HCR Choke Valve Koomey Drawdown Test ISP = 3025 PSI ISP After Function = 1450 PSI 200 PSI = 27 SEC Full PSI = 161 SEC 4 Nitrogin Bottles = 2520 PSI AVG Closing Times BAG = 19 SEC UPR = 7 SEC Blinds = 14 SEC LPR = 7 SEC HCR Kill/Choke = 1 Sec each Test Gas Alarms AOGCC - Kam St. John Witness BOP Test 0.0 0.0 9/2/2022 03:45 9/2/2022 06:00 2.25 COMPZN, RPCOMP RURD P Rig Down Test Equipment - Blow Down Lines - Pull Blanking Plug - L/D Test JT 0.0 0.0 9/2/2022 06:00 9/2/2022 07:45 1.75 COMPZN, RPCOMP SLPC P PJSM - P/U 5" DP Pup - M/U To Top Drive - Clean Clear Floor For Slip/Cut 0.0 0.0 9/2/2022 07:45 9/2/2022 08:30 0.75 COMPZN, RPCOMP SLPC P PJSM - Hang Blocks - Pull Drawworks Gaurd - Traction Motor A Issues 0.0 0.0 9/2/2022 08:30 9/2/2022 09:00 0.50 COMPZN, RPCOMP SVRG P Sericve Rig SimOps - Trouble Shoot Traction Motor 0.0 0.0 9/2/2022 09:00 9/2/2022 16:15 7.25 COMPZN, RPCOMP RGRP T Trouble Shoot Traction Motors SimOps Stage 3 1/2" Tools At Slide - Work On Trip Tank Artic Dumps - Clean/Prep Shed For Laying Down TBG - Check Bolts on MP # 1 Fluid End - Plumbing On Charge Pump #1 For Mud Samples - Work On H2O Plumbing - Totco Wiring In Gauges and Work On Auto Driller 0.0 0.0 9/2/2022 16:15 9/2/2022 18:30 2.25 COMPZN, RPCOMP SLPC P Slip Cut 60' DRLG LIne 0.0 0.0 9/2/2022 18:30 9/2/2022 20:00 1.50 COMPZN, RPCOMP RURD P PJSM - R/U To Pull 3 1/2" TBG SimOps Trouble Shoot BOP Panel In Dog House 0.0 0.0 9/2/2022 20:00 9/2/2022 21:00 1.00 COMPZN, RPCOMP MPSP P Pull BPV 0.0 0.0 9/2/2022 21:00 9/2/2022 22:00 1.00 COMPZN, RPCOMP PULL P PJSM - P/U JT 3 1/2" TBG and 6' Pup - M/U Landing JT - M/U T/Hanger - M/U Crossovers On Top - M/U To Top Drive 0.0 0.0 9/2/2022 22:00 9/3/2022 00:00 2.00 COMPZN, RPCOMP PULL P PJSM - Pull Hanger T/Floor - BOLDS - Pull Up T/140K on Hook (Calc Up WT=125K) - S/O T/90K - P/U T/150K On Hook Come Free - FL CK F/10 MIn - Drain Stack - Set Hanger Back In TBG Spool - R/D Crossovers F/Landing JT - Pull Hanger T/Floor 120K UP WT - L/D Hanger And Landing JT 8,279.0 8,241.0 9/3/2022 00:00 9/3/2022 07:45 7.75 COMPZN, RPCOMP PULL P POOH L/D 3 1/2" TBG F/8241' T/ 8,241.0 2,450.0 9/3/2022 07:45 9/3/2022 08:00 0.25 COMPZN, RPCOMP OWFF P Flow Check - R/U Drain Stack - Clean Floor 2,450.0 2,450.0 Rig: DOYON 19 RIG RELEASE DATE 9/4/2022 Page 5/5 3S-21 Report Printed: 6/13/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/3/2022 08:00 9/3/2022 10:00 2.00 COMPZN, RPCOMP FRZP P R/U To Freeze Protect well - Test Lines To 1000 PSI 2,450.0 2,450.0 9/3/2022 10:00 9/3/2022 11:15 1.25 COMPZN, RPCOMP FRZP P PJSM - Freeze Protect Well - Pump 84 BBLS Diesel W/LRS - Returns To Open Top Tank - 350 PSI ICP @ 2BPM - 450 FCP @ 2 BPM - Pump 84 BBLS Return 84 BBLS 2,450.0 2,450.0 9/3/2022 11:15 9/3/2022 13:15 2.00 COMPZN, RPCOMP FRZP P Allow Diesel To Utube - ISP 75 PSI SimOps Take 3 1/2" TBG Out Of Shed 2,450.0 2,450.0 9/3/2022 13:15 9/3/2022 13:45 0.50 COMPZN, RPCOMP OWFF P Flow Check 2,450.0 2,450.0 9/3/2022 13:45 9/3/2022 16:00 2.25 COMPZN, RPCOMP PULL P POOH With 3 1/2" TBG T/1023' - 65K UP 65K DN 2,450.0 1,023.0 9/3/2022 16:00 9/3/2022 16:30 0.50 COMPZN, RPCOMP SVRG P Service rig - SimOps Trouble Shoot Pipe Skate 1,023.0 1,023.0 9/3/2022 16:30 9/3/2022 17:00 0.50 COMPZN, RPCOMP RGRP T Trouble Shoot And Repair Pipe Skate Sensors - Clean And Readjust 1,023.0 1,023.0 9/3/2022 17:00 9/3/2022 18:00 1.00 COMPZN, RPCOMP PULL P POOH W/3 1/2" TBG F/1023' T/Surface - Cut JT = 14.60' - Total L/D Hanger/Pup - 266 JTS TBG - GLM/Pups - DS Nipple - Cut JT Cut JT Left In Hole = 16.74' 1,023.0 0.0 9/3/2022 18:00 9/3/2022 19:00 1.00 COMPZN, RPCOMP RURD P PJSM - Flow Check - R/D Casing Equipment SimOps - Clear Pipe Shed Of 3 1/2" TBG - Spot LRS 0.0 0.0 9/3/2022 19:00 9/3/2022 20:30 1.50 COMPZN, RPCOMP FRZP P PJSM - R/U LRS Test Lines T/500 PSI - Pump 8 BBLS Diesel To Fill Hole - Suck Back 3 BBLS To Drain Stack SimOps - B/D Choke/Kill Lines , Hole Fill , Mud LIne 0.0 0.0 9/3/2022 20:30 9/4/2022 00:00 3.50 COMPZN, WHDBOP NUND P PJSM - N/D Riser - Flow Box - Break Connection On Adaptor Spool - Bleed Off Koomy SimOps - Start getting Pits/RockWasher ready to move 0.0 0.0 9/4/2022 00:00 9/4/2022 02:30 2.50 COMPZN, WHDBOP NUND P Finish N/D BOP And Rack Back On BOP Stand - Break Off 11" x 13 5/8" Adaptor Flange 0.0 0.0 9/4/2022 02:30 9/4/2022 05:30 3.00 COMPZN, WHDBOP NUND P N/U 7 1/16" Dry Hole Tree - R/U Test LRS Lines T/3500 PSI 0.0 0.0 9/4/2022 05:30 9/4/2022 06:30 1.00 COMPZN, WHDBOP WAIT T Wait On CPAI - Fitting For Top Of Wellhead To Be Able To Fill Tree And Test 0.0 0.0 9/4/2022 06:30 9/4/2022 08:30 2.00 COMPZN, WHDBOP DHEQ P PJSM - R/U LRS Test Lines T/3000 PSI - Test Tree And Well Bore T/2500 PSI F/30 Min 0.0 0.0 9/4/2022 08:30 9/4/2022 11:00 2.50 COMPZN, WHDBOP RURD P R/D And Clean Cellar , Well Head SimOps - Prep Rig For Move - Secure Well Rig Relaese @ 11:00 HRS 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/4/2022 DTTMSTART JOBTYP SUMMARYOPS 8/19/2022 SUPPORT OTHER OPERATIONS CUT TUBING WITH WELTEC MECHANICAL CUTTER AT 8297.0' RKB, CCL TO CUTTER = 18.0', CCL STOP DEPTH = 8279.0'. JOB COMPLETE READY FOR RIG. 8/29/2022 RECOMPLETION Prep to move rig - Move rig to 3S-21 8/30/2022 RECOMPLETION Move rig to 3S - 21 8/31/2022 RECOMPLETION Rig acceptance checklist - M/U service lines - Spot open top tank for displacement - Set up lay downn area for TBG - Bring on seawater to pits - Displace well 9/1/2022 RECOMPLETION R/D Circ lines - Set/Test BPV - Pull tree off - Install blanking plug - N/U BOP's and lines - Test BOP 9/2/2022 RECOMPLETION Finish BOP Test - Pull Blanking Plug - Cut/Slip DRLG Line - Pull BPV - Unseat Hanger - L/D Hanger and Landing JT 9/3/2022 RECOMPLETION POOH W/3 1/2" TBG T/2450' - Freeze Protect Well - POOH W/3 1/2" TBG - Fill Hole With Diesel - N/D BOP 9/4/2022 RECOMPLETION N/D BOP - N/U Test Tree and Well Bore - Release Rig @ 11:00 HRS 9/5/2022 ACQUIRE DATA RIG UP ELINE, DRIFT 7" CASING WITH 5.96" GAUGE RING TO TUBING STUB AT 8299'. LOG USIT/CBL FROM ABOVE TUBING STUB AT 8275' TO 6100' AT 30 FPM. CONFIRM GOOD DATA AND UPLOAD FOR RUSH PROCESSING. ***JOB IN PROGRESS*** 9/7/2022 SUPPORT OTHER OPERATIONS RIG UP AND RIH W/ CIBP, PLUG STUCK AT 6990' WHILE TYING IN. ABLE TO GO DOWNHOLE INDICATING UPPER SLIPS ARE STICKING. SET CIBP AT 7026.7'. CCL TO MID ELEMENT = 9.8', CCL STOP DEPTH = 7016.9'. SECOND CIBP BROUGHT TO LOCATION. SET 7" CIBP AT PLANNED DEPTH OF 6502'. CCL TO MID ELEMENT = 9.8', CCL STOP DEPTH = 6492.2'. GOOD SET. ***JOB IN PROGRESS*** 9/9/2022 SUPPORT OTHER OPERATIONS AWAIT D19 RIG MOVE, TRAVEL TO 3S-PAD, DISCUSS RU PLAN W/ D19 COMPANY MAN, DECISION MADE TO PICK TOOLS FROM BACK SIDE OF WELL ROW W/ 3RD PARTY CRANE AS TO NOT BLOCK BEAVER SLIDE ACCESS. COMPLETE SLB UNIT SPOT UP, WAIT ON WEATHER. JOB IN PROGRESS 9/10/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 09-SEP-2022*** RIG UP SLB AND 3RD PARTY CRANE. GUN 1 PERFORATED INTERVAL = 6462'-6482', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6454.9' GUN 2 PERFORATED INTERVAL = 6442'-6462', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6434.9' GUN 3 PERFORATED INTERVAL = 6424'-6442', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6414.9' ***JOB IN PROGRESS*** 9/11/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 10-SEP-2022*** CONTINUE PERFORATING GUN 4 PERFORATED INTERVAL = 6402' - 6422', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6394.9' GUN 5 PERFORATED INTERVAL = 6382 '- 6402', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6374.9' GUN 6 PERFORATED INTERVAL = 6362' - 6382', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6354.9' GUN 7 PERFORATED INTERVAL = 6342' - 6362', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6334.9' GUN 8 PERFORATED INTERVAL = 6332' - 6342', CCL TO TOP SHOT = 7.1', CCL STOP DEPTH = 6324.9' ***JOB IN PROGRESS*** 9/12/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 11-SEP-2022*** DRIFT W/ JUNK BASKET AND 5.88" GAUGE RING TO TOP OF CIBP AT 6502'. OVERPULL OFF BOTTOM, ABLE TO PULL FREE. READY FOR COIL TUBING 9/13/2022 SUPPORT OTHER OPERATIONS MIRU. PERFORMED CHAIN INSPECTION ON INJECTOR. FOUND MULTIPLE BROKEN BEARINGS AND PINS. HAD TO GET PARTS FROM DEADHORSE. STILL WORKING ON INJECTOR REPAIRS AT MIDNIGHT. 3S-21 Plug and Abandon Summary of Operations 9/14/2022 SUPPORT OTHER OPERATIONS RIH WITH WASH/CEMENTING NOZZLE. SLOW DOWN TO 15 FPM @ 6300'. WASH ACROSS PERFS DOWN TO TAG @ 6465' CTMD. MAKE 2 MORE UP/DOWN PASSES ACROSS THE PERFS @ 15 FPM. DROP BALL TO SHIFT NOZZLE, PUMP 91 TOTAL BBLS (~2 COIL VOLUMES) AND DID NOT SEE BALL GO ON SEAT. OOH TO VISUALLY CHECK NOZZLE, BALL ON SEAT, NOZZLE SHIFTED. RBIH WITH NOZZLE SHIFTED TO CEMENTING PORTS. JOB IN PROGRESS. 9/15/2022 SUPPORT OTHER OPERATIONS COME ONLINE WITH HALLIBURTON CEMENTERS. PUMP 5 BBL SW PILL. PT HARDLINE TO 8000 PSI. GOOD. COME ONLINE WITH 15.8 PPG CEMENT DOWN THE COIL @ 1.65 BPM, WHP=120, CP=2215, COIL @ 6482' RKB. AS PER PUMP SCHEDULE, BEGIN PULLING UP @4.5 FPM . PUMP A TOTAL OF 69.58 BBLS OF CEMENT. SWAP TO S/W FOR DISPLACEMENT. COIL @ 6332', PULL UP @ 10 FPM, SLOW PUMP RATE TO 0.6 BPM. PULL UP TO 6182'. INCREASE PUMP RATE TO 2.0 BPM COIL @ 6170', CEMENT OUT OF THE COIL. CONTINUE POOH @ 11.6 FPM, PUMP RATE @ 2.0 BPM. COIL @ 5525'. SWAP TO COIL PUMP (WELL READY FOR SLICKLINE IN 48 HRS) 9/17/2022 SUPPORT OTHER OPERATIONS ((STATE WITNESS TAG n' TEST)) DRIFT W/ 2.5" DRIVE DOWN BAILER TO TOC @ 6151' RKB & WORK DOWN TO SOLID TAG @ 6172' RKB (OBTAIN SAMPLE); MIT 7" CASING TO 1800 PSI (PASS) RE-TAG W/ BAILER @ 6156' RKB; READY FOR CTU MILLING. 9/18/2022 SUPPORT OTHER OPERATIONS MIRU. SIMOPS WITH DOYON 19. GET SPOTTED IN NEXT TO THE RIG. RIG UP UNIT AND ALL SUPPORT EQUIPMENT. BEGIN MAKING UP BHA. JOB IN PROGRESS. 9/19/2022 SUPPORT OTHER OPERATIONS RIH WITH 6" BEAR CLAW BIT. DRY TAG @ 6112' CTMD (6148' RKB). ATTEMPT MILLING WHILE PUMPING 3.0 BPM WITH LITTLE SUCCESS. INCREASED PUMP RATE TO 4.0 BPM, STARTED PLUGGING OFF CHOKE DOWNSTREAM. WORKED THROUGH CHOKE PROBLEMS. BACK ONLINE @ 4.0 BPM MILLING. MILLED DOWN TO 6213' CTMD (6249' RKB). MADE 78' OF HOLE. LAY DOWN FOR THE DAY. JOB IN PROGRESS. 9/19/2022 SUPPORT OTHER OPERATIONS RIH WITH 6" BEAR CLAW BIT. DRY TAG @ 6210' CTMD (6246' RKB). COME ONLINE WITH PUMP @ 4.0 BPM. BEGIN MILLING IN HOLE. AVERAGE ROP 1.1 FT/MIN. MILLED DOWN TO 6385' CTMD (6421' RKB) AT MIDNIGHT. JOB IN PROGRESS. 9/20/2022 SUPPORT OTHER OPERATIONS CONTINUE MILLING. BROKE THROUGH CEMENT @ 6460' CTMD. CLEAN DOWN TO 6464.5' CTMD. RBIH AND DRY TAG @ 6477' CTMD (ORIGINAL TAG PRIOR TO CEMENTING WAS 6465' CTMD). FREEZE PROTECT WELL. READY FOR SLICKLINE. 9/22/2022 SUPPORT OTHER OPERATIONS ((STATE WITNESS TAG n' TEST)) DRIFT W/ 3" DRIVE DOWN BAILER TO CEMENT @ 6469' RKB (EST. 13' ABOVE BOTTOM PERF @ 6482' RKB); ATTEMPT TO MIT 7" CASING TO 1500 PSI & ESTABLISH LLR OF .80 BPM LLR @ 1450 PSI (5 BBLS PUMPED); DRIFT W/ 5.95" JUNK BASKET GAUGE RING & TAG @ 6273' RKB; DRIFT W/ 5" IMPRESSION BLOCK TO 6337' RKB. 9/23/2022 SUPPORT OTHER OPERATIONS RIH W/ CBL TOOLS. DEEPEST TAG DEPTH ACHIEVED WAS 6362.0' (~30' FROM TOP OF PERFS). PERFORM MAIN PASS OVER INTERVAL 6350' - 6000', PERFORM REPEAT PASS OVER INTERVAL 6334' - 6000' TOP OF CEMENT FOUND AT 6332.0'. JOB SUSPENSED FOR A PLAN FORWARD. 10/5/2022 SUPPORT OTHER OPERATIONS DRIVE FROM 3F PAD TO 3S-21. CONTACT COMPANY MAN ON RIG 19. SPOT AND RIG UP CTU#14. RIG UP CHOKE, HARD LINES AND TANKS ONCE COIL WAS SPOTTED IN PLACE. P/U HAILEY UNDERREAMER, PRESSURE AND PULL TEST. JOB ONGOING. 10/6/2022 SUPPORT OTHER OPERATIONS M/U 6.25" HAILEY U/R WITH 3.80" 5 BLADE JUNK MILL. TOTAL LENGTH 34FT. TEST TO 4000 PSI. OPEN SWAB VALVES, TAGGED UP IN WELLHEAD. P/U CLOSE SWABS, TAPE UPPER AND LOWER U/R BLADES CLOSED. PRESSURE TEST, OPEN SWABS RIH TAG TOC @ 6370'. STAGE UP PUMPS AND BEGIN U/R FROM 6350' DOWN TO 6501' RKB'. MAKE 3 UP PASSES FROM 6501' TO 6100' RKB, OPEN CIRC SUB AND WASH TBG FROM 6501' TO SURFACE, F/P 7" TO 3000' WITH DIESEL, READY FOR E- LINE. 10/11/2022 SUPPORT OTHER OPERATIONS PERFORM CEMENT EVALUATION LOG WITH DSLT/IBC. LOG MAIN AND REPEAT PASSES UP FROM 6485' TO 6100' AT 5 DEG 6", 5 DEG 3", AND 5 DEG 1.5" RESOLUTIONS. UPLOAD DATA TO DOMAIN CHAMPION FOR RUSH PROCESSING. JOB COMPLETE. 10/13/2022 SUPPORT OTHER OPERATIONS INJECTIVITY TEST PUMPED 20 BBLS DIESEL DOWN OA FOR INJECTIVITY TEST, 3 BPM @1300 PSI. JOB COMPLETE 10/14/2022 SUPPORT OTHER OPERATIONS BULL HEAD 5 BBLS F/W AND 122 BBLS CLASS G CEMENT 10/16/2022 SUPPORT OTHER OPERATIONS PERFORM WEEKLY BOP TEST. RIH TO PLUG AT 6,500'. LAY IN 250 BBLS 15.8 PPG CLASS G CEMENT TO SURFACE. 4/7/2023 SUPPORT OTHER OPERATIONS (P&A) TXIA CDDT (PASSED) OA DDT (PASSED) TXIA TOC @ SURFACE AND OA TOC @ SURFACE 4/10/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/11/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/13/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/14/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/15/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/16/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/17/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/18/2023 SUPPORT OTHER OPERATIONS (P&A) DEGAS OA (IN PROGRESS) 4/21/2023 SUPPORT OTHER OPERATIONS (P&A) OA DDT (PASSED) 4/23/2023 SUPPORT OTHER OPERATIONS (P&A) CUT AND REMOVED THE WELLHEAD (COMPLETE) FOUND ICE BRIDGE IN THE PRODUCTION CASING 4/24/2023 SUPPORT OTHER OPERATIONS (P&A) CUT & REMOVE CELLAR (COMPLETE) EXCAVATE TO 14' (IN PROGRESS) @ 6') 4/25/2023 SUPPORT OTHER OPERATIONS (P&A) EXCAVATE TO 14' (COMPLETE) 4/26/2023 SUPPORT OTHER OPERATIONS (P&A) SET SHORING "CAN" (COMPLETE) ACS CHECKED THE TAILINGS PILE FOR CONTAMINATION (NONE WAS FOUND OK TO USE AS BACKFILL MATERIAL) REMOVE WELLHEAD (IN PROGRESS) 4/27/2023 SUPPORT OTHER OPERATIONS (P&A) NES WELDER CUT AND REMOVED ADDITIONAL 6.25' OF WELL STUB, PLACING CUT ~10' BELOW ORIGINAL TUNDRA. BAD CEMENT AND ICE PLUG FOUND IN THE IA. CONTACTED AOGCC INSPECTOR GUY COOK FOR WITNESS OPPORTUNITY ON 4/29/23. IN PROGRESS. 4/28/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS-WAIT ON AOGCC INSPECTOR WITNESS OF TOC & MARKER PLATE, DUE TO RIG MOVE. SET UP NES EQUIPMENT FOR CAN EXTRACTION. 4/29/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- REMOVED APPROX 28" OF CONTAMINATED CEMENT FROM CONDUCTOR AND PRODUCTION CASING. AOGCC INSPECTORS GUY COOK AND SULLY SULLIVAN, CONFIRMED GOOD CEMENT IN SC. CONDUCTOR AND PRODUCTION CASING NEED FURTHER CEMENT REMOVAL. 4/30/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- CONTINUED TO REMOVE BAD CEMENT FROM PRODUCTION CASING AND CONDUCTOR. DEPTH OBTAINED FROM CUT LOCATION OF WELL STUB IS APPROX 53" AND NO INDICATION OF THE BAD CEMENT CHANGING CONSISTENCY. JOB SUSPENDED FOR PLAN FORWARD. 5/8/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS - AIR DRILLED ADDITIONAL 73' TO FIND GOOD CEMENT. DRILLED ADDITIONAL 5' TO VERIFY GOOD CEMENT. ESTIMATED FILL UP VOLUME 3.4 BARRELS OF CEMENT. OVERALL DEPTH FROM TOP OF PC CUT TO TOP OF CEMENT =83' CLEANED UP AREA INSIDE OF EXCAVATION CAN WITH SUPERSUCKER. FOLLOW UP WITH SL TAG IN THE AM AND CONFER WITH TOWN AND AOGCC FOR PERMISSION TO TOP OFF CEMENT. 5/9/2023 SUPPORT OTHER OPERATIONS RAN UP TO 3" BAILER, TAG CEMENT @ 95' SLM. JOB COMPLETE. 5/10/2023 SUPPORT OTHER OPERATIONS AOGCC INSPECTOR KAM STJOHN WITNESSED TAG W/ 3' BAILER, TAG GOOD CEMENT @ 94' SLM, JOB COMPLETE 5/11/2023 SUPPORT OTHER OPERATIONS (P&A) STANDBY FOR AOGCC APPROVAL TO PROCEED. EMAIL RECEIVED @ 1448 PM TO DO TOP OFF OF CEMENT, NOTIFY AOGCC INSPECTORS AFTER TOP OFF. 5/12/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- TOPPED OFF PC AND CONDUCTOR WITH 15.8 PPG PORTLAND TYPE I/II CLASS G CEMENT. NOTIFIED AOGCC INSPECTORS OF CEMENT TOP OFF. 5/13/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- AOGCC INSPECTOR KAM STJOHN ,VERIFIED GOOD CEMENT AND 3S-21 MARKER PLATE AND INFORMATION. REQUESTED THE SURVEY RECORDS FOR REFERENCE POINT TO VEIFY CUT DEPTH. NES WELDER WELDED 1/4" MARKER PLATE TO WELL STUB TO COVER 7" PRODUCTION CASING x, 9.625" SURFACE CASING,x 16"x 30" INSULATED JACKET. LOUNSBURY & ASSOCIATES SURVEYED THE TOP OF MARKER PLATE TO CONFIRM 10.1' BELOW ORIGINALTUNDRA . AOGCC INSPECTOR KAM STJOHN GAVE APPROVAL TO BACKFILL. RETURN IN THE MORNING TO BACKFILL EXCAVATION CAN & VIBRATE CAN OUT OF EXCAVATION. 5/14/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- BACKFILLED 8' D x 16' H SHORE CAN, EXTRACTED WITH VIBRATORY HAMMER AND CRANE. COMPLETE. REMAINING STEPS, DEMOBILIZE EQUIPMENT AND REQUEST FINAL SITE CLEARANCE. 5/15/2023 SUPPORT OTHER OPERATIONS (P&A) DEMOB SITE EQUIPMENT. REQUEST SITE CLEARANCE FROM AOGCC. AOGCC INSPECTOR GUY COOK , DEFERRED SITE CLEARANCE UNTIL OTHER WITNESS TAG OR TESTS ARE AVAILABLE ON OTHER WELLS ON LOCATION. 5/17/2023 SUPPORT OTHER OPERATIONS (P&A) COMPLETE- AOGCC INSPECTOR GUY COOK, GIVEN SUNDRY AND DOCUMENTATION FOR 3S- 21 P&A. NO DISCREPANCIES MENTIONED INSPECTOR GUY COOK TOOK PHOTOS OF P&A AREA. WSR CLOSED OUT. 2023-0513_Surface_Abandon_Final_KRU_3S-21_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 5/14/2023 P. I. Supervisor FROM: Kam StJohn SUBJECT: Final Surface Abandonment Petroleum Inspector KRU 3S-21 ConocoPhillips Alaska Inc. PTD 2030310; Sundry 322-429 5/13/2023: I travel out to KRU 3S-21 to inspect the surface abandonment. Met with Roger Mouser (CPAI) and discussed what had been done since last inspection of cement top. I was out at KRU 3S on 5-12-2023 doing other work so I was able to witness the weighing of the cement and it being poured into the 7-inch casing and the 9- 5/8-inch x 16-inch annulus. Each bucket was tested for weight before being dumping into the 7-inch. It is not a pretty top job but when I hammered on it with a 5-foot steel bar and it is good hard cement. There is also about 4 inches of cement on the insulation of the 16-inch x 30-inch conductor annulus. Marker plate was inspected and found to be ¼-inch thick steel. All well identification information was correct but the plate was about 3/8-inch too big, so I had them grind it down to fit as per regulations. I had a little trouble getting the survey for the tundra level and depth of casing cutoff. They called Lounsbury back out to reshoot the elevations. The final cut is 10.1 feet below tundra level. They welded on the marker plate and I gave them the go ahead to bury the well. Attachments: Photos       2023-0513_Surface_Abandon_Final_KRU_3S-21_ksj Page 2 of 2 Final Surface Abandonment – KRU 3S-21 (PTD 2030310) Photos by AOGCC Inspector K. StJohn 5/13/2023 2023-0510_Surface_Abandon_KRU_3S-21_ksj Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 5/10/2023 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-21 ConocoPhillips Alaska Inc. PTD 2030310; Sundry 322-429 5/10/2023: Travel out to KRU 3S-21 to look witness a cement tag as part of an ongoing surface abandonment. I met with Roger Mouser (CPAI) and discussed what had been done since AOGCC’s 4/29/2023 inspection of the surface abandonment that showed poor cement quality at surface. Mr. Mouser said CPAI started removing bad cement with a 5-foot heavy steel bar and reached 53 inches below the casing cut-off (cut-ff depth is approximately 10 feet below original tundra). The 7-inch casing still had poor quality cement at 53 inches deep, so they switched over to a track-mounted air driller and we able to drill to 81 feet from the casing cutoff, including approximately 5 feet into hard cement. On 5/9/2023 CPAI tagged top of hard cement with a slick-line bailer and returned a sample – photos attached of the cement sample and current well status. CPAI reran the slickline bailer and again tagged at 81 feet below the casing cutoff and retrieved a had cement sample – photo attached. The 7-inch by 9 5/8-inch annulus has hard cement as noted in previous inspection so no work there was necessary. The 9 5/8-inch by 16-inch annulus was also found to have poor cement during the 4/29/2023 inspection and was dug out with the 5-foot bar to 24 inches below the casing cutoff. It had the consistency of a dry clay that crumbles when struck with a bar hammer. CPAI will discuss with AOGCC engineer about the need to continue digging out the 9 5/8-inch by 16-inch annulus. The marker plate was inspected. It is a ¼-inch steel plate with a diameter of 30 inches to cover the 30-inch by 16-inch insulated conductor. All required information is no the marker plate – photo attached. Attachments: 4 Pictures      2023-0510_Surface_Abandon_KRU_3S-21_ksj Page 2 of 3 Surface Abandonment – KRU 3S-21 (PTD 2030310) Photos by AOGCC Inspector K. StJohn 5/10/2023 2023-0510_Surface_Abandon_KRU_3S-21_ksj Page 3 of 3 2023-0429_Surface_Abandon_KRU_3S-21_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4/29/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-21 ConocoPhillips Alaska Inc. PTD 2030310; Sundry 322-429 4/29/2023: Traveled out to Kuparuk River Unit 3S-21 with AOGCC Petroleum Inspector Sean Sullivan to look at the cement in the casings after the wellhead had been removed from the casing stub. We met with Roger Mouser and Brent Rodgers (both CPAI) upon arrival. There had been a prior conversation between me and Mr. Mouser on 4/28/2023 about the condition of the cement and how it did not appear to be good, cured cement at surface. A sample of the cement found in the well annuli was reportedly taken for analysis – no results were provided during our inspection. Mr. Rodgers left location shortly after our arrival. Our inspection of the cement in the casing was conducted using a 5-foot pry bar to strike down on the cement to see if it was good and cured. The ID of the 7-inch casing contained a yellowish substance that was fairly dense but broke apart easily and crumbled when we struck it with the pry bar. It looked to have a similar characteristic as clay but with a yellow color. The substance between the 7-inch and 9 5/8-inch casing had a yellowish appearance as well but was harder than the material inside the 7-inch casing. Striking it with the pry bar would chip the material annulus material and not crumble like the material inside the 7-inch casing. The material between the 9 5/8-inch casing and the 16-inch conductor looked more like what you would expect cement to look like but would break apart and crumble easily when struck with the pry bar. We inspected the information on the ¼-inch steel identification plate. The API number on the identification plate was not complete and the last two numbers needed to be added. I informed Mr. Mouser of this. We informed Mr. Mouser that they had to remove the material in the 7-inch casing and between the 9-5/8 inch and 16-inch conductor casing until they found good, cured cement. We then told him an AOGCC Inspector would have to come back out to location to confirm the cement was good before they could proceeded with a top-job to fill the casings to surface. 9 James B. Regg Digitally signed by James B. Regg Date: 2023.05.03 16:28:34 -08'00' 2023-0429_Surface_Abandon_KRU_3S-21_gc Page 2 of 4 Before leaving the location, Sean Sullivan and I took some quick measurements to estimate the depth of the casing stub below the top of original tundra. We also measured the cut off sections of the casing removed, and wellhead. When we were done with measurements, we left location. Attachments: Photos 2023-0429_Surface_Abandon_KRU_3S-21_gc Page 3 of 4 Surface Abandonment – KRU 3S021 (PTD 2030310) Photos by AOGCC Inspector G. Cook 4/29/2023 2023-0429_Surface_Abandon_KRU_3S-21_gc Page 4 of 4 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: ___________________ 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:17. Field / Pool(s): GL: 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 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 9-5/8" L-80 2602' 7" L-80 5213' 3-1/2"6005' 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 315 sx Class G6-1/8" TUBING RECORD 169 sx Class G8-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/12/2022 203-031/ 322-152 2551' FNL, 1207' FEL, Sec. 18, T12N, R8E, UM 2030' FSL, 690' FEL, Sec. 24, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476052 5993865 2196' FSL, 573' FEL, Sec. 24, T12N, R7E, UM 8424' MD/ 5168' TVD 9857' MD/ 6009' TVD ADL0025544, ADL0380107 ALK 2639 50-103-20452-00-00 KRU 3S-21 March 21, 2003 April 3, 2003 9. Ref Elevations: KB: 29' Kuparuk River Field/ Kuparuk River Oil Pool AMOUNT PULLED 471860 471742 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BOTTOM N/A 1678' MD/ 1539' TVD N/A 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, CASING If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE CEMENTING RECORD 5988068 SETTING DEPTH TVD 5987900 TOP HOLE SIZE 8391' 3-1/2" 30'582 sx Class G, 326 sx Class G 9.3# 30' 8338' 30' 30' SUSPENDED Perforations: 9594-9624' MD and 5842-5861' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: 8509' SIZE DEPTH SET (MD) 16.4 bbls 15.8 ppg Cement below retainer, 9 bbls above retainer 8424-9624' MD 9851' 27' 5123' 62.5# 40# 108' 27' 8351' MD/ 5129' TVD PACKER SET (MD/TVD) 42" 12-1/4" 80 sx ArcticCrete Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 3644' L-80 By James Brooks at 8:06 am, Feb 21, 2023 Suspended 8/12/2022 JSB RBDMS JSB 022823 xGDSR-3/3/23 Permit to Drill Number / SundrySusp Service Kuparuk River Field/ Kuparuk River Oil Pool KRU 3S-21 Suspended 8/12/2022 203-031/ 322-152 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surfcae Surface 1678' 1539' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email: jill.simek@conocophillips.com Contact Phone:(907) 263-4131 Staff Well Integrity Engineer 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: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 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. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Suspended TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Signed for Jill Simek Digitally signed by Allen EscheteDN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.comReason: I have reviewed this documentLocation:Date: 2023.02.20 15:23:11-09'00'Foxit PDF Editor Version: 12.0.1 Allen Eschete Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cement Casing and OA to surface. 3S-21 10/17/2022 famaj General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / GEN 5 / 5M TREE CAP CONNECTION: TOP 5.75"" ACME W/3.5"" EUE 8RD THREAD 4/5/2003 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.9 3,643.8 2,602.1 40.00 L-80 BTC PRODUCTION 7 6.28 27.0 8,508.7 5,212.9 26.00 L-80 BTCM LINER 3 1/2 2.99 8,337.6 9,851.0 6,005.5 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.8 Set Depth … 8,391.0 Set Depth … 5,150.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.8 24.8 0.00 HANGER 8.000 FMC GEN 5 TUBING HANGER 3.500 512.3 510.0 10.24 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 8,268.0 5,086.1 58.30 GAS LIFT 5.968 CAMCO MMG 2.992 8,313.8 5,110.1 58.48 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 8,352.1 5,130.1 58.49 LOCATOR 5.000 BAKER G-22 LOCATOR SUB BAKER G-22 3.000 8,353.3 5,130.7 58.49 SEAL 3.980 BAKER GBH-22 CSG SEAL ASSEMBLY BAKER GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,501.0 4,131.1 56.99 PLUG Baker Hughes 3BB K1 CIBP (OAL = 1.98'), MOE @ 6052' RKB Baker Hughes 3BB K1 9/7/2022 0.000 7,025.7 4,415.8 56.08 PLUG Baker Hughes 3BB K1 CIBP (OAL = 1.98'), MOE @ 7026'7' RKB Baker Hughes 3BB K1 9/7/2022 0.000 8,297.0 5,101.3 58.47 CUT TUBING CUT AT 8297' RKB W/ 238 WELLTEC MECHANICAL CUTTER 8/19/2022 2.992 8,424.0 5,167.8 58.09 PLUG Pumped 25.4 bbls of 15.8 ppg cement. 16.4 bbls below retainer, 9 bbls above. 8/12/2022 0.000 9,200.0 5,598.5 53.17 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/28/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,268.0 5,086.1 58.30 1 GAS LIFT OPEN RKP 1 1/2 0.0 8/12/2022 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,337.6 5,122.5 58.48 TIEBACK 5.750 TIEBACK SLEEVE, LENGTH 13.39' 5.250 8,351.0 5,129.5 58.49 PACKER 7.000 BAKER ZXP LINER TOP ISOLATION PACKER w/ HR PROFILE BAKER ZXP 5.000 8,355.7 5,132.0 58.49 NIPPLE 5.530 BAKER RS NIPPLE w/ COLLARS BAKER RS 4.250 8,387.8 5,148.8 58.36 XO THREAD 5.000 4.000 9,750.8 5,941.0 50.29 LANDING COLLAR 3.500 BAKER LANDING COLLAR BAKER 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,332.0 6,482.0 4,037.3 4,120.7 9/12/2022 21.0 APERF 4.72" HSD, PowerFLow 4621, RDX (19g, 21 spf, 60° PHASE, API: 5.9 PEN, 0.83" EH). (9/11/22) 9,594.0 9,624.0 5,841.6 5,860.6 C-4, 3S-21 4/18/2003 6.0 IPERF 2.5" HSD PJ, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,142.0 6,502.0 3,932.5 4,131.6 Plug – Plug Back / Abandonment Plug 36 bbls 15.8 ppg HES Cement plug in production casing through fancy HydaWell tool. 9/14/2022 29 0 3 644 0 29 0 2 602 2 Surface String OA Downsqueeze 122 BBLs 15 8 ppg Class G 10/14/2022 IPERF; 9,594.0-9,624.0 CEMENT RETAINER; 9,200.0 PLUG; 8,424.0 PRODUCTION; 27.0-8,508.7 CUT; 8,297.0 PLUG; 7,025.7 PLUG; 6,501.0 APERF; 6,332.0-6,482.0 Plug – Plug Back / Abandonment Plug; 6,142.0 ftKB SURFACE; 29.9-3,643.8 Surface String Cement; 29.0 ftKB CONDUCTOR; 30.0-108.0 Plug – Plug Back / Abandonment Plug; 29.0 ftKB DTTMSTART JOBTYP SUMMARYOPS 4/30/2022 SUPPORT OTHER OPERATIONS DRIFT TBG DOWN INTO LINER W/ 2.72" DMY RBP DOWN TO 9200' RKB PERFORM INJECTIVITY TEST DOWN TBG UP TO 3 BPM @ 1400 PSI PERFORM INJECTIVITY TEST DOWN THE OA UP TO 1.5 BPM @ 1200 PSI. (SEE ATTACHMENTS FOR PUMP REPORT) READY FOR CTU PENDING WELL INTERVENTION ENGINEER REVIEW. 7/28/2022 SUPPORT OTHER OPERATIONS FUNCTION TEST BOP'S PUMPED 25.4 BBLS OF 15.8 PPG CEMENT PUMPED 16.4 BBLS BELOW RETAINER LAID IN 9 BBLS ABOVE RETAINTER JET TOP OF CEMENT TO 8165' POOH LAY F.P 2500; W/22 BBL DIESEL 7/31/2022 ACQUIRE DATA (Pre SW) DEGAS/LOAD IA FOR UPCOMING SW MITIA (COMPLETE) 8/1/2022 SUPPORT OTHER OPERATIONS (PRE STATE WITNESS) TAG TOP OF CEMENT W/ 2" BAILER @ 8798' RKB (633' DEEPER THAN PLANED TOC @ 8165'); MITT TO 1500 PSI (PASS). 8/5/2022 SUPPORT OTHER OPERATIONS MIRU FOR CEMENT TOP JOB LAID IN 7.3 BBLS OF 15.8 PPG CEMENT FROM 8789' TO 7900' RIH CLEAN OUT EXCESS CEMENT LEAVING CEMENT TOP AT 8165' FREEZE PROTECT WELL FROM 2500' W / 23 BBLS OF DIESEL SUPPORT OTHER OPERATIONS SUPPORT OTHER OPERATIONS 3S-21 Suspend Summary of Operations 8/11/2022 8/12/2022 (P&A PREP) FUNCTION TEST T & IC LDS/GNS (COMPLETE), T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), (STATE WITNESS) TAG TOP OF CEMENT W/ 2.5" BAILER @ 8424' RKB. MITT & CMIT TO 1500 PSI(PASS). PULLED DV @ 8268 RKB, CMIT - TxIA TO 2500 PSI (PASS) PUMPED 25.4 BBLS OF 15.8 PPG CEMENT PUMPED 16.4 BBLS BELOW RETAINER LAID IN 9 BBLS ABOVE RETAINTER JET TOP OF CEMENT TO 8165' TAG TOP OF CEMENT W/ 2.5" BAILER @ 8424' RKB TAG TOP OF CEMENT W/ 2" BAILER @ 8798' RKB (633'() DEEPER THAN PLANED TOC @ 8165' MIRU FOR CEMENT TOP JOB LAID IN 7.3 BBLS OF 15.8 PPG CEMENT FROM 8789' TO 7900' RIH CLEAN OUT EXCESS CEMENT LEAVING CEMENT TOP AT 8165' DRIFT TBG DOWN INTO LINER W/ 2.72" DMY RBP DOWN TO 9200' RKB PERFORM INJECTIVITY TEST MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 9857 ft MD Lease No.: ADL 0380107 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3644 Feet Csg Cut@ Feet Intermediate: 7" O.D. Shoe@ 8509 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 9851 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8391 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer 8509 ft 6469 ft 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Top of cement plug was tagged with slickline and a 3-inch bailer. The bailer was full of soft gritty material that looked and smelled like cement. A MIT to 1500 psi was performed; tubing and IA pre-test pressures were both 50 psi. They attempted to pressure tubing up to 1800 psi. At 1450 psi tubing and 100 psi IA psi, you could tell the well was losing fluid. Liquid Leak Rate of 0.8 bpm at 1450 psi was determined (5.3 bbls pumped). After shut in for 5 minutes, the tubing pressure fell to 1210 psi and IA remained at 100 psi. September 22, 2022 Bob Noble Well Bore Plug & Abandonment KRU 3S-21 CPA PTD 203-031, Sundry 322-429 none Test Data: F Casing Removal: John Hanson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-0922_Plug_Verification_KRU_3S-21_bn smelled like cement. A MIT to 1500 psi was performed; tubing and IA pre-test pressures were both 50 psi. They attempted to At 1450 psi tubing and 100 psi IA psi, you could tell the well was losing fluid. At 1450 psi tubing and 100 psi IA psi, you could tell the well was losing fluid. shut in for 5 minutes, the tubing pressure fell to 1210 psi At 1450 psi tubing and 100 psi IA psi, you could tell the well was losing fluid. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 9851 ft MD Lease No.: ADL0380107 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3644 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8509 Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 9821 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8391 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 6501 ft MD 6156 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 150 1810 1720 1685 IA 150 1810 1720 1685 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Top perfs at 6332 ft MD. 34-ft tool string with bailer used for tag - 210 lbs. Cement sample recovered from bailer shows solids. Pressure test (CMIT TxIA) with diesel; 2.1 bbls pumped, 1.6 bbls returned. Septembert 17, 2022 Sully Sullivan Well Bore Plug & Abandonment KRU 3S-21 CPAI PTD 2030310; Sundry 322-429 none Test Data: P Casing Removal: Ed Zemba Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2022-0917_Plug_Verification_KRU_3S-21_ss STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3S-21 JBR 09/22/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 This was initial BOP test after being stacked. High PSI 5000 psi. all tested well once they got the choke line oteco gasket fixed when doing the shell test. Test with 3 1/2" TJ 250psi low and 5000 psi high. Test went well. Rig in really nice shape with the work they had done to it. Test Results TEST DATA Rig Rep:Kelly Haug/Einer FleaglOperator:ConocoPhillips Alaska, Inc.Operator Rep:Andy Lundale/Dusty Pickw Rig Owner/Rig No.:Doyon 19 PTD#:2030310 DATE:9/2/2022 Type Operation:WRKOV Annular: 250/5000Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopKPS220902160510 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.3 MASP: 1440 Sundry No: 322-429 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 3 1/2"x6" VB P #2 Rams 1 Blinds 5K P #3 Rams 1 3 1/2"X6" VB P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5K P HCR Valves 2 3 1/8" 5K P Kill Line Valves 1 3 1/8" 5K P Check Valve 0 NA BOP Misc 1 4" Kill line de P System Pressure P3025 Pressure After Closure P1450 200 PSI Attained P27 Full Pressure Attained P161 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2520 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P19 #1 Rams P7 #2 Rams P14 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9 9 9 9 initial BOP test after being stacked. P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Contractor RepresentativeWell Permit to Drill # 2030310 Sundry Approval # 322-429Operation Inspection LocationWorking Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure PP Flow Rate Sensor P Operating Pressure PP Mud Gas Separator P Fluid Level/Condition PP Degasser P Pressure Gauges PP Separator Bypass NA Sufficient Valves PP Gas Detectors P Regulator Bypass PP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections P Blind Ram Handle Cover PP Reserve Pits NA Control Panel, Driller PP Trip Tank P Control Panel, Remote PP Firewall PP 2 or More Pumps PP Kelly or TD Valves P Independent Power Supply PP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment PP Flow Monitor PFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes NAHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line PFAILURES:0CORRECT BY:COMMENTSKRU 3S-21MUD SYSTEMKRU 3S-21Workover CLOSING UNITALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsKelly HaugAndy LundaleLocking Devices, RamsBOP STACKInspector Bob Noble accompanied me. Initial inspection after rig return to work (idle since 5/2020). The pits and piping are all new on Doyon 19. Well control and kill sheets were available. Well control training current. Rig is in really good working order.Kam St.John9/1/2022INSPECT DATEAOGCC INSPECTORDoyon 19DoyonCPAIMISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOORCHOKE MANIFOLD2022-0901_Rig_Doyon19_KRU_3S-21_ksj rev. 1-11-2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 9857 ft MD Lease No.: ADL 0380107 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3644 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8509 Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 9851 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8391 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer 9200 ft 8424 ft 7.1 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1680 1600 1580 IA 190 200 180 OA 260 260 280 Initial 15 min 30 min 45 min Result Tubing 210 240 240 IA 1660 1610 1600 OA 440 450 440 Remarks: Attachments: Brent Rodgers P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Suspension plug. Inspector Bob Noble and I arirved on location; talk with S/L unit operator then witnessed run in the hole with a bailer for plug tag. Pick up and set down 3 times after initial tag - call depth 8424 ft MD. MITT & MITIA went well. Bailer sample sample was mostly diesel with minimal cement slurry. August 12, 2022 Kam StJohn Plug Verification KRU 3S-21 ConocoPhillips Alaska Inc. 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D/Zh͘ Ϯϳ͘ Z/,ĂŶĚ>ƚŚĞϳ͟ĐĂƐŝŶŐƚŽĐŽŶĨŝƌŵŐŽŽĚĐĞŵĞŶƚ͘ Ϯϴ͘ ZDK͘ Žŝů;KŶĨŝƌƐƚϮŽǇŽƚĞKǁĞůůƐͿ Ϯϵ͘ D/ZhĂŐĂŝŶ͘ ϯϬ͘ WƵŵƉĐĞŵĞŶƚƉůƵŐŝŶƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐ͕ĂĐƌŽƐƐƉĞƌĨŽƌĂƚĞĚŝŶƚĞƌǀĂůƐĞĐƚŝŽŶĂŶĚƚŽƐƵƌĨĂĐĞ͘:ŽďŝƐƉůĂŶŶĞĚĨŽƌ ϮϰϵďďůƐĐĞŵĞŶƚ͘ ϯϭ͘ ZDK͘ WƵŵƉŝŶŐ ϯϮ͘ D/Zh͘ ϯϯ͘ WĞƌĨŽƌŵKĚŽǁŶƐƋƵĞĞǌĞƚŽƉůĂĐĞĐĞŵĞŶƚĨƌŽŵƐƵƌĨĂĐĞƚŽϯ͕ϲϰϰĨƚ<͘:ŽďŝƐƉůĂŶŶĞĚĨŽƌϭϮϯďďůƐŽĨĐĞŵĞŶƚ͕ ŝŶĐůƵĚŝŶŐĞǆĐĞƐƐ͘ ϯϰ͘ ZDK͘ tĞůůŚĞĂĚǆĐĂǀĂƚŝŽŶͬ&ŝŶĂůWΘ͗ ϯϱ͘ ŽŶĨŝƌŵƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐĂŶĚƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐǆƐƵƌĨĂĐĞĐĂƐŝŶŐĂŶŶƵůƵƐƉƌĞƐƐƵƌĞƐĂƌĞĂƚϬƉƐŝ͘ ϯϲ͘ EŽƚŝĨǇƚŚĞK'/ŶƐƉĞĐƚŽƌŽĨƚŝŵŝŶŐĨŽƌƐƵƌĨĂĐĞƉůƵŐǁŝƚŶĞƐƐĂŶĚŵĂƌŬĞƌƉůĂƚĞŝŶƐƚĂůůĂƚŝŽŶ;ƐƵďŵŝƚK'dĞƐƚ tŝƚŶĞƐƐEŽƚŝĨŝĐĂƚŝŽŶ&ŽƌŵϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨǁŝƚŶĞƐƐͿ͘ ϯϳ͘ ZĞŵŽǀĞƚŚĞƚƌĞĞ͕ŝŶƉƌĞƉĂƌĂƚŝŽŶĨŽƌƚŚĞĞǆĐĂǀĂƚŝŽŶĂŶĚĐĂƐŝŶŐĐƵƚ͘ ϯϴ͘ ǆĐĂǀĂƚĞĂŶĚƌĞŵŽǀĞǁĞůůŚĞĂĚĂŶĚĂůůĐĂƐŝŶŐƐƚƌŝŶŐƐĂƚϰĨĞĞƚďĞůŽǁŽƌŝŐŝŶĂůŐƌŽƵŶĚůĞǀĞů͘ ϯϵ͘ sĞƌŝĨǇƚŚĂƚĐĞŵĞŶƚŝƐĂƚƐƵƌĨĂĐĞŝŶĂůůƐƚƌŝŶŐƐ͘WĞƌĨŽƌŵĐĞŵĞŶƚ͞ƚŽƉŽĨĨ͟ũŽď;ƐͿŝĨƌĞƋƵŝƌĞĚ͘K'ǁŝƚŶĞƐƐĂŶĚ ƉŚŽƚŽĚŽĐƵŵĞŶƚƌĞƋƵŝƌĞĚ͘ ϰϬ͘ ^ĞŶĚƚŚĞĐĂƐŝŶŐŚĞĂĚǁͬƐƚƵďƚŽŵĂƚĞƌŝĂůƐƐŚŽƉ͘WŚŽƚŽĚŽĐƵŵĞŶƚ͘ ϰϭ͘ 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'RQRWFOLFNOLQNVRURSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZ WKHFRQWHQWLVVDIH )URP/RHSS9LFWRULD72*& 7R6LPHN-LOO:DUG'XVW\. 6XEMHFW.586DQG6$$EG 'DWH7XHVGD\$XJXVW$0 :ŝůů͕ ƉƉƌŽǀĂůŝƐŐƌĂŶƚĞĚĨŽƌƚŚĞƚƵďŝŶŐĐƵƚ͘ sŝĐƚŽƌŝĂ Victoria Loepp 6HQLRU3HWUROHXP(QJLQHHU 6WDWHRI$ODVND 2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ :WK$YH $QFKRUDJH$. :RUN 9LFWRULD/RHSS#DODVNDJRY CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov &ƌŽŵ͗^ŝŵĞŬ͕:ŝůůф:ŝůů͘^ŝŵĞŬΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕ƵŐƵƐƚϭϲ͕ϮϬϮϮϵ͗ϰϮD dŽ͗tĂƌĚ͕ƵƐƚǇ<фƵƐƚǇ͘tĂƌĚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖>ŽĞƉƉ͕sŝĐƚŽƌŝĂd;K'Ϳ фǀŝĐƚŽƌŝĂ͘ůŽĞƉƉΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ŽŶŬůŝŶ͕ŵǇфŵǇ͘͘ŽŶŬůŝŶΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖>ǇŽŶƐ͕<ĞůůǇ ф<ĞůůǇ͘͘>ǇŽŶƐΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх͖WĂĐŬĞƌ͕:͘ƌĞƚƚф:͘ƌĞƚƚ͘WĂĐŬĞƌΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗<Zhϯ^ͲϮϭĂŶĚϯ^ͲϬϲďĚ sŝĐƚŽƌŝĂ͕ ƐĚŝƐĐƵƐƐĞĚ͗ tŚŝůĞǇŽƵĂƌĞƌĞǀŝĞǁŝŶŐƚŚĞϯ^ͲϮϭĂŶĚϯ^ͲϬϲƐƵŶĚƌǇĂƉƉůŝĐĂƚŝŽŶƐ͕ŽŶŽĐŽWŚŝůůŝƉƐƌĞƋƵĞƐƚƐǀĞƌďĂů ĂƉƉƌŽǀĂůĨŽƌƚŚĞƚƵďŝŶŐĐƵƚƐƚĞƉŽŶƚŚĞϯ^ͲϮϭWΘƉƌŽĐĞĚƵƌĞ͕ƐŽǁĞĐĂŶŐĞƚƚŚŝƐƐƚĞƉĚŽŶĞďĞĨŽƌĞƌŝŐ ĂƌƌŝǀĂů͘ dŚĂŶŬƐ͕ ! 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"Pi Lu .a reCCWWWCeWDZCLI:efYE W W W W W W W W W W W E• u w > > > > > > > > > > > I. ---,EA ZMDMDDD = = =Y Y Y Y Y Y Y Y Y Y Y CC CC CC CC CC CC Q' 2 • a IIIw < < < Q Q < < < < <8Q O® LL CL LL LL CL LL LL CL LL LL CL LL UO CD 0 > > > > > > > > > > > c Y Y Y Y Y Y Y Y Y Y Y u 0 o NMI LIUI G,4 w 00 O 0) N O Co r N M •�' to X N _ ❑ N (n M co �' co Coc , Ifia) cc 8 0 0 0 0 '�` 0 0 0 0 0 0 r C E 0 . . . . . . . . . . ., , y � '* d d ❑ d o a (n (n e� (n (n v 5 m 00 E m E 00 0 0 0 0 0(J CON N F- F- a CI CI CIF- F- fn N C C C CO CC CI ❑ ❑ ❑ ❑ ❑ ❑ C C Cr X `^ m E (00 N O \ F- 0O O O O O O O o O O O C Nn O 0 O 0 0 0 O 0 O O O bA r- c0 V 8 00 N O O 4 4 •H t0 cN N h h )f) 1n c() co O) co � O 4) u. r O NIM N St N ti U) I.0 U) 0 N N O M 0 M 0 N N M M M O N G N N N N N N N N N N N 4 R < O M O M O) M O Q) Q) O O) al ,, RN O N O N 0 N N N N N 'y Q1 O O O O O O O O - OO O O O O O O O O O I CM en 1 0�0 C Y') try cA )S7 )f) U) O N O N fl. Fu •(p •aJ — 0) D.I- cn W Y OLL, OC C 0 on U ++ Q p L 2 to,a ■� Z 2 a a N o 0 0 0 N N N r Tt Y a) Y 00 r r r E W � +� (h Z F- C▪ O a (n (moo _, .� .itN 2 N O O 2 = _ ns a 0 n• Q O N J r N M M M M r y z 41 c6 •C C '� U n C aa)i rv'o (n .a ra o CM II-L) it 0 as • � \��y�� THE STATE Alaska Oil and Gas ti � o � f LAsKACommissionConservation Commission 7. A # � z 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 (4'ALAB/I'P Fax: 907.276.7542 www.aogcc.alaska.gov Roger Mouser Well Integrity Field Supervisor %WE© AllG 0 1 '1017, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-21 Permit to Drill Number: 203-031 Sundry Number: 317-334 Dear Mr. Mouser: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Commissioner DATED this y of July, 2017. RBDMS Lc JUL 2 7 2017 • • RECEIVED STATE OF ALASKA JUL 2 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION o 7/15� :1 / 7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon LI Plug Perforations H Fracture Stimulate LJ Repair Well H Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing H Other: Conductor Extensior0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 203-031 3.Address: Stratigraphic ❑ Service 0 , 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 501032045200 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Nk • rrt Will planned perforations require a spacing exception? Yes ❑ No M rtli KRU 3S-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ��J ADL0025544 • Kuparuk River Field/Kuparuk River Oil Pool r 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): EffectivvDe MD: Effective Depth TV: MPSP(psi): Plugs(MD): Junk(MD): 9,851' 6,006' 9' StV ' 2,480 N/A N/A Casing Length Size MD �'`+ TVD Burst Collapse Structural Conductor 78' 16" 108' 108' Surface 3,614' 9.625" 3,644' 2,602' Intermediate Production 8,482' 7" 8,509' 5,213' Liner 1,513' 3.5" 9,851' 6,006' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,594'-9,624' 5,842'-5,862' 3.500" L-80 8,352' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV.Nipple-Camco DS Nipple MD=512',TVD=510' Baker GBH-22 Casing Seal Assembly MD=8,353',TVD=5,131' 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 9/15/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ . GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned H 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@cop.com `�_I Contact Phone: (907)659-7506 Authorized Signature: i? 716401 Date:07/19/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3I7 - 33`-{ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes H No Subsequent Form Required: /0 — 1 04- RBDMS 1--(--JUL 2 7 2017 APPROVED BY Approved by:diel7 (� COMMISSIONER THE COMMISSION Date:'_15_/7 -ti a tix 7/2VT'-1-/z5-11 7 o I A� Submit Form and Form 10-403 Revised 4/2017 Alp C is valid for 12 months from the date of approval. attachmentss in Duplicate • • �✓ VED ConocoPhIIIIps JUL 2 0 2017 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 19, 2017 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3S-19, PTD 203-096 conductor extension. Please contact Roger Mouser or Roger Winter at 659-7506 if you have any questions. Sincerely, Roger Mouser/Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 3S-21 (PTD 203-031) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 19, 2017 This application for Sundry approval for Kuparuk well 3S-21 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 10". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Field Supervisor • KUP INJ 3S-21 ConocorPhillips fri Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm OMB) Ccrwcathdmp. 501032045200 KUPARUK RIVER UNIT INJ 66.08 2,555.35 9,851.0 ... rr� Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3S-21,1015/2016 6:14:34 PM SSSV:NIPPLE Last WO: 34.05 4/6/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,617.0 11/11/2016 Rev Reason:TAG pproven 11/15/2016 Casing Strings " I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND) Wt/Len(I...Grade Top Thread HANGER;24.8 1�'-1. 1 CONDUCTOR 16 15.062 30.0 108.0 1080 62.50 H40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I..Grade Top Thread SURFACE 95/8 8.835 29.9 3,643.8 2,602.1 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 27.0 8,508.7 5,212.9 26.00 L-80 BTCM Ll toCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 3 1/2 2.992 8,337.6 9,851.0 6,005.5 9.30 L-80 SLHT A' Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 8,337.6 5,122.5 58.48 TIEBACK TIEBACK SLEEVE,LENGTH 13.39' 5.250 CONDUCTOR;30.0-108.0- 8,351.0 5,129.5 58.49 PACKER BAKER ZXP LINER TOP ISOLATION PACKER w/ 5.000 HR PROFILE NIPPLE;512.3Nt 8,355.7 5,132.0 58.49 NIPPLE BAKER RS NIPPLE w/COLLARS 4.250 8,358.5 5,133.4 58.49 HANGER BAKER FLEXLOCK HANGER 4.440 8,368.6 5,138.7 58.49 SBE BAKER 20'SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt)1b/ft) Grade Top Connection TUBING 31/2 2.992 24.8 8,391.0 5,150.4 9.30 L-80 EUEBRDMOD Completion Details Nominal ID SURFACE;29.9-3,643.8-+ Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 24.8• 24.8' 0.00 HANGER I FMC GEN 5 TUBING HANGER 3.500 512.3 510.0• 10.24 NIPPLE I CAMCO DS NIPPLE w/2.875"NO GO 2.875 8,313.8 5,110.1 58.48 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 8,352.1 5,130.11 58.49 LOCATOR BAKER G-22 LOCATOR SUB 3.000 8,353.3 5,130.7 58.49 SEAL BAKER GBH-22 CSG SEAL ASSEMBLY 3.000 Perforations&Slots Shot --- Dens Top(ND) atm(TVD) (shots/I _ Top(ftKB) atm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn GAS LIFT;8,288.1 9,594.0 9,624.0 5,841.6 5,860.6 C-4,3S-21 4/18/2003 6.0 IPERF 2.5"HSD PJ,60 deg phase Mandrel Inserts St atl on Top(ND) Valve Latch Port Sire TRO Run NIPPLE;8,313.8 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1� 8,268.0 5,086.1 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 4/13/2003 I Notes:General&Safety End Date Annotation - Igggei 12/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 1'=_1 I Et LOCATOR;8,352.1 ri. SEAL;8,353.3 -I II',, aI PRODUCTION;27.0-,508.7 IPERF;9,594.0-9,624.0 - LINER;8,337.6-9,851.0 •• • Bettis, Patricia K (DOA) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Thursday,July 20, 2017 1:45 PM To: Bettis, Patricia K (DOA) Cc: NSK Well Integrity Supv CPF1 and 2; NSK Well Integrity Supv CPF3 and WNS Subject: RE: [EXTERNAL] KRU 3S-21 (PTD 203-031): Sundry Application Good afternoon Patricia, The current Effective depth for 3S-21 PTD 203-031 as of 5/15/2017 was: MD=9,615' and TVD=5,854'. Respectfully, Roger Mouser/Roger Winter CPAI WI Field supervisor Office (907) 659-7506 Cell (907)943-1055 N1927@ COP.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,July 20, 2017 10:53 AM To: NSK Well Integrity Field Supv<N1927@conocophillips.com> Subject: [EXTERNAL] KRU 3S-31 (PTD 203-031): Sundry Application Good morning Roger, For Form 10-403, please provide the current effective depth for KRU 3S-31 in both MD and TVD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,July 20, 2017 10:53 AM To: NSK Well Integrity Field Supv Subject: KRU 3S-31 (PTD 203-031): Sundry Application Good morning Roger, For Form 10-403, please provide the current effective depth for KRU 3S-31 in both MD and TVD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • 2. 3-a3� • Z5 WELL LOG TRANSMITTAL DATA LOGGED G /201'] PROACTIVE DIAGNOSTIC SERVICES, INC. M.K.BENDEPt To: AOGCC RECEIVED Makana Bender 333 West 7th Avenue MAY 2 5 2017 Suite 100 Anchorage, Alaska 99501 AOGCC(907) 793-1225 A RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) 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: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED JUN 0 9201? 1) Injection Profile 15-May-17 3S-21 Color Log /CD 50-029-20452-00 2) Signed : ..E:�N:�' �P ' Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(a MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFi les\Templates\Distribution\Transmittal Sheets\ConocoPhillips_Transmit.docx Image ¡:.. ~ject Well History File Cc,)er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d 03 - O~l Well History File Identifier Organizing (done) ~wo-sided 11I11111I1111111111 ~escan Needed I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner R'TCAN yz( Color Items: o Greyscale Items: DI,-AL DATA ~Diskettes, No. ~ o Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: NOTES: BY: Helen ('Maria ) D Other:: I Date: 5" &4 D5"ISI . I WID Project Proofing Scanning Preparation BY: Helen ~ ::l x 30 = ~D YVtJ + J I = TOTAL PAGES 'PI (Count dOEO not Ir ~Iude cover sh..et) 1/111 '':J Date: Õ d., Y- ~/sl r , ; , , I I Date:b ~tf b s Isl I BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: ~;l. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,/ YEp Helen ~ Date:~ ól" Y- YES Stage 1 If NO in stage 1, page(s) discrepancies were found: NO ".,. ,.--- VI A -:J, U0 Isl , v J..- NO BY: BY: Helen Maria Date: Isl IIIIIIIIIIIIJIIIIII 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: IsI Comments about this file: Quality Checked III "1111111" 1II11 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, August 11, 2010 Tim Regg ~~` f~~ i.~i J SUBJECT: Mechanical Integrity Tests P.I. Supervisor J 1 CONOCOPHILLIPS ALASKA INC 3S-21 FROM: Bob Noble KUPARUK RIV UNIT 3S-21 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~Jn~- Comm Well Name: KUPARUK RIV UNIT 35-21 Insp Num: mitRCN100809161258 Rel Insp Num: API Well Number: 50-103-20452-00-00 Permit Number: 203-031-0 Inspector Name: Bob Noble Inspection Date: 8/'7/2010 Packer Depth Pretest Initial l5 Min. 30 Min. 45 Min. 60 Min. Well 3s-21 ~ Type Inj. ~' ~ TVD 5129 IA s6o laao ~ laoo 17so ' P.T.D 2030310 TypeTest SPT Test psi 1840 QA ~ 500 600 600 600 Interval aYRTST p~F, P ~ Tubing 2350 2350 2350 2350 Notes: ~./li~n, (~ j C~' -~25-~- (~~ps; '~,. ~.._ ~- f'.1i' Wednesday, August 11, 2010 Page 1 of 1 • • ~. __ ill 03101 /200.8 DO NOT PLACE _~- ~~'"~ ,~~ _ .. _ __ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\C~rPgs_Inserts~Microfilm Marker.doc . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 3S-21, 3S-22, 3S-23, 3S-24. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-21: urC- 803 -031 ~ ¡'-l3(d:, Digital Log Images: 50-103-20452-00 1 CD Rom 3S-22: U:r:C- ~ó3-o II ~ ~ 14./30'1} Digital Log Images: 50-103-20446-00 1 CD Rom 3S-23: <9ð3-ö4S- it 1L.(3~ Digital Log Images: t-.....A...WED JAN 3 0 2007 50-103-20453-01 ~.." 1 CD Rom 3S-24: C)ó3 -O~ tlILf3(¿,'t- Digital Log Images: 50-103-20456-00 1 CD Rom c.lt---- trllft...... MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation CommissIOn TO: Jim Reggp €4 ß!3¿)uéç; P.I. Supervisor f<- // J DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 35-21 KUPARUK R1V UNIT 3S-21 ;3' 02> I t}..9 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: ~~ P.I. Suprv, I . Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3S-21 API Well Number 50-103-20452-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060829122618 Permit Number: 203-03 1-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S-21 Type Inj. w TVD 5130 IA 1250 2510 2450 I 2440 2440 P.T. 2030310 TypeTest SPT Test psi 1500 OA 700 800 780 750 750 Interval 4YRTST P/F P Tubing 1750 1750 1750 1750 1750 Notes 1.4 BBLS diesel pumped. I well house inspected; no exceptions noted. SCANNED S£P 0 820GB Wednesday, August 30, 2006 Page I of I . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 :'r ",. ~~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 d03- 03) 3S-~J Uf¡ v Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18, 2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~f~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field August 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 12, 2004 I :~ (67 4--- RE: MWD Formation Evaluation Logs 3S-21, AK-MW-2323379 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 0C' h l -ðS-J:(): ::J J - .-7 Digital Log Images 50-103-20452-00 {)th7_Ã3f L) J (),- ( 1 CD Rom f' I, Schlumbel'gef1 RECEIVED NO. 3638 Schlumberger -DCS ,JAN 0 9 2006 2525 Gambell Street, Suite 400 Company: Anchorage, AK 99503-2838 A TTN: Beth -\la~Ka Cd '?x Gas Cons. Commission And!crage Field: Well Job# Log Description Date BL 2D-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE WIDEFT 12/27/05 1 2U-08 11166750 PROD PROFILE W/DEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 30-09 11166737 LDL 12/17/05 1 3S-21 ~'?ó-3-()? \ 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE WIDEFT 12/26/05 1 30-09 11144055 LDL 12/23/05 1 2V-01 11144056 INJECTION PROFILE 12/24/05 1 SIGNED~dlillOO1-¡ 5(;Át\\NED JAN :¡¡ 1 2005 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color ,-.,-,," CD '- I ~ M~ ~t.L\ 'Ý DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Current Status WAGIN 5()u¿ )/ ~ÁÒ03 API No. 50-103-20452-00-00 ~ ---- - Permit to Drill 2030310 Well Name/No. KUPARUK RIV UNIT 3S-21 Operator CONOCOPHILLlPS ALASKA INC MD 9857- TVD 6009 ./ Completion Date 4/18/2003 ,,/ Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes, Dens-Neut, SCMT cement bond log Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Rpt Log Log Scale Media Run No 1 Name Directional Survey Rpt Directional Survey ~/ Cement Evaluation 5 Blu ED 0 11653 UB V~I irïcatlon G Y\. fw t\. <{ CM!? 5~Ô f\ðØ 4 I I F Rpt LIS Verification 4 ~/ Pressure 5 Blu ED 0 Directional Survey J-IY -- 0 11653 LIS Verification ED 0 Directional Survey Rpt LIS Verification Well Cores/Samples Information: Name IntelVal Start Stop Received Sent Directional SU~~ c - - - (data taken from Logs Portion of Master Well Data Maint) -- IntelVal OH/ Start Stop CH Received Comments 358 9857 Open 4/29/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/26/2003. 0 358 Open 4/29/2003 GYRO 8360 9735 Open 5/8/2003 3630 8487 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 3630 8487 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 9325 9710 Open 5/8/2003 0 358 Open 4/29/2003 GYRO 3630 8487 Open 4/29/2003 REPLACED BY NEW ~- DATA RCVD 07/24/2003 358 9857 Open 4/29/2003 3630 8487 Open 4/29/2003 REPLACED BY NEW DATA RCVD 07/24/2003 Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030310 Well Name/No. KUPARUK RIV UNIT 35-21 Operator CONOCOPHILLlPS ALASKA INC MD 9857 TVD 6009 Completion Status 1-01L Current Status WAGIN UIC Y Completion Date 4/18/2003 ADDITIONAL INFORMÆION Well Cored? y\Ji.;h Daily History Received? (J;) N Formation Tops 01 N ,- Chips Received? Y 1 N Analysis Received? ~ Comments: Compliance Reviewed By: h Date: API No. 50-103-20452-00-00 '-' / C( II&; ~ r- -- ,.' , , c' I ~ Operél.tions' P~rf~:imed: " , 'Abanpqn i ',.. ·1 \ STATE OF ALASKA ) ALA .,.{ OIL AND GAS CONSERVATION COMMISSi ' REPORT OF SUNDRY WELL OPERATIONS .,:,:.:0,: fYJ~¡jj) -10 WA'r . p¿riorate 0 ,', , , ,,::Vari~nqe, ,.0 ~n~ular Disp., 0 ·.·c ".;.,,: ·i,,: ·.",':',::1.: ,'r·. ';;:'.,::-. '.:1' ..-' , ¡ n C . \=.1, ;: ~. 5. Permit to Drill Number: 203-031 I 6. API Number: 50-103-20452-00 P. O. Box 100360 7. KB Elevation (ft): RKB 57' . ;: ;~:.:' ~:[ : r : :. ;~,:;¡ :... .. ";. . c· , .. . ·1:. . .:.,.,., 9. Well Name and Number: 3S-21 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10, Field/Pool(s): Kuparuk Oil Pool Total Depth measured 9857' 6009' feet feet feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Length Size MD TVD Burst Collapse 108' 3616' 8483' 1514' 16" 9-5/8" 7" 108 3644' 8509' 9851' 108' 2602' 5213' 6006' 3-1/2" Perforation depth: Measured depth: 9564-9624 true vertical depth: 5842-5861 RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8391' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 512' '12; Stimulationor:~è"fTlent sque$ze ~!Jmmáry: ." , ' ',lriterValstrëated(me~~Qre~) , , ',N/A , T.r.~atment descrîp~.iþns,inçIU(Un~ vOlu,mes lJsecj ~,nd final,pressure~ , pnor to well operéJ.tion S,ubsequent to, operation, " 14. Att~chmerits Copies of Logs 'and Survêys ,run _ ,Ae'pré~él)tative O~ny' Averåge Pr<;>dùc,ion or- lrijeêtip~ Data I " ' :,Gas~Mcf I ':Water-Bbl ," ' " ..,' CasÎna:Pre-s~ur!3 "Tubinqpr~ss~J're: 204, ' ' "1~ØO, ,224 ' :,:3254 1"6QO' '111,8 15. Well CI~ss after proposed work: , .' E~plor~tory , 0 Development 0 Service, 0 16. ,Well Status after proposed wórk: oilD GasD WAG 0 GINJ,D WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ,: " Oil-Bbl , ,726 ..13,' Daily Report of Well Operations_X WDSPLD Cdntact Jeff Spencer @ 659-7226 p~nted NamjJ ¡f R~rt D¡fþtfstens7{l Signature r~~~ Production Engineering Technician 659-7535 Date I ;2/ø RI3[IIS Bfl DEC ~ 4003 ORIGINAL SUBMIT IN DUPLICATE Form 1 0-404 Revised 2/2003 · .~" 11/24/031 Cômmê,¡'¢$d ::WAØ:::EP.R:;lbjèÞ.tiqrf::/:"" :;:"":::': ';'~:: ""''',, Date Event Summary ) 3S~1 ) , DESCRIPTION OF WORK COMPLETEú ,. SUMMARY S ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~û 1~~\1I3 DATE: November 29,2003 P.I. Supervisor -( l SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 3S Pad FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Well 35-21 Type Inj. P.TD. 2030310 Type test Notes: Pretest OA psi. 800 Well Type Inj. P.TD. Type test Notes: Well P.TD. Notes: Well P.TD. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Type Inj. Type test Type Inj. Type test Type Inj. Type test No failures witnessed. M.I.T.'s performed: 1 Attachments: MIT report form 5/12/00 L.G, Packer Depth Pretest Initial S TV.D. 5130 Tubing 2300 2300 P Test psi 3000 Casing 1100 3000 Pressure during test 940 .5 BBL pumped TV.D. 7869 Tubing P Test psi 2000 Casing 15 Min. 30 Min. 2300 2300 Interval I 2960 2940 P/F .e Interval P/F Interval P/F Interval P/F Interval P/F TV.D. ' Tubing Test psi Casing T.V.D. Tubing Test psi Casing TV.D. Tubing Test psi Casing Type Test M= Annulus Monitoring P= Standard Pressure Test " ~= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details Number of Failures: º Total Time during tests: 4 hrs. cc: 2003-1129_MIT _KRU_3S-21.Jc.xls 12/3/2003 ) y ConocoPhillips Ala8ka P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ') Fi~CSJ _ C.' 111l:D 4I9I,t¡¡Q1¡&Ga, 0 ? (00) ;g Con. ~~, Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surtàce casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as noti:fication that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. ;;; ~¡ MJ:¿¡ /' ConocoPhillips Problem Well Supervisor Attachment :r:.+ '\ ~ rv!:.)~ «. ~,~(""\. ~"" ~,,-ct ~~\-. +0 t, ~\\ 'o'->...c..~" c.M~ç b~~~ ~~~ ":,~~..:I \ \...., ~<t. ""«. ,,~~ .I.¡~ S"'~. Å \ \ oç. -\-~ "T~ <...1' ~-\-'" s ~~ \:)G:..t"'j ~Q..0l\ ~\....G: ~û~~... \--..J 0 Çù ,..\- ~~ \ Ct.. c...~ \ 0 '" t"\Q..ct. ~<J..' '{ J/-.)!.'Y'f7lJ Á - Ö ~ ' ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well TOC Volume Sacks Name PTO# Type ft BBL8 Cement 38-03 2030910 Prod 8 0.6 3.6 38-07 2021870 Prod 8 1.5 9.1 38-09 2022050 Inj 14 2.5 15.1 38-10 2022320 Prod 12 1.5 9.1 38-14 2022210 Inj 3 1.5 9.1 38-15 2022540 Prod 8 0,8 4.8 38-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 38-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3,0 38-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0,3 1.8 ) i ) P-ø3 ... D.ò ) \ \ (p'b3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West ihA venue, Suite 100 Anchorage, Alaska June 03, 2003 RE: MWD Fonnation Evaluation Logs 3S-21, AK-MW-2323379 1 LDWG fonnattedDisc with verification listing. llPI#: 50-103-20452-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVED D ~UL 24 2003 ~o AlaS:~ & Gas Cons. Commission Signed: Ant.'horage Note: This Data Replaces Any Previous Data For We1l3S-21. SchluDlbepger NO. 2765 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 05/05/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color 3S-21 ri¡)~1--03 / SBHP SURVEY 04/18/03 1 1B-08A J q 7'/~ I INJECTION PROFILE 04/17/03 1 3S-09 . Q.;)~ 0$ INJECTION PROFILE 04/07/03 1 3S-10 d~- 3;;J PRODUCTION PROFILE 04/08/03 1 1G-13 ~ - J~O PRODUCTION PROFILE 04/09/03 1 3S-21 ()3~~ SCMT 04/18/03 1 1C-174 ~3-- . '-Î 23113 USIT 04/01/03 1 1G-03 J ~-141 INJECTION PROFILE 04/24/03 1 1C-135 ~ ð/- d-~n PRESS/TEMP SURVEY 04/23/03 1 / '-/;-'- SIGNE~~Ú~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk '-.~ CD ,~. RECEIVED MAY 08 2003 AI_ OH & Gas Cons. Commiseion Anchorage ) STATE OF ALASKA ) ~~Jv.Þe ' ALASKA OIL AND GAS CONSERVATION COMMISSION 1a.w~s~~iI¡-L C?s~LE!u~~~ O~n~=EO~~:~TI2GND RE~~~~sAND LOG 20AAC 21;>.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions 1 Other _XX Pre-Produced Injector Service 0 Stratigraphic Test 0 2. Operator Name: S ð «.. \... 12. Permit to Drill Number: 5. Date Comp., usp., Iv pY or Aband.: Aprilj(,2003 6. Date Spudded: March 21,2003 7. Date TO Reached: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2551' FNL, 1207' FEL, Sec. 18, T12N, R8E, UM At Top Productive Horizon: 2196' FSL, 573' FEL, See, 24, T12N, R7E, UM Total Depth: 2030' FSL, 690' FEL, Sec. 24, T12N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476052 y- TPI: x- 471860 y- Total Depth: x- 471742 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res, Dens-Neut, SCMT cement bond log 22. CASING SIZE WT. PER FT. GRADE 16" 62.5# B 9.625" 40# L-80 7" 26# L-80 3.5" 9.3# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3644' Surface 8509' 8338' 9851' 5993865 5988068 5987900 Zone-4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 9594' - 9624' MD 5842' - 5861' TVD ,,\1..,,'-.,".....'-',."'......,.......,.._. i {~.: [\/ œ~.TE .$-LL__~~ .¡ ~'~'3:if'!::ID 1 "¡:; :\~ ¡ .-......-- . _......~,.- :, ~" ',,', "".,a..:o..',",' .'.c.......M ..'.'··",¡;,.-.:...t",·.n/; 6 spf , "'~Il' '.ijÌ:"" ''''Þ. 25. 1·\:- ',' ,.,~': . ~ . .., ;:' . . ¡.~~~.." :~:.,..: . April 3, 2003 8. KB Elevation (ft): RKB 29' 157' AMSL 9. Plug Back Depth (MD + TVD): 9751' MD 15941' TVD 10. Total Depth (MD + TVD): 9857' MD I 6009' TVD 11. Depth where SSSV set: Land Nipple @ 512' 19. Water Depth, if Offshore: N/A feet MSL 203-031/303-107 13. API Number: 50-103-20452-00 14. Well Name and Number: 3S-21 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25544 17. Land Use Permit: ALK 2639 20. Thickness of Permafrost: 1678' MD 42" 80 sx ArcticCrete CEMENTING RECORD AMOUNT PULLED HOLE SIZE 582 sx Class G & 326 sx Class G 169 sx Class G 12,25" 8.5" 6.125" 315 sx Class G 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 8391' PACKER SET (MD) 8351' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. Date First Production April 24, 2003 Date of Test Hours Tested 5/4/2003 6 hours Flow Tubing Casing Pressure press. 261 psi not available 27. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Pre-Produced Injector Production for OIL-BBL GAS-MCF 196 27 OIL-BBL GAS-MCF 744 176 CORE DATA Test Period n> Calculated 24-Hour Rate -> W A TER-BBL o W A TER-BBL o CHOKE SIZE GAS-OIL RATIO 236 100 OIL GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". R E eEl V ED RIBDI\4Is BFl Form 10-407 Revised 2/2003 NONE . 7'?OO~ ~ t:' CONTINÔR~VG~ ÑAL MAY 0 7 7003 Alaska Oil & Gas Cons. Commission Anchorage Submit in duplicate 28. ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 3S-21 Kuparuk C Kuparuk D 9590' 9590' 5839' 5839' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Lowry @ 265-6869 Printed NamA R. Thomas Signature .... ~ <....~. \. ~ Title: -Etone Kuparuk Drilling Team Leader Date 5"/6(01 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: list all test information. If none, state "None". Form 10-407 Revised 2/2003 ') ) Legal Well Name: 3S-21 Common Well Name: 3S-21 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES · ···...Date Hours. Code ·Sub. Code 3/20/2003 08:00 - 19:00 11.00 MOVE MOVE MOVE 19:00 - 00:00 5,00 MOVE RURD RIGUP 3/21/2003 00:00 - 04:00 4.00 DRILL OTHR RIGUP 04:00 - 04:30 0.50 DRILL OTHR RIGUP 04:30 - 06:00 1.50 DRILL PULD RIG UP 06:00 - 09:00 3.00 DRILL PULD SURFAC 09:00 - 10:00 1.00 DRILL RIRD SURFAC 10:00 - 00:00 14.00 DRILL DRLG SURFAC 3/22/2003 00:00 - 17:30 17.50 DRILL DRLG SURFAC 17:30 - 18:45 1.25 DRILL CIRC SURFAC 18:45 - 21 :30 2.75 DRILL TRIP SURFAC 21 :30 - 00:00 2.50 DRILL DEQT SURFAC 3/23/2003 00:00 - 03:30 3,50 DRILL TRIP SURFAC 03:30 - 08:45 5.25 DRILL DRLG SURFAC 08:45 - 09:00 0.25 RIGMNT OTHR SURFAC 09:00 - 16:30 7.50 DRILL DRLG SURFAC 16:30 - 19:30 3.00 DRILL CIRC SURFAC 19:30 - 00:00 4.50 DRILL TRIP SURFAC 3/24/2003 00:00 - 02:00 2.00 DRILL PULD SURFAC 02:00 - 03:30 1.50 CASE RURD SURFAC 03:30 - 03:45 0.25 CASE SFTY SURFAC 03:45 - 11 :30 7.75 CASE RUNC SURFAC 11:30 -12:15 0.75 CASE CIRC SURFAC 12:15 - 13:00 0.75 CASE RURD SURFAC 13:00 - 14:30 1.50 CEMENT CI RC SURFAC 14:30 - 18:00 3.50 CEMENT PUMP SURFAC Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: Moved rig from 3S-08 to 3S-21. Accepted rig @ 1900 Hrs. Nipple up Diverter. Modify riser and Nipple up Diverter. Function tested Diverter. RU to run Gyro surveys. Picked up and made up BHA. Checked Diverter and Riser for leaks, tested lines to 3500 psi. Drilled and surveyed 12 1/4" Directional hole from 108' to 1095' ART 3.01 Hrs. AST 6.41 Hrs. Up Wt. 75K Dn 65K Rt 75K. Torque off btm 3K on btm 4K. Drilled and surveyed 12 1/4" Directional hole from 1095' to 2616'. AST 7.87 Hrs. ART 4.19. SW UP 95 K Dn 73 K Rot 80 K. Torque Off Btm 4000 On Btm 7000. Unable to control angle or direction. Set back 1 stand and CBU X 2. POOH to check BHA. Inspected Mud Motor, Bit, and MWD. Found Internal components in MWD had come loose and shifted Toolface 180 Deg. Changed out MWD module and Picked up Motor and same bit. Orient MWD, Made up BHA and RIH to 2616'. took check shots at 1568' and 2137'. Washed last stand to bottom with no fill. Drilled 12 1/4" Directional hole from 2616' to 3044'. AST 1.4 Hrs. ART 2.1 Hrs. Cleaned pump suction screens on both pumps. Plugged with Materail used in Sweeps. Drilled 12 1/4" Directional hole from 3044' to 3655'.(2610' TVD) AST .53 Hrs. ART 2.34 Hrs. St Wt Up 108 K Down 90 K Rot. 90 K. Torque Off btm 5000 On btm 8000 to 9000 Ft Lbs. Pumped Sweep and Circulated and conditioned mud to lower Vis and Wt. Flow checked well, Blew down Top drive, and POOH SLM, Spent a lot of time cleaning clay off of drill string, all of it was coated. Laid down BHA and cleaned up floor. Rigged up casing crew. Pre job safety meeting. Ran 95 Jts 9 5/8" 40 # L-80 BTC Casing. Circulated every 1000'. Float shoe @ 3644' Float collar @ 3563'. Circulated. Rigged down Franks Circulating tool and RU Dowell. Circulated and conditioned mud. Pumped 5 Bbls CW100, Tested lines to 3500 PSI, Pumped 45 Bbls CW100 and dropped bottom plug, pumped 50 Bbls Mudpush 10.5 PPG followed by 444 Bbls lead mixed at 10.7 PPG. cement to surface. Mixed and pumped 130 Bbls of tail 12 PPG dropped top plug and Dowell displaced with 21.5 Bbls wash water followed by 250 Bbls mud displaced with rig pump at 7 BPM. Plug bumped with 1000 PSI and floats held. Good returns and worked pipe throughout job Wt. up 180 K down 110 K. 269 Bbls cement to surface. CIP 1743 Hrs. 3/24/03. FS @ 3644' FC @ 3563'. 1.50 CEMENT RURD SURFAC Rigged down Dowell and flushed stack. 1.00 CEMENT RURD SURFAC Rigged down casing crew and changed bales. 2.00 CASE NUND SURFAC Nipple down Diverter and Riser. 1.50 CASE NUND SURFAC Nippled up FMC Speed Head and tested. Nipple up BOP. 3.00 WELCTL NUND SURFAC Nippled up BOP and tested metel to metel seal. 3/25/2003 18:00 - 19:30 19:30 - 20:30 20:30 - 22:30 22:30 - 00:00 00:00 - 03:00 Printed: 4/24/2003 4:19:36 PM ) ) . q()noC?o~hilljþs'~laska ., Qper¡a~i;OllS$Umrna~Y8eport ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-21 38-21 ROT - DRILLING N 1268@ ppco.com Nabors 7ES Hours...>Code ,,~uþ. , ....., .. ,'. ..... ·Code Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: .' De$þription ofOperati()l'1s 0.50 WELCTL BOPE SURFAC Rigged up to test BOP and set test plug, Opened Annulus valve. 4.00 WELCTL BOPE SURFAC Tested Hydrill to 250/3500 psi. Tested Top Rams, IBOP, Choke and Kill valves, Lower rams, Lower IBOP, Floor Safety Valves, and Blind Rams to 250/5000 psi. Tested VBR with 7" casing. Tested Accumulator System. John Spaulding waived witiness of test. Rigged down test equipment and set wear bushing. Picked up and stood back 28 stands of drill pipe. Picked up and RIH BHA. RIH with HWDP and picked up and RIH 81 Jts of Drill pipe + one stand from Derrick, Tagged cement @ 3554'. Circulated and rigged up to test casing, Tested casing to 2500 psi for 30 min. Cleaned out down to FC at 3563', Circulate out thick mud. Drilled out shoe track and cleaned out rat hole. Drilled 8.5" hole from 3655' to 3675'. Up Wt 140 K Down 70 K Rot 90 K Torque off btm 9000 FP On btm 9000 FP. ART.1 Jars 55.1 Hrs. Circulated while rigging up to displace mud system. BOP Drill. Circulated while preparing pits for displacement. Displaced well with 8.8 PPG LSND mud. Performed FIT to 18.1 PPG EMW. Drilled 8.5" Directional hole from 3675' to 3871'. ART 1.05 Hrs. Lost pump pressure. Cleaned pump suctions and reprimed pumps. Drilled 8.5" Directional hole from 3871' to 5013'. ART 5.81 Hrs. AST 1.09 Hrs, Up Wt 155 K Down 85 K Rot 95 K. Torque Off Btm 9000 On Btm 10000 FP. Pumped Hi Dense Baralift sweep to lower ECD. Drilled 8.5" Directional hole from 5013' to 5584'. ART 3.83 Hrs. Backreaming and pumping Hi Dense Barafiber sweeps. Control Drilling to lower ECD. Up Wt 165 K Down 76 K Rot 105 K. Torque Off Btm 10000 On Btm 10000 - 11000 FP. 16.25 DRILL DRLG INTRM1 Drilled 8.5" Directional hole from 5584' to 7010'. ART 9.32 AST .78 TD RPM 100 - 105 WOB 10 - 15 K Up Wt 185 K Down 90 K Rot 115 K Torque Off Btm 12,000 On Btm 12,000 FP. 4.50 DRILL CIRC INTRM1 Partial lost returns. Flow reduced from 32% to 22%. Hole static with pumps off. Pumped 40 Bbl. pill with 20 PPB LCM and circulated @ 60 SPM staging up to 135 SPM while monitoring losses from 94 BPH to 184 BPH (Pumped 2 nd 40 Bbl pill with 40 PPB LCM while staging) then declining to 20 BPH after 2 nd LCM pill . 2.75 DRILL DRLG INTRM1 Drilled 8.5" Directional hole from 7010' to 7295' with losses of 30 to 70 BPH. ART 1.25 Hrs. AST .45 Hrs. TD RPM 100 WOB 10 to 20 K. Up Wt 210 K Down 87 K Rot 125 K Torque Off Btm 15000 On Btm 15000 FP. Started drilling with 450 GPM and loss of 30 BPH. Worked GPM up to 500 and loss went to 70 BPH. While drilling mixing 2 PPB Baracarb 150 + Barafiber to active system. Loss while drilling @ 70 BPH. Spotted 40 Bbls LCM Pill with 40 PPB LCM. Total loss for day 529 Bbls. Drilled 8.5" Directional hole from 7295' to 7863'. ART 2.84 Hrs. AST 1.8 Hrs. TD RPM 100 WOB 10 -15 K. Up Wt 230 K Down 95 K Rot 130 Torque Off Btm 16 K On Btm 16 - 17 K. GPM 470 loss -20 BPH. Circulated and monitored well. Increased pump rate to 550 GPM losses 100 BPH, decreased rate to 500 GPM losses declined to 22 BPH, reduced rate to 412 GPM and started getting some of the lost mud 3/25/2003 03:00 - 03:30 03:30 - 07:30 07:30 - 08:30 1.00 WELCTL BOPE SURFAC 08:30 - 13:00 4.50 DRILL PULD SURFAC 13:00 - 17:00 4.00 DRILL PULD SURFAC 17:00 - 21 :00 4.00 DRILL TRIP SURFAC 21 :00 - 21 :30 0.50 DRILL CIRC SURFAC 21 :30 - 22:15 0,75 CASE MIT SURFAC 22:15 - 23:00 0.75 DRILL CIRC SURFAC 23:00 - 23:30 0.50 DRILL OTHR SURFAC 23:30 - 23:40 0,17 DRILL DRLG SURFAC 23:40 - 00:00 0.33 DRILL CIRC SURFAC 3/26/2003 00:00 - 01 :00 1.00 DRILL CIRC SURFAC 01 :00 - 02:00 1.00 DRILL CIRC SURFAC 02:00 - 03:00 1.00 DRILL FIT SURFAC 03:00 - 05:00 2.00 DRILL DRLG INTRM1 05:00 - 05:30 0.50 RIGMNT OTHR INTRM1 05:30 - 16:30 11.00 DRILL DRLG INTRM1 16:30 - 17:00 0.50 DRILL CIRC INTRM1 17:00 - 00:00 7.00 DRILL DRLG INTRM1 3/27/2003 00:00 - 16:15 16:15 - 20:45 20:45 - 23:30 23:30 - 00:00 0.50 DRILL CIRC INTRM1 3/28/2003 00:00 - 08:00 8.00 DRILL DRLG INTRM1 08:00 - 11 :00 3.00 DRILL CIRC INTRM1 Printed: 4/24/2003 4: 19:36 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-21 3S-21 ROT - DRILLING N1268@ppco.com Nabors 7ES . Ðate From~ To HOiJrs<c;ódecfgle Phase 3/28/2003 3.00 DRILL 4.00 DRILL 2.50 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL CIRC INTRM1 WIPR INTRM1 TRIP INTRM1 CIRC INTRM1 TRIP INTRM1 CIRC INTRM1 CIRC INTRM1 TRIP INTRM1 CIRC INTRM1 OTHR INTRM1 08:00 - 11 :00 11 :00 - 15:00 15:00 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 3/29/2003 00:00 - 04:00 4.00 DRILL OTHR INTRM1 04:00 - 04:45 0.75 DRILL CIRC INTRM1 04:45 - 05:15 0.50 DRILL TRIP INTRM1 05: 15 - 08:00 2.75 DRILL REAM INTRM1 08:00 - 09:00 1.00 DRILL TRIP INTRM1 09:00 - 16:00 7.00 DRILL DRLG INTRM1 3/30/2003 16:00 - 19:00 3.00 DRILL CIRC INTRM1 19:00 - 20:30 1.50 DRILL WIPR INTRM1 20:30 - 22:30 2.00 DRILL CIRC INTRM1 22:30 - 23:30 1.00 DRILL OBSV INTRM1 23:30 - 00:00 0.50 DRILL TRIP INTRM1 00:00 - 07:00 7.00 DRILL TRIP INTRM1 07:00 - 09:00 2.00 DRILL TRIP INTRM1 09:00 - 10:00 1.00 DRILL TRIP INTRM1 10:00 - 13:00 3.00 CASE RURD INTRM1 13:00 - 13:15 0.25 CASE SFTY INTRM1 13:15 - 20:30 7.25 CASE RUNC INTRM1 20:30 - 21 :00 0.50 CASE CIRC INTRM1 21 :00 - 23:30 2.50 CASE RUNC INTRM1 23:30 - 00:00 0.50 CASE CIRC INTRM1 00:00 - 00:30 0.50 CASE CIRC INTRM1 00:30 - 02:45 2.25 CASE RUNC INTRM1 02:45 - 03:15 0.50 CASE RURD INTRM1 03:15 - 04:15 1.00 CASE CIRC INTRM1 04:15 - 06:00 1.75 CEMENT PUMP INTRM1 3/31/2003 Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: . '" . . Description of Operations back. Reduced pump rate to 150 GPM no loss. POOH to Casing shoe and monitor well. RIH to 7768'. Broke circulation slowly and CBU X 2. POOH to 7010'. Circulated while finished mixing HYRDO-PLUG pill, PJSM. Displaced Hydro-plug from 7010' to 6502', POOH from 6630' to 6060'. Circulated 50 Bbls at 5 BPM. Closed Hydrill and squeezed 20 Bbls of plug to zone @ 2 BPM Formation broke at 569 PSI and pumped in at 515 PSI. Wait 10 min. Pressure 238 PSI, Continue squeeze with 2 Bbls @ 1.5 BPM Pump in @ 450 PSI bled back to 237 PSI in 10 Min, Pumped 6 Bbls @ 1.5 BPM 445 PSI bleed back to 211 PSI in 10 min. Pumped 7 Bbl @ 1.5 BPM at 411 PSI. Total pumped in 35 Bbls. Held pressure on squeeze job started at 218 and bled to 50 PSI. Rotated pipe every 15 min. Rotation was getting more difficult by 0330. Bled off pressure no fluid return. Opened Hydrill. Staged up pump rate to 450 GPM circulated. LCM was at surface after 204 Bbls pumped. No down hole losses. RIH to 6440'. Washed down from 6440' to 7104' pumping 8 BPM. RIH to 7763' and washed last stand to 7868'. Drilled 8.5" Directional hole from 7868' to 8517'. ART 3.7 Hrs. AST .75 TD RPM 100 WOB 20 K. GPM 550 Up Wt 230 K Down 95 K Rot 135 K Torque Off Btm 16500 On Btm 17000 FP. Mud loss started @ 8432' tolallost 62 Bbls. Circulated at 350 GPM and momitored losses while mixing LCM pill. Pumped 34 Bbls 20 PPB LCM pill. Losses declined as ECD came down. Total lost 292 Bbls. Decision was made to run casing. Observed well and made 8 stand short trip. Drilled 2 feet of rat hole. Circulated hole clean at 440 GPM losses 15 BPH, Monitored well for flow back from balooning, 4.7 BPH declined to 2.3 BPH. POOH to run casing. POOH and laid down 4300' of DP. PJSM and unloaded RA sorce. Downloaded MWD. Laid down BHA. Retrived wear bushing and rigged up casing crew. Pre job safety meeting. Ran 108 Jts 7" 26 # L 80 BTC Casing with partial returns. Circulated with partial returns. Ran 7" 26 # L 80 BTC casing to 6823' 160 Jts in. Very little or no returns. Attempted to Circulate pumped in with no returns. Circulate with partial returns. Ran 7" 26# L-80 BTC casing to 8509' with no returns. Laid down fill up tool and made up cement head. Pumped into well at 25 SPM trying to get returns. No returns, PJSM for cement job. Lost 342 Bbls of mud. Rig Dowell, mix and pump 20 bbls CW100 @ 8.3 ppg, 20 bbls MudPUSH @ 12 ppg, 169 sxs (36 bbls) @ 15.8 ppg wI Class G + Printed: 4/24/2003 4:19:36 PM ) ) 3S-21 3S-21 ROT - DRILLING N1268@ppco,com Nabors 7ES H. ours .·..Cpde.·· ·CSUdb .. .... ..... .. .0 e 1.75 CEMENT PUMP INTRM1 AOO%BWOC D65, .200 gal/sk D46, .600% BWOC D67, Pump 5 bbls CW100, Test lines to 3500 psi, Pump 15 bbls CW100, Pump 20 bbls MudPUSH at rate of 5 bpm at 540 psi, Drop btm plug, Pump 36 bbls cmt at rate of 4.0 bpm at 500 to 550 psi, Drop top plug, Dowell Displace first 20 bbls water at rate of 5.6 bpm at 360 psi, switched to Rig pump and displaced 302 Bbls at 7 bpm , Slowed rate to 2.0 bpm @ 980 psi & bumped plug wi total of 322 bbls, Bumped plug wI 1500 psi, Bled back 1.5 bbls CIP @ 0550 hrs 3/21/03, Had no circ. thru out job, Casing movement stopped @ 0515 Hrs due to tight hole. Lost 323 Bbls of mud during cementing. Rigged down cementing equipment and change bales. Laid down landing Jt. Picked up and ran packoff. Tested packott to 5000 psi. Flushed stack, cleaned up rig floor and RU to lay down drill pipe. Laid down 153 Jts of drill pipe, 24 Jts of HWDP, and Jars from derrick. Changed top rams to 4". Rigged uo top drive and iron roughneck to work 4" DP. Set test plug and tested BOP. Tested Hydrill to 250/3500 psi. Tested Top Rams, IBOP, Choke and Kill valves, Lower rams, Lower IBOP, Floor Safety Valves, and Blind Rams to 250/5000 psi. Tested Accumulator System. State waived witiness of test. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: pate Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: 3/31/2003 04:15 - 06:00 06:00 - 08:00 2.00 CEMENT PULD INTRM1 08:00 - 09:30 1.50 CEMENTOTHR INTRM1 09:30 - 12:00 2,50 CEMENTOTHR INTRM1 12:00 - 17:00 5.00 CEMENTOTHR INTRM1 17:00 - 18:00 1.00 DRILL RIRD INTRM1 18:00 - 20:00 2,00 DRILL RIRD INTRM1 20:00 - 23:30 3.50 WELCTL BOPE INTRM1 23:30 - 00:00 0.50 WELCTL BOPE INTRM1 4/1/2003 00:00 - 01 :45 1,75 WELCTL BOPE INTRM1 01 :45 - 03:30 1.75 WELCTLOTHR INTRM1 03:30 - 04:30 1.00 RIGMNT RSRV INTRM1 04:30 - 04:45 0.25 DRILL SFTY INTRM1 04:45 - 08:30 3.75 DRILL PULD INTRM1 08:30 - 12:00 3.50 DRILL PULD INTRM1 12:00 - 16:00 4.00 DRILL TRIP INTRM1 16:00 - 16:30 0.50 DRILL CIRC INTRM1 16:30 - 18:00 1.50 RIGMNT OTHR INTRM1 18:00 - 23:15 5.25 DRILL TRIP INTRM1 23:15 - 00:00 0.75 CEMENTCOUT INTRM1 41212003 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 01 :00 - 02:30 1.50 CASE DEQT INTRM1 02:30 - 03:45 1.25 CEMENT DSHO INTRM1 Pulled test plug and installed wear bushing. Tested Upper & Lower IBOP's, 3 1/2" Floor & Dart Valves to 250 Psi Low, 5,000 Psi High, Lower IBOP Valve Failed Removed Lower IBOP, Tested New Valve to 250/5,000 psi Before Installing and Ck Ok, Re-Installed New Valve Serviced Top Drive Held PJSM on MU BHA & PU Radioactive Sources PU & MU 6 1/8" Bit, MM, MWD, Orient & Surface Test Same, Loaded Radioactive Source in MWD PU 4" HT 40 HWDP & Jars & RIH, PU 51 Jts of 4" HT 38 DP & Stood Back 17 Stds in Derrick TIH with BHA #4 to 3,855', PU 4" HT 38 DP While TIH Filled Dp and Broke Circ at 3,855', Blow Down Top Drive Cut & Slipped 130' of Drlg Line, Inspected Brake Pads & Linkage on Drawworks Cont TIH PU 4" HT 38 DP, Began Taking Wt at 8,365', Installed Blower Hose on Top Drive, Cleaned Out Soft Cmt from 8,365' and Tagged Firm Cmt at 8,384', (Top of Fit Collar @ 8,424') Drilled Med-Firm Cmt from 8,384' to 8,411', 5-1 OK WOB, 50 Rpm's, 225 Gpm at 1,950 Psi NOTE: SIM-OP Perform LOT on 7" x 95/8" Ann to 15.8 ppg EMW, Flushed Ann with 300 bbls Fresh Water and Freeze Protected with 65 bbls Diesel Circ Btms Up & Circ Hole Clean for Csg Test, 10.6 ppg Mud Wt In & Out RU and Pressure Tested 7" Csg to 3,500 Psi for 30 Min, Good Test, RD Test Equip Drilled Out FIt Collar @ 8,424', Shoe Trac and Float Shoe at 8,509', Drilled 20' of New Formation to 8,539' MD/5,224' TVD, 5-10K WOB, 50 Printed: 4/24/2003 4:19:36 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4/2/2003 02:30 - 03:45 03:45 - 04:30 04:30 - 06:00 06:00 - 12:00 12:00 - 20:00 20:00 - 21 :00 21 :00 - 00:00 4/3/2003 00:00 - 02:30 3S-21 3S-21 ROT - DRILLING N 1268@ ppco.com Nabors 7ES · ..... . ···Sub . Hours CodeCodè Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: 1.25 CEMENTDSHO INTRM1 0,75 CEMENTCIRC INTRM1 1.50 CEMENT FIT INTRM1 6.00 DRILL DRLG PROD 8.00 DRILL DRLG PROD 1.00 DRILL CIRC PROD 3.00 DRILL DRLG PROD 2.50 DRILL DRLG PROD 02:30 - 04:00 1.50 DRILL CIRC PROD 04:00 - 05:30 1.50 DRILL WIPR PROD 05:30 - 06:15 0.75 DRILL WIPR PROD 06: 15 - 07:00 0.75 DRILL CIRC PROD 07:00 - 10:30 3.50 DRILL CIRC PROD 10:30 - 11 :00 0.50 DRILL CIRC PROD 11:00-11:15 0.25 DRILL OBSV PROD 11:15-12:15 1.00 DRILL TRIP PROD 12:15 - 13:00 0.75 DRILL TRIP PROD 13:00 - 14:30 1.50 DRILL CIRC PROD Rpm's, 225 Gpm, 2,100 Psi Circ Btms Up for FIT, 10.6 ppg MW In & Out RU & Performed FIT to 13.5 ppg EMW with 10.6 ppg MW and 794 Psi, Good Test, RD Test Equip & Est Slow Pump Rates Drilled 61/8" Hole from 8,539' to 9,010' MD/5,486' TVD (471') ART 4.13 Hrs, AST -0-, 10-20K WOB, 60-100 Rpm's, 102 Spm, 250 Gpm, Off Btm Press 2,750 Psi, On Btm 3,050 Psi, On & Off Btm Torque 10K Ft#s, Rot WT 94K, Pu Wt 180K, Dn Wt 60K, Ave 45 Units BGG, 10.6 MW, Ave 12.95 ECD Top HRZ 8,979' MD/5,469' TVD Drilled from 9,010' to 9,579' MDI 5,831' TVD, (569') ART 5 Hrs, AST .5 Hrs, 10-20K WOB, 240 Gpm, Off Btm Press 2,675 Psi, On Btm 2,970 Psi, Torque Off Btm 11 K Ft#'s, On Btm 10K Ft#'s, Rot Wt 100K, Pu Wt 175K, Dn Wt 68K, Ave 120 Units BGG, 11.0 ppg MW, Ave 12.9 ECD Base of HRZ 9,292' MDI 5,654' TVD, Top of K-1 Sand 9,490' MDI 5,776', Max Gas from K-1 Sand 145 Units Pumped 20 bbl High Vis Baralift Sweep and Circ Out, No Increase in Cuttings, Circ Hole Clean Prior to Drlg Kup C, No Mud Loss, Circ at 240 Gpm, 2,970 Psi and 100 Rpm's, ECD went from 12.97 to 12.77, Ave 90 Units BGG Drill from 9,579' to 9,725' MDI 5,925' TVD (146') ART 2,10 Hrs, AST -0-, Control Drilled Thru Kup C at 1 OO'lHr ROP at 200 Gpm, 2,300 Psi, 10-20K WOB, 100 Rpm's, Slowed ROP to 55'/Hr When Logging Tools Were in Sand, Top of Kup C 9,591' MDI 5,840' TVD, Base of Kup C 9,623' MDI 5,860' TVD, Max Gas 1,150 Units with No Mud Loss or Gas Cut Mud, Ave BGG 100 Units, with 11.0 pg MW, Ave 12.8 ECD Drilled 6 1/8" Hole from 9,725' to 9,857' MDI 6,009' TVD T.D. (132') ART 2.16 Hrs, AST -0-, 20K WOB, 100 rpm's, 91 Spm, 222 Gpm's, Off Btm Press 2,540 Psi, On Btm 2,870 Psi, Off Btm Torque 11 k Ft#'s, On Btm 10.5K Ft#'s, Ave BGG 100 Units with 11.0 ppg Mw Ave ECD 12.8 ppg, Control Drilled to TD at 100'/Hr Circ 2 Btms Up for Wiper Trip, Circ at 250 Gpm, 2,900 Psi and 100 Rpm's, Ave Bgg 100 Units Wiped Hole 14 Stds to 8,450', Inside 7" Csg Shoe, Pulled 20K Over at 8,700' Thru Morraine Sand, Dropped Back Down and Pulled Thru with No Prob, Cont POOH to Shoe with No Problems TIH to 9,786' and washed 71' to Btm, No Problems Circ Btms up at 9,857', Max gas on btms Up 5,328 units, Gas Decreased to 100 Units, Pumped 20 bbl High Vis Baralift Sweep, No Increase in Cuttings Circ Hole Raising MW fro m 11.0 to 11.2 ppg Due to Gas Up on Wiper Trip, Circ Hole While Raising MW at 246 Gpm, 2,742 Psi, Pump 40 bbls LCM pill and displace into openhole - 220 gpm 12515 psi I 106 rpm I 10k rot torque. LCM pill 20 ppb =2.5 ppb Baracarb 25,8 ppb Baracarb 50, 4.5 ppb Baracarb 150, 5 ppb Steel Seal. Monitor well, static - line up on trip tank. POH from 9857' to 8820' - 5-1 OK drag - hole took proper displacement. Precautionary backreamed across Moraine sands from 8820' into shoe 1150 gpm I 1510 psi I 50 rpm CBU x 1.5 I 225 gpm I 2340 psi I 20 rpm - Max BBG 535 units average BBG after BU 100 units. Monitor well 15 min static - drop 2.25" drift down drill string. Printed: 4/24/2003 4:19:36 PM ) ) POH to 7495' slowly (10stds) hole took proper displacement. Pump dry job - blow down Top drive - clean rig floor mess from wet pipe. Cont POOH to 480', At BHA, Monitored Well-Static LD 8 Jts 4" HWDP & Jars and 3 Flex Dc's Held PJSM with Sperry Sun on Radioactive Sources Removed Radioactive Source from MWD Tool Downloaded Mwd and Fin LD BHA & 61/8" Bit RU GBR 31/2" Liner Running Equipment Held PJSM on Running 31/2" Liner PU & MU 3 1/2" Liner, RIH with 3 1/2" 9.3# L-80 SLHT Liner, Ran Baker "V" Set Float Shoe, 2 Jts 3 1/2" Liner, Baker Fit Collar, 1 Jt 31/2" Liner, Baker Landing Collar, RIH with 8 Jts of 31/2" Liner, 1-Pup Jt 3.82' Long for Marker Jt, 35 Jts 31/2" Liner (Total 46 Jts with Pup & Fit Equip, 1,457,51') Ran 44 Rigid Centralizers with 1 Stop Ring PU & MU Baker 7" x 5" ZXP Liner Top Pkr W/HR Profile & Flex Lock Hanger with 3.77' Pup Jt on Btm and RIH, Liner Wt 13K#'s ( Total Length 55.87') RIH with 3 1/2" Liner on 4" DP 10 Stds to 2,460' Circ Btms Up from 2,466', Had Gas back After Est Circ, Max gas 4,900 Units, Circ Out Gas Cut Mud, Final BGG 160 Units, Circ at 65 Spm, 160 Gpm at 340 Psi Monitor well, static. RIH with 31/2" Liner on 4" DP to 4,361' Circ Btms Up at 4,361', Max Gas at Btms up 2,285 Units, Circ Gas Out, Final BGG 150 Units, Circ at 99 Spm, 240 Gpm's, 800 Psi, Monitored Well-Static Cont RIH with Liner to 8,502', (7" Csg Shoe), Circ Btms Up at Shoe, Max Gas at Btms Up 250 Units, Final BGG 110 Units, Circ at 92 Spm, 225 Gpm's, 1,140 Psi, St Up WT 125K, Dn Wt 63K with 13 Rpm's and 8K Ft#'s Torque, Monitored Well-Static Fin RIH with 3 1/2" Liner to Btm, MU Cmt Head & Est Circ and Tagged Up at 9,857', No Problems W/Running Liner in Open Hole Circ & Cond Mud for Cmtg Liner, Lowered YP from 23 to 19, Gels from 6/8/10 to 5nl9 with 11.2 ppg Mw In & Out with No Mud Loss, Max Gas on Btms Up 760 Units, Held Safety Mtg with Crew & Cementers W/Circ, Batch Mixed Cmt, Ave BGG Prior to Cmtg 100 Units, Circ at 220 Gpm, 1,350 Psi, Rotated & Reciprocated Liner, full returns throughout. Up Wt 125K, Dn Wt 88K, Rot at 15 Rpm's with 9K Ft#'s Torque 1.75 CEMENT PUMP CMPLTN Line up to cementers - pumped 10 bbls of CW 100 and tested lines to 4400 psi. pumped remaining 20 bbls of CW 100 - 40 bbls of 12.5 ppg MudPush spacer and 65 bbls of 15.8 ppg G cement wI adds, 1.16 Yield. Flushed cement lines to rig floor, dropped wiper plug, Dowell Pumped 10 bbls FW, Turned Over to Rig and began displacing cmt with 11.2 ppg mud @ 5 bpm 700 psi. 50 bbls into Displacement 10 Water/40 Mud, with Approx 14 bbls of Cmt Out Of Shoe, Press increased to 3,100 psi, then dropped to 2,300 psi, (hanger set) appeared to have packed off, Lost Returns. Slowed Pump to 2.6 bpm at 1,835 psi with No Returns, after 100 bbls, Calc Displacement to Bump Plug, Press Increased from 1,670 psi to 2,150 then decreased to 1,850 psi, Pumped 4 add bbls and plugs Didn't Press Up, Reciprocated and Rotated Pipe until hanger set, CI P @ 21: 10 Hrs, Static drill pipe pressure 650 Psi. Legal Well Name: 38-21 Common Well Name: 38-21 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES Date . Hours ...Ùode ·Spb Phase ·.Cdde 4/3/2003 14:30 - 15:30 1.00 DRILL TRIP PROD 15:30 - 16:30 1.00 DRILL TRIP PROD 16:30 - 22:00 5.50 DRILL TRIP PROD 22:00 - 23:30 1.50 DRILL TRIP PROD 23:30 - 23:45 0.25 DRILL SFTY PROD 23:45 - 00:00 0.25 DRILL TRIP PROD 4/4/2003 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 02:45 0.75 CASE RURD CMPL TN 02:45 - 03:00 0.25 CASE SFTY CMPL TN 03:00 - 05:00 2.00 CASE PULR CMPL TN 05:00 - 06:15 1.25 CASE PULR CMPL TN 06: 15 - 07:00 0.75 CASE RUNL CMPL TN 07:00 - 08:00 1.00 CASE CIRC CMPL TN 08:00 - 09:30 1.50 CASE RUNL CMPL TN 09:30 - 10:00 0.50 CASE CIRC CMPL TN 10:00 - 14:00 4.00 CASE RUNL CMPL TN 14:00 - 15:00 1.00 CASE CIRC CMPL TN 15:00 - 17:00 2.00 CASE RUNL CMPL TN 17:00 - 19:30 2.50 CASE CIRC CMPL TN 19:30 - 21 :15 Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: 8pud Date: 3/20/2003 End: 4/6/2003 Group: DescriptionöfOperations Printed: 4/24/2003 4:19:36 PM ) ) C.onOcbPhillip~ .Alåskä Operatiol1S.SlIl1'ul1äryRepørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-21 38-21 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: . Date Sub From-To Hours>Code Code Phase . .pescriptionof Operations 01 :00 - 04:00 1.25 CEMENT OTHR CMPL TN Anchor tested hanger with 50K slack off wt. Picked up to 155K (initial PUW) . Worked pipe to manually release from HR tool- Put 4K#'s Left hand Torque & Worked Pipe Up to 140K & Down to 50K 8-9 Times, Saw Slight Indication of Being Free, Bled Off 650 Psi on DP and Fits Held, PUW remained 150-155k pulled up 1', slacked off to check hanger depth - no change. Pickud up 3' @ 150-155k, slacked off to check hanger depth - no change. Picked up 5' to realese packer setting dogs, Set Packer with 60K SOW - appeared to shear at 30k SOW. Press Up on Annulus to 1,000 Psi for 3 min, no bleed off, Press up to 500 Psi on DP and PU 8' - Press Dropped Off, Est Circ at 160 Gpm at 585 Psi, Up Wt 140K, Liner Set with shoe @ 9,851', Top Of Liner at 8,337'. Circ Btms Up, had 30 bbls of CW 100 Back with a Trace of Mud Push (MWT 11.6 ppg), Circ Hole at 8 Bpm, 343 Gpm's, 1,870 Psi RD Cement Lines, LD Single and Baker Plug Dropping Head. Pumped Dry Job and POOH LD 264 Jts of 4" DP Break Down & LD Baker Liner Setting Tool. Observed hydraulic release pins sheared and packer setting dogs tattle tail sheared. TIH with 14 Stds of 4" DP from Derrick, POOH LD Same Pulled Wear Bushing RU GBR Equip. to Run 31/2" Completion Run Completion equipment: MU Baker GBH-22 Seal Assembly - 1 jt tbg - DS Nipple (2.812") 1 jt tbg - MMG w/ DCR Shear Valve (3000#), 251 jts tbg - DS Nipple (2.875") & 15 jts of tbg (3 1/2" 9.3# L-80 EUE Mod) to 8,342', Ran a Total of 268 Jts 8,277,76" of 31/2" Tbg 1.50 CMPL TN DEOT CMPL TN RU & Tested 7" Csg and 3 1/2" Liner to 3,500 Psi for 30 Min, Good Test 1.50 CMPL TN RUNT CMPL TN Est circ at 1 Bpm and Stung Into Seal Bore Ext, PU & Spaced Out Tbg String, Up Wt 95K, Dn Wt 53K, 1.00 CMPL TN CIRC CMPL TN Displaced 11.2 ppg Mud in Hole Over to Seawater, Pumped 40 bbl High Vis Sweep, 250 bbls Fresh Water followed with 270 bbls of Seawwater, Pumped at 310 Gpm, 1,250 Psi 1.00 CMPL TN RUNT CMPL TN Monitored Well after Displacing 11.2 ppg Mud in Hole Over to Seawater, Well-Static, Landed Tbg in Hanger & RILDS, Landed 31/2" Tbg at 8,391', with Shear Valve at 8,268' and DS Nipple with 2.875" No Go at 512' 3.00 CMPL TN DEQT CMPL TN RU & Tested 31/2" Tbg to 3,500 Psi for 15 Min, Ck Ok, Tested 31/2" x 7" Ann to 3,500 Psi & Ck Ok, Made Several attempts to Shear DCR Valve at 3,500 Psi with no Success, Press Up to 3,900 psi and Sheared DCR Valve at 8,268', Est Circ Thru Valve & Ck Ok, Blew Down Surface Lines, LD Landing Jt and Installed 2 way Ck. 4/4/2003 21 :15 - 22:30 22:30 - 23:00 0.50 CEMENTCIRC CMPL TN 23:00 - 00:00 1.00 CEMENT PULD CMPL TN 4/5/2003 00:00 - 08:00 8.00 CEMENT TRIP CMPL TN 08:00 - 09:00 1.00 CEMENT PULD CMPL TN 09:00 - 11 :00 2.00 CMPL TN TRIP CMPL TN 11 :00 - 11 :30 0.50 CMPL TN OTHR CMPL TN 11 :30 - 12:00 0.50 CMPL TN RURD CMPL TN 12:00 - 20:00 8.00 CMPL TN RUNT CMPL TN 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 4/6/2003 00:00 - 01 :00 13:00 - 13:15 NOTE 1 Hr Time Change to Daylight Savings Time 1.00 RIGMNT RSRV CMPL TN Washed Up wind walls & Rig Floor 1.50 WELCTL EORP CMPL TN Changed Out Top Set of 4" Rams Over to 4 1/2" X 7" VBR's, Removed Turnbuckles & Mousehole 3.50 WELCTL NUND CMPL TN Pull Riser and Remove Extension, ND BOP Stack and Removed Double Studded Adapter, Sim Ops Cleaning Mud Pits, RD Ball Mill & Injection Skid 3.00 WELCTL NUND CMPL TN NU Gen V 5K# Tree & Adadpter Spool, RU & Tested Void and Tree to 5,000 Psi and Ck Ok. Pulled TWC. Sim Ops, Cont Cleaning Mud Pits 0.25 CMPL TN SFTY CMPL TN Held PJSM with Little Red on Freeze Protecting Well 04:00 - 05:00 05:00 - 06:30 06:30 - 10:00 10:00 - 13:00 Printed: 4/24/2003 4:19:36 PM i) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-21 3S-21 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES Start: 3/20/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/20/2003 End: 4/6/2003 Group: Date· . Frorn;.;To Hours. Code ðotre D~scripti~n .ofOpßrations 4/6/2003 13:15 - 15:00 1.75 CMPL TN FRZP CMPL TN Freeze Protected Well with 142 bbls Diesel, Diesel down to DCR Valve in Tbg to 8,268' and Diesel in 3 1/2" x 7 Ann Down to 2,655', Circ Diesel @ 2 Bpm-680 Psi 0.50 CMPL TN RURD CMPL TN RU & Set BPV, Blow Down Surface Lines, Cleaned Up Around Cellar and Fin Cleaning Mud Pits 15:00 - 15:30 RIG RELEASED at 15:30 Hrs 4/6/03 to Move to 3S-23 Printed: 4/24/2003 4: 19:36 PM Date 03/21/03 04/09/03 04/13/03 04/18/03 ) ) 3S-21 Event History Comment STAND BY FOR RIG. RUN GYRO TOOL TO 901,180',240' & 3601 SLM. [STANDBY] CLEAN OUT MUD WITH COILED TUBING FROM 8,268 - 9,7311 CTMD USING SLICK DIESEL. TAGGED BOTTOM AT 9,7311 CTMD. [FCO] TAGGED FILL @ 97431 RKB, DRIFTED WI 24'-3" OF 2.60" DUMMY GUN1S TO 9715' RKB, REPLACED SOV WI DV @ 82681 RKB, PT TBG & IIA TO 3000 PSI, GOOD TEST. [TAG, GLV, PT TBG-CSG, MIT] PERFORMED SCMT CEMENT BOND LOG FROM TD (97491) TO 82601. GOOD QUALITY CEMENT FROM TD TO 93651, POOR TO GOOD - FROM 9190' TO 93651. TOC AT 91901. PERFORATED INTERVAL 95941- 96241 WITH 2.5" HSD GUN, 6 SPF, POWERJET CHARGES. PERFORMED INITIAL SBHPS 2 HRS AFTER PERF. Page 1 of 1 4/24/2003 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) ó(D3-1J<3 ! 22-Apr-03 Re: Distribution of Survey Data for Well 3S-21 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 9,857.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 2 9 2003 Alaska a~ & Gas Con~ ~-""Il'ì'lm' , ..;1, vv H ISSiOn Anchoraoe oJ Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-21 -.,....._~~/.. Job No. AKMW0002323379, Surveyed: 13 April, 2003 Survey Report 16 April, 2003 Your Ref: AP/501032045200 Surface Coordinates: 5993865.00 N, 476052.15 E (70023'39.7234" N, 150011'41.4473" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993865.00 N, 23947.85 W (Grid) Surface Coordinates relaüve to Súucture: 20.71 N, 402.92 W (True) Kelly BushIng: 56. 95ft above Mean Sea Level Elevation relative to Project V Reference: 56.95ft Elevation relative to Súucture: 0.85ft -- spe""""'Y-55Uí1 DRILLING seRVices A Halliburton Company Survey Ref: svy2011 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-21 Your Ref: AP/501032045200 Job No. AKMW0002323379, Surveyed: 13 April, 2003 ConocoPhil/íps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 358.00 7.000 182.000 300.52 357.47 13.27 8 0.20W 5993851.73 N 476051.91 E 10.88 MWD Magnetic 482.95 9.920 192.060 424.11 481.06 31.41 S 2.71 W 5993833.60 N 476049.34 E 2.611 27.06 569.59 10.850 192.720 509.33 566.28 46.66 8 6.07W 5993818.36 N 476045.93 E 1.082 41.39 661.19 13.570 192.800 598.85 655.80 65.55 8 10.35 W 5993799.48 N 476041.59 E 2.969 59.22 750.86 15.750 196.990 685.60 742.55 87.458 16.23 W 5993777.60 N 476035.64 E 2.702 80.43 842.04 18.460 201 .120 772.74 829.69 112.768 25.05 W 5993752.32 N 476026.74 E 3.255 106.11 938.13 21.420 204.720 863.06 920.01 142.908 37.88 W 5993722.22 N 476013.82 E 3.334 138.06 1034.28 24.350 208.260 951.64 1008.59 176.31 8 54.61 W 5993688.86 N 475996.98 E 3.366 174.95 1130.20 27.750 211.090 1037.80 1094.75 212.878 75.51 W 5993652.38 N 475975.96 E 3.773 216.82 '~ 1224.89 29.770 214.080 1120.81 1177.76 251.228 100.07 W 5993614.10 N 475951.28 E 2.618 262.29 1320.12 32.130 214.700 1202.48 1259.43 291.638 127.74 W 5993573.78 N 475923.48 E 2.501 311.25 1414.74 35.110 214.910 1281.26 1338.21 334.64 S 157.64 W 5993530.87 N 475893.44 E 3.152 363.63 1510.08 40.800 214.640 1356.41 1413.36 382.798 191.06 W 5993482.82 N 475859.86 E 5.971 422.23 1604.50 41.940 211.950 1427.27 1484.22 434.95 8 225.30 W 5993430.78 N 475825.46 E 2.237 484.56 1700.16 42.420 209.370 1498.16 1555.11 490.19 8 258.04 W 5993375.63 N 475792.54 E 1.879 548.52 1793.06 47.780 207.810 1563.72 1620.67 547.97 S 289.48 W 5993317.96 N 475760.92 E 5.891 613.77 1889.84 51.730 207.690 1626.23 1683.18 613.338 323.87 W 5993252.71 N 475726.32 E 4.083 686.90 1985.27 53.630 208.370 1684.08 1741.03 680.328 359.53 W 5993185.84 N 475690.44 E 2.070 762.09 2079.55 58.040 207.920 1737.01 1793.96 749.09 S 396.32 W 5993117.18 N 475653.44 E 4.694 839.39 2175.48 59.000 208.640 1787.11 1844.06 821.138 435.08 W 5993045.27 N 475614.44 E 1.188 920.49 2270.80 59.900 212.420 1835.57 1892.52 891.81 S 476.78 W 5992974.72 N 475572.52 E 3.543 1002.21 2365.25 60.470 214.060 1882.53 1939.48 960.358 521.70 W 5992906.33 N 475527.38 E 1.623 1084.07 2460.30 63.360 216.250 1927.28 1984.23 1028.888 569.99 W 5992837.95 N 475478.87 E 3.657 1167.91 2555.35 66.080 216.680 1967.87 2024.82 1098.008 621.07W 5992769.00 N 475427.57 E 2.891 1253.84 2646.75 63.480 218.560 2006.81 2063.76 1163.498 671.52 W 5992703.67 N 475376.90 E 3.399 1336.48 2742.34 58.000 219.360 2053.52 2110.47 1228.328 723.93 W 5992639.00 N 475324.29 E 5.779 1419.71 2837.45 57.340 220.100 2104.38 2161.33 1290.138 775.29 W 5992577.36 N 475272.73 E 0.956 1499.89 2930.89 57.790 219.520 2154.50 2211.45 1350.71 8 825.78 W 5992516.94 N 475222.04 E 0.712 1578.56 ~ 3027.36 57.900 219.000 2205.84 2262.79 1413.958 877.47 W 5992453.87 N 475170.16 E 0.470 1660.08 3123.05 56.980 221.110 2257.34 2314.29 1475.688 929.36 W 5992392.31 N 475118.07 E 2.092 1740.50 3217.67 57.440 222.270 2308.59 2365.54 1535.07 8 982.26 W 5992333.08 N 475064.98 E 1.140 1819.62 3313.96 58.050 221.590 2359.98 2416.93 1595.658 1036.67 W 5992272.68 N 475010.37 E 0.871 1900.59 3409.05 55.640 221.590 2411.98 2468.93 1655.198 1089.51 W 5992213.31 N 474957.34 E 2.534 1979.78 3501.91 55.020 221.920 2464.80 2521.75 1712.168 1140.37 W 5992156.50 N 474906.30 E 0.729 2055.74 3594.56 55.740 222.140 2517.44 2574.39 1768.808 1191.42W 5992100.03 N 474855.07 E 0.801 2131.54 3713.01 56.080 221.970 2583.83 2640.78 1841.638 1257.13 W 5992027.40 N 474789.13 E 0.311 2229.05 3805.41 55.170 222.170 2636.00 2692.95 1898.258 1308.23 W 5991970.96 N 474737.85 E 1.001 2304.86 3900.68 55.800 219.860 2689.98 2746.93 1957.478 1359.73 W 5991911.89 N 474686.15 E 2.104 2383.02 3997.17 56.590 218.310 2743.67 2800.62 2019.71 8 1410.27 W 5991849.82 N 474635.41 E 1.566 2463.06 4092.11 57.760 215.970 2795.14 2852.09 2083.30 8 1458.43 W 5991786.38 N 474587.05 E 2.410 2542.81 16 April. 2003 - 8:23 Page 2 0'5 Drl/lQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-21 Your Ref: AP/501032045200 Job No. AKMW0002323379, Surveyed: 13 April, 2003 ConocoPhlllips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 4186.22 57.050 215.260 2845.84 2902.79 2147.768 1504.60 W 5991722.07 N 474540.68 E 0.986 2622.10 4283.09 56.140 214.690 2899.17 2956.12 2214.028 1550.96 W 5991655.96 N 474494.11 E 1.060 2702.96 4376.94 57.780 215.510 2950.34 3007.29 2278.38 8 1596.20 W 5991591.74 N 474448.66 E 1.895 2781.62 4472.99 57.120 215.100 3002.01 3058.96 2344.45 8 1642.99 W 5991525.82 N 474401.66 E 0.776 2862.58 4569.02 59.070 215.480 3052.76 3109.71 2410.998 1690.08 W 5991459.44 N 474354.35 E 2.058 2944.09 4662.59 58.440 214.840 3101.30 3158.25 2476.398 1736.15 W 5991394.19 N 474308.07 E 0.892 3024.09 4760.18 57.900 214.260 3152.77 3209.72 2544.68 S 1783.18 W 5991326.05 N 474260.83 E 0.749 3106.98 4855.66 57.320 212.890 3203.92 3260.87 2611.858 1827.77 W 5991259.02 N 474216.03 E 1.355 3187.54 ~ 4951.02 56.810 213.600 3255.76 3312.71 2678.788 1871.64 W 5991192.23 N 474171.94 E 0.823 3267.49 5045.33 59.140 216.650 3305.78 3362.73 2744.158 1917.66 W 5991127.01 N 474125.71 E 3.690 3347.43 5140.80 60.310 218.130 3353.91 3410.86 2809.65 8 1967.72 W 5991061.67 N 474075.44 E 1.815 3429.84 5235.30 59.930 217.410 3400.99 3457.94 2874.428 2017.91 W 5990997.06 N 474025.04 E 0.773 3511.73 5330.65 59.900 217.220 3448.79 3505.74 2940.03 8 2067.92 W 5990931.61 N 473974.82 E 0.175 3594.20 5425.79 59.450 217.620 3496.83 3553.78 3005.26 8 2117.83 W 5990866.54 N 473924.71 E 0.596 3676.29 5521.18 59.150 217.670 3545.53 3602.48 3070.208 2167.92 W 5990801.76 N 473874.40 E 0.318 3758.27 5615.81 58.930 217.190 3594.21 3651.16 3134.648 2217.24 W 5990737.48 N 473824.88 E 0.493 3839.39 5710.69 58.340 216.750 3643.59 3700.54 3199.378 2265.97 W 5990672.91 N 473775.95 E 0.737 3920.38 5806.19 57.850 216.130 3694.06 3751.01 3264.59 8 2314.12 W 5990607.84 N 473727.58 E 0.753 4001.45 5900.62 57.210 216.150 3744.76 3801.71 3328.92 8 2361.11 W 5990543.66 N 473680.39 E 0.678 4081.12 5996.52 57.260 215.390 3796.66 3853.61 3394.35 8 2408.24 W 5990478.38 N 473633.05 E 0.668 4161.76 6091.70 57.170 215.870 3848.20 3905.15 3459.398 2454.86 W 5990413.49 N 473586.22 E 0.434 4241.78 6186.72 56.750 215.700 3900.01 3956.96 3524.01 8 2501.44 W 5990349,02 N 473539.44 E 0.467 4321.43 6282.65 56.370 215.160 3952.87 4009.82 3589.23 8 2547.84 W 5990283.95 N 473492.82 E 0.614 4401.48 6377.37 55.650 215.410 4005.82 4062.77 3653.34 8 2593.21 W 5990219.98 N 473447.25 E 0.791 4480.01 6472.28 56.970 217.510 4058.47 4115.42 3716.848 2640.14 W 5990156.64 N 473400.12 E 2.307 4558.96 6567.68 57.030 216.590 4110.43 4167.38 3780.708 2688.34 W 5990092.93 N 473351.71 E 0.811 4638.95 6661.13 56.520 216.280 4161.64 4218.59 3843.59 8 2734.77 W 5990030.19 N 473305.08 E 0.612 4717.12 ~ 6756.32 58.120 216.600 4213.03 4269.98 3908.048 2782.36 W 5989965.89 N 473257.28 E 1.704 4797.24 6848.08 57.610 215.860 4261.84 4318.79 3970.72 8 2828.29 W 5989903.36 N 473211.16 E 0.880 4874.93 6944.74 56.910 215.780 4314.12 4371.07 4036.64 8 2875.87 W 5989837.59 N 473163.36 E 0.728 4956.24 7041.96 55.910 217.310 4367.91 4424.86 4101.71 8 2924.08 W 5989772.68 N 473114.94 E 1.666 5037.21 7136.06 57.610 216.880 4419.48 4476.43 4164.488 2971.55 W 5989710.06 N 473067.27 E 1.847 5115.89 7229.13 57.900 216.480 4469.14 4526.09 4227.61 8 3018.57 W 5989647.08 N 473020.05 E 0.479 5194.60 7326.93 57.210 216.310 4521.61 4578.56 4294.05 8 3067.54 W 5989580.80 N 472970.87 E 0.721 5277.13 7420.74 56.520 215.990 4572 .89 4629.84 4357.48 8 3113.88 W 5989517.52 N 472924.33 E 0.789 5355.68 7514.74 55.770 216.100 4625.25 4682.20 4420.59 S 3159.81 W 5989454.55 N 472878.19 E 0.804 5433.74 7609.52 57.440 216.160 4677 .42 4734.37 4484.50 8 3206.47 W 5989390.79 N 472831.33 E 1.763 5512.87 7704.23 56.980 216.550 4728.71 4785.66 4548.63 8 3253.67 W 5989326.82 N 472783.93 E 0.596 5592.48 7799.38 58.850 216.550 4779.25 4836.20 4613.398 3301.67 W 5989262.21 N 472735.71 E 1.965 5673.09 7894.42 58.560 216.150 4828.62 4885.57 4678.80 S 3349.81 W 5989196.96 N 472687.37 E 0.472 5754.30 16 April, 2003 - 8:23 Page 3 0'5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-21 Your Ref: AP/501032045200 Job No. AKMW0002323379, Surveyed: 13 April, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7990.72 57.910 216.220 4879.31 4936.26 4744.88 S 3398.15 W 5989131.03 N 472638,82 E 0.678 5836.17 8086.58 57.300 217.430 4930.67 4987.62 4809.67 S 3446.66 W 5989066.40 N 472590.10 E 1.241 5917.10 8180.41 56.460 215.850 4981.94 5038.89 4872.72 S 3493.56 W 5989003.50 N 472543.00 E 1.670 5995.67 8276.28 58.470 216.080 5033.50 5090.45 4938.13 S 3541.02 W 5988938.24 N 472495.32 E 2.106 6076.49 8369.86 58.490 217.210 5082.42 5139.37 5002.14 S 3588.64 W 5988874.39 N 472447.51 E 1.030 6156.25 8455.46 57.860 217.590 5127.56 5184.51 5059.91 S 3632.81 W 5988816.75 N 472403.15 E 0.827 6228.95 8573.57 57.540 216.370 5190.68 5247.63 5139.66 S 3692.86 W 5988737.19 N 472342.84 E 0.914 6328.76 8667.91 57.330 216.210 5241.46 5298.41 5203.75 S 3739.92 W 5988673.26 N 472295.58 E 0.265 6408.27 8760.74 57.180 215.410 5291.67 5348.62 5267.07 S 3785.61 W 5988610.09 N 472249.69 E 0.743 6486.35 ~. 8856.69 56.710 215.690 5344.00 5400.95 5332.50 S 3832.36 W 5988544.81 N 472202.72 E 0.548 6566.76 8952.58 55.760 215.490 5397.30 5454.25 5397.32 S 3878.76 W 5988480.13 N 472156.12 E 1.006 6646.48 9046.75 54.800 215.530 5450.93 5507.88 5460.33 S 3923.71 W 5988417.27 N 472110.96 E 1.020 6723.88 9141.59 53.270 215.580 5506.63 5563.58 5522.77 S 3968.35 W 5988354.97 N 472066.13 E 1.614 6800.64 9236.40 53.110 216.640 5563.44 5620.39 5584.10 S 4013.08 W 5988293.79 N 472021.20 E 0.911 6876.54 9331.17 52.350 215.860 5620.83 5677.78 5644.91 S 4057.68 W 5988233.11 N 471976.41 E 1.035 6951.96 9426.64 51.600 215.350 5679.64 5736.59 5706.06 S 4101.46 W 5988172.11 N 471932.43 E 0.891 7027.16 9518.20 51.000 214.190 5736.89 5793.84 5764.75 S 4142.21 W 5988113.55 N 471891.49 E 1.186 7098.60 9614.38 50.750 215.390 5797.58 5854.53 5826.03 S 4184.78 W 5988052.41 N 471848.72 E 1.002 7173.20 9709.65 50.690 215.090 5857.89 5914.84 5886.26 S 4227.33 W 5987992.31 N 471805.98 E 0.252 7246.94 9798.65 49.820 214.370 5914.80 5971.75 5942.50 S 4266.32 W 5987936.20 N 471766.81 E 1.159 7315.36 9857.00 49.820 214.370 5952.45 6009.40 5979.29 S 4291.49 W 5987899.49 N 471741.53 E 0.000 7359.93 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.95' MSL. Northings and Eastings are relative to 2551' FNL, 1201' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2551' FNL, 1201' FEL and calculated along an Azimuth of 215.800° (True). ~ Magnetic Declination at Surface is 25.154°(18-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 9857.00ft., The Bottom Hole Displacement is 7359.95ft., in the Direction of 215.668° (True). 16 April, 2003 - 8:23 Page 4 of5 Dri/lQuest 3.03.02.004 wÞ Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 3S-21 Your Ref: API 501032045200 Job No. AKMW0002323379, Surveyed: 13 April, 2003 ConocoPhl1fips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 9857.00 6009.40 5979.29 S 4291.49 W Projected Survey .....,;..--- Survey tool program for 35-21 ~ From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 358.00 0.00 357.47 358.00 9857.00 357.47 Tolerable Gyro(3S-21 Gyro) 6009.40 MWD Magnetic(3S-21) ~ 16 April, 2003 - 8:23 Page 5 0'5 DrmQuest 3.03.02.004 ) ) ¿;¡ 03-06 J 22-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-21 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0,00' MD 0.00' MD (if applicable) 0,00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECE\VEO ~PR 2. 9 200~ f""r\.~ r·o~m1\5àon Œ\ &. Gas \NIt.... v It Aias\æ AAchmag9 Attachment(s) --- \'() -<J ~ f1) Sperry-Sun Drilling Services --- Western North Slope ConocoPhillips Kuparuk 3S Pad 38-21 Gyro Job No. AKF00002323379, Surveyed: 13 April, 2003 Survey Report 16 April, 2003 Your Ref: AP/501032045200 Surface Coordinates: 5993865.00 N, 476052.15 E (70023' 39.7234" N, 150011'41.4473" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ,.- Surface Coordinates relative to Project H Reference: 993865.00 N, 23947.85 W (Grid) Surface Coordinates relative to Structure: 20.71 N, 402.92 W (True) Kelly Bushing: 56.95ft above Mean Sea Level Elevation relative to Project V Reference: 56.95ft Elevation relative to Structure: 0.85ft spe...,.....y-su11 DRIL..L..ING seRVices A Halliburton Company Survey Ref: 5vy2010 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 3S-21 Gyro Your Ref: AP/501032045200 Job No. AKFOOOO2323379, Surveyed: 13 April, 2003 ConocoPhllllps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.95 0.00 0.00 N O.OOE 5993865.00 N 476052.15 E 0.00 Tolerable Gyro 88.30 0.000 0.000 31.35 88.30 0.00 N 0.00 E 5993865.00 N 476052.15 E 0.000 0.00 176.00 0.900 180.000 119.05 176.00 0.69 S O.OOE 5993864.31 N 476052.15 E 1.026 0.56 266.00 3.950 180.000 208.96 265.91 4.50S 0.00 E 5993860.50 N 476052.14 E 3.389 3.65 358.00 7.000 182.000 300.52 357.47 13.27 S 0.20W 5993851.73 N 476051.91 E 3.321 10.88 ~. All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.95' MSL. Northings and Eastings are relative to 2551' FNL, 1201' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2551' FNL, 1201' FEL and calculated along an Azimuth of 215.800° (True). Magnetic Declination at Surface is 25.154°{18-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 358.00ft., The Bottom Hole Displacement is 13.27ft., in the Direction of 180.845° (True). Survey tool program for 35-21 Gyro Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 358.00 357.47 Tolerable Gyro ,................ --- 16 Apríl, 2003 - 7:59 Page 2 of 2 DríllQuest 3.03.02.004 ') ') a03-03( II to 53 \VELIÁ LOG TRANS1\fITT AI.. To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 \Vest 7th A venue, Suite 100 Anchorage, Alaska April 22, 2003 RE: J\ffiTI FOfiTIation Evaluation Logs 3S-21, AK-J\f\V-2323 3 79 1 LDWG foru1atted Disc with verification listing. API#: 50-103-20452-00 PIJEASE ACKNOWIJEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF TH.E TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Dlilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage:! Alaska 99518 Date: Sigooj: ~~----.J ECE'\/r·"s R ,~ . I ......tl· ~~tJ> APR 29 2003 flJatm80\'; B; Gi:1S Cnns. '.>Yn~r!~~~-j A¡,,~ct~r1ì:~'¡;: ) '. ~",I . ConocoPhilUps ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com March 31,2003 Alaska Oil and Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approval to alter casing program for well 3S-21 PTD # 203-031 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby files this Application for Sundry Approval to alter the casing program from the originally approved plan. After several unsuccessful attempts to cure lost circulation, it was deemed necessary to stop drilling and top-set the 7" casing string above the Kuparuk "c" sand. A schematic of the proposed casing program is attached to this application. An exception to 20 AAC 25.412 (b) is requested. The distance between seals at the top of the 3 %" liñer and the top perforation ~will exceed 200' MD. In this case, the distance between the seals and the top perforation will be. -1290' MD / 700' TVD. An adequate leak-off test of the 7" casing shoe, combined with a cement bond log of the liner section below the 7" casing shoe will provide proof of zonal isolation between the seals and the perforated interval. ,_ ~ \' -In <1\/? ..!- \'Qc.c)''¡~~C2..~c..J o.'~Q'CY~~ . f.H:- r I" ( ~(~'-Û") If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, \~,~ Randy Thomas GKA Drilling Team Leader RECEIVED APR 0 1 2.003 Aìasita Oti & Gas Cons. Commission ORIGINAL Anchorage ') ) -1 /~,: .--.., vtf - I £/ '<1(\7 ¿~ ? ~,JJ,III./%/, ("í 7fU3 ~ ø; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Alter casing _XX Repair well _ Change approved program _XX 2. Name of Operator ConocoPhillips Alaska, Inc, 3. Address p, O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2551' FNL, 1207'FEL,Sec. 18,T12N, R8E,UM At top of productive interval 2179'FSL,60T FEL, Sec. 24,T12N, R7E, UM At effective depth At total depth 1943' FSL, 782' FEL, Sec. 24, T12N, R7E, UM 12. Present well condition summary Total depth: measured true vertical 8519 5218 Effective depth: measured true vertical Operational shutdown _ Plugging _ Pull tubing_ 5. Type of Well: Development _ Exploratory Stratigraphic _ Service _XX (asp's: 476052, 5993865) (as proposed) (as proposed) feet feet feet feet Plugs (measured) Junk (measured) Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 28 7. Unit or Property name Other Kuparuk River Unit 8. Well number 3S-21 9, Permit number I approval number 203-031 / 10. API number 50-103-20452-00 11. Field I Pool Kuparuk River Field/Kuparuk River Oil Pool Casing Conductor Surface Production Length 108' 3616' 8481' Size Cemented Measured Depth True vertical Depth 16" x 30" 80 sx ArcticCrete 108' 108' 9.625" 582 sx AS Lite, 326 sx LiteCrete 3644' 2602' 7" 180 sx Class G 8509' 5213' Perforation depth: measured none true vertical none Tubing (size, grade, and measured depth none Packers & SSSV (type & measured depth) none 13. Attachments Description summary of proposal _XX 14. Estimated date for commencing operation March 31, 2003 16lf~OPO, sa', was Verb~IY approved tf ?})f)..." M C' ~ S \ \~ a 'of å~þMt'è'r·~ Date approved Service _XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. f'~' E<$)o. l"',," E' 'I v, ~;,.,",;" , """'¡, 'Il II> '" N"""I' ~ }J G ~J'r ~I:ìo'n~ :¡~)C.'\~~ APR 0 1 f'!{'.fY".J' L:,)~/J Alaska Œ1 & Gas Cons, {~Jmm~n Anchomge Detailed operations program 15. Status of well classification as: BOP sketch Oil Gas Suspended _ Questions? Call Scott Low/}' 265-6869 3/~. (03 Date Prepared by Sharon Allsup-Drake Signed C \ ~. "j~. R. Thomas ) FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no::.> ,_-"_, _._ Plug integrity _ BOP Test _ Location clearance _ ....."X ~-)~- L¡ 7 Mechanical Integrity Test "'i:-- r- Subsequent form required 10- '" - ( ~""~t\.;.\Q;.JtJ.\~~ LO~~", -S\(~H \.\~'" E~~~~'\c.,,'\O aC)~c..JSl'-\\~) ~~~ Approved by order of the Commission ~~ ~ ~ Commissioner Date L/ I 0/ bY APR Form 1 0-403 Rev 06/15/88 . t? B 0 M S B F L Title: Kuparuk Drilling Team Leader 4 20m OR',G NAL SUBMIT IN TRIPLICATE 'KRµ - 35-21 Injec"Jr \ Proposed Completion Schematic T opset Case Contingency ) ConocóPhillips ! ..~ l I I r ~ ~ ~ ~ ~ ~ 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down Special Drift 2.91" ~ ~ ~ ~ ~ ~ 16"x30" 1 ~ ~ " ~ ~ 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required Special Drift 2.91" .~ ~ ~ ~ ~ insulated ~ ~ ~ " ~ ~ 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" conductor @ ~ ~ ~ " ~ ~ :1 ~ ~ " ~ ~ +/- 108' MD ~ ~ ~ - " ~ ~ 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. ~ ~ ~ " ~ ~ I ~ ~ " ~ ~ .~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ... ~ ~ " ~ .~ ~ " ~ ~ ~ " ~ ~ ~ I ~ .~ ~ .~ ~ ~ ~ I ~ ~ ~ " .~ ~ " I ~ ~ ~ " ~ .~ ~ ~ .~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " ~ ~ ~ I I ~ ~ ~ ~ ~ ~ " ~ Surface csg. ~ ~ " ~ 9-5/8"40# L-80 ~ ~ ~ ~ .,¡¡¡¡å ~ " ~ BTC (3644' MD / ~ " ~ § 2602' TVD) ~ ~ ~ I Surface csg. ~ " ~ " Cemented with ~ " ~ " 582 sx lead ~ ~ 326 sx tail ~ I ~ I Circulated 269 ~ I 3-1/2" X 1-1/2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' ~ " L-80 handling pups installed on top and bottom of mandrel. bbl cement to ~ ~ surface ~ ~ ~ I ~ I ~ " 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing ~ I ~ " ~ " ~ I 3-1/2" Cameo 'DS' nipple w/2.813" No-Go profile ~ I ~ ... " ~ § ~ I 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing ~ ~ ~ " 5.125" X 3" Baker locator sub ~ " ~ " ~ j 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 +- EUE8RD box up Intermediate csg. 7" 26.0# L-80 BTCM (8509' MD / 5213' TVD) Cemented with 180 sx Class 'G' + adds. C Sand Perfs (to be done after rig moves off) ~ ~ ~ .¿ ~ þ: ~ þ Liner Assembly (run on drillpipe). 150' of liner overlap Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flex lock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 3-1/2" 9.3# L-80 SLHT liner as needed Production Liner 3-1/2" 9.3# L-80 SLHT (9994' MD /6027' TVD) AlII ~ 3-1/2" Baker Landing Collar 2 jts 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe Scott Lowry 03/31/03 Rig: Nabors 7Es Location: Palm Client: ConocoPhillips Alaska Revision Date: 3/31/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 8,167' MD < Liner Top at 8,367' MD Previous Csg. .. 7", 26.0# casing at 8,517' MD ì 38-21 i CemCADE Preliminary Job Design 3 ·1/2"··Liner Prelimnary Job Design based on limited input data. FOr estimate purpoæs only. ) SCIllll._1PU8P Volume Calculations and Cement Systems Volumes are based on 60% excess, Displacement is calculated with a 4.0"- 14,0# drill string. Tail Slurry Minimum thickening time: 130 min, (pump time plus 90 min,) 15,8 ppg Class G + 2.0 gps D600G + 0.02% B155 + 0.3% D65 + 0,2 gps D47 -1.16 ft3/sk Liner Cap: 0.1276 ft3/ft x 200' x 1.00 (no excess) = Liner Lap..: 3 0,1480 ft 1ft x (8517' - 8367') x 1.00 (no excess) = Annular Volume: 0.1378 ft31ft x (9994' - 8517') x 1.60 (60% excess) = Shoe Volume: 3 0.0488 ft 1ft x 80' x 1,00 (no excess) = Totals: 25.5 ft3 + 22.2 ft3 + 325,6 ft3 + 4.4 ft3 = 377.7 ft3/1,16 ft3/sk = Round up to 330 sks 25,5 ft3 22,2 ft3 325.6 ft3 4.4 ft3 377.7 ft3 325.6 sks BHST = 147°F, Estimated BHCT = 114°F, (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 < 31/2",9.3# casing CW100 5 20 4.0 16.0 in 6 1/8" OH MudPUSH XL 5 40 8,0 24.0 Tail Slurry 5 68 13.6 37.6 Drop Liner Plug 5.0 42,6 Displacement 3.5 40 11.4 54.0 Displacement 5 45 9,0 63.0 Slow Rate 3 19 6.3 69.3 TD at 9,994' MD (6,028' TVD) Mark of Schlumberger MUD REMOVAL Recommended Mud Properties: 11,3 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12,5 ppg MudPUSH* XL, Pv? 25-30, Ty ? 40-50 Centralizers: Recommend 2 per shoe joint and 1 per joint to Liner Lap for effective mud removal. ( ) ~.. 0...·J.^'"u···,~, ~' IT'. ' rr. I ,A :...., lJ :J lb [JJ, ;? "i¡ILÛ LI I I, P , . ®.Il ® ~rf ~ fÆ bU~ è0 w\\lJu l / I / j I í I FRANK H. MURKOWSKI, GOVERNOR A.I,A.~KA. OIL AND GAS CONSERVATION COJDIISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage AK 99510 333 W. 'JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 3S-21 ConocoPhillips Alaska Permit No: 203-031 Surface Location: 2551' FNL, 1207' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 1943' FSL, 782' FEL, Sec. 24, TI2N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659...3607 (pager). Sincerely, ~} /.-- --t-L- -'"L, Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this'.... J day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section conocóPhlllips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com February 17, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, injector 3S-21 Dear Commissioner Taylor: // / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, KRU 3S-21 , a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, l~~\~ Randy Thomas GKA Drilling Team Leader 1...11 ~ II 1 .0\ 1 \ \ _' I., \~ 9. Approximate spud date /' Amount February 28, 2003 $200,000 14. Number of acres in property 15. Propos~depth (MD and TVD) 2448 9994 ' MD / 6027 ' TVD 17. Anticipated pressure (see 20 AAC 25,035 (e)(2)) Maximum surface 2979 psig / At total depth (TVD) 3621 psig Setting Depth ,) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas D Single Zone D 5. Datum elevation (DF or KB) RKB = 28' 1a. Type of work: Drill l.::J Redrill U Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2551' FNL, 1207' FEL, Sec. 18, T12N, R8E, UM At top of productive interval 2179' FSL,607'FEL,Sec.24,T12N, R7E, UM At total depth 1943'FSL,782'FEL, Sec, 24,T12N, R7E,UM 12. Distance to nearest property line 13. Distance to nearest well· 607' @ Target 3S-18 @ 53' / 16. To be completed for deviated wells Kickoff depth: 200 MD 18. Casing program size 6. Property Designation ADL 25544 ALK 2639 7. Unit or property Name Kuparuk River Unit 8. Well number // 3S-21 feet Maximum hole angle 57.6° N4A- l.-IZ'1IZ-CC1'~ ~ ") ('Jt:' Ä t../ V·;I Development Oil U Multiple Zone D 10. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Hole Casing Weight 42" 16" x 30" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling H-40 Weld L-80 BTC L -80 BTCM Length 80' 3601' 9966' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' 9 cy High Early 28' 28' 3629' 2612' 580 sx AS Lite & 300 sx LiteCrete 28' 28' 9994' 6027' 290 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: Plugs (measured) measured true vertical feet feet Effective Depth: Junk (measured) measured true vertical feet feet Casing Conductor Surface Production Length Size Cemented Measured depth Perforation depth: measured true vertical True Vertical depth 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869 Commission Use Only Permit Number I API number I Approval date a :'J ( ,v1-.. Isee cover letter ;¿. ~S - ~31 50- ~ ~ 3. - ).., Q I...j )~:À - C G IÏ' L^, V'J for other requirements Conditions of approval Samples required DYes j¿9 No Mud log required U Yes l2f. No Hydrogen sulfide measures D Yes ~ No Directional survey required ~. Yes D No ,. RequiredworkingpressureforBO~E D2M; D 3M¡ D 5M; D. 10M; D ~ D )€s+ ''ßa PE ~ $000 f~'" Other: ,,~v- 1-0 At+<- l.S. ~I ~ (þ~ P~~ dJ2~.fk r.:'b"~~ ~t: ,~ 1......;('1..{. Vi- ~ · J, J. t ' Á1) \') t'\7 <.l A..l "-i.11~ ~ d . C\..t k: "'-'A...fe.. ~ ç ¡., kÞ\ p"',"'" a ",,\. M r rj t..t. Kit e'tll. t f t{ ""-l-t '\ 0,\ "(,(t1 (..(.,( t\.lJ . 1 Ongina gn c, -.J by order or ..I U Approved by Randy Ruedrich Commissioner the commission Date ~ 'fA <' 0 " ¡-eþrt1¿oI ..z-/ð?(Pk, Submit in triplicate V Signed " \.T~ \ "'---~ Title: Kuparuk Drilling Team Leader Form 10-401 Rev. 12/1/85· o i H "'.., ! , .~.. ~~ .kd z..../z.o(o ~ Date Pr¡:m;:¡rArI hv Sh;:¡mn AI/!';/m-nmkA ') AP'-'Ii")ation for Permit to Drill, Well 3S-21 Revision No.O Saved: 17-Feb-03 Permit It - Kuparuk Well 38-21 Application for Permit to Drill Document Table of Contents 1. Well Name ....... ...... .... .... ........... ........ ..... ....... ...... ....... ... ..... ..... ... .... ....... ..... ... .......... ... 2 Requirements of 20 AAC 25.005 (f)...............................,..................... ........ ....... ....................................2 2. Location Sum mary ......... ........... .... ....... ....... ... ... .... .......... ... ..... ............... ..... ... .......... 2 Requirements of 20 AAC 25.005(c)(2) ......................... ...................... ....... ...... ......... ........... ...................2 Requirements of 20 AAC 25. 050(b)............................... .................... ....... ........ ........ ..............................2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drill i ng Hazards Information. ........... ..... ...... ....... ..... ........ ........ .... ...... ......... ...... ....... 3 Requirements of 20 AAC 25.005 (c)( 4) ........ ........ ......................... ...... ...... .................. ........................... 3 5. Procedure for Conducting Formation Integrity Tests...........................·................ 3 Requirements of 20 AAC 25.005 (c)(5) ................... .......... ........................ ....... ........ .............................. 3 6. Casi ng and Cementing Program.............................................................................4 Requirements of 20 AAC 25. 005( c)(6) .................................................... ............................ ............. ...... 4 7. Diverter System Information... ......... ........... .... ... ....... ...... ..... ..... .... ......... ... .... .......... 4 Requirements of 20 AAC 25.005(c)(7) ..... .................. ............................ ............... ...... ....... ...... ..... ......... 4 8. Drill i ng FI u id Program . ..... ........ ........... ........ ....... ..................... ..... .... ......... ....... ... .... 4 Requirements of 20 AAC 25. 005( c)(B) ........ .................... ...... ............. ........ ............ ................ ........ ........ 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ............... ................... .......... ........ ........ ........ ................ .............. 5 10. Seismic Analysis.... ....... ... .......... ....... ..... ...... ....... ............ ............ ........... ... ......... ...... 6 Requirements of 20 AAC 25.005 (c)(10) .............. ............ ...... ................ ........ ........................................ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ........................................... .................. ................................... 6 12. Evidence of Bondi ng .... ..... ... ... .......... .... ...... ......... .... ..... ...... ..... ........... ..... ..... ... ....... 6 Requirements of 20 AAC 25.005 (c)(12) . ........ ....................... ............. ........ .... ......... .............................. 6 13. Proposed Drilling Program .....................................................................................6 .. n .,.,...... ~ .. ~,' , ..... '1<r ~ '\ : ¡ IP' W" j' i''¡ .,!I/II 3$-21 PERMIT IT. DOC Page 1 of 7 Printed: 17-Feb-03 ) Apr':~tion for Permit to Drill, Well 38-21 , Revision No.O ./ Saved: 17-Feb-03 Requirements of 20 AAC 25.005 (c)(13) ...................... ..... .................... .......................... ............ ........... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. A tta c h me nts ............................................................................................................. 7 Attachment 1 Directional Plan. ........... ............ ............ .... ..................................... ....... ...... ...... ............... 7 Attachment 2 Drilling Hazards....... ... .................................................... ........ ....... ...... ..........6 Attachment 3 Well Schematic........................................................................................... ...6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unìque name des¿qnated by the operator and a unìque API number assigned by the commìssion under 20 AAC 25.040(b), For a well with multiple well br{mche!;,~ each branch must similal1y be Identified by a unique name and API number by adding a suffix to the name designated for t/7e well by the operator and to the number as!:>1..qned to t/7e well by tt7e commission. The well for which this application is submitted will be designated as 35-21. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Olill must be accompanied by eaäl of'the following items, exælj.ìt for an item already on flÏe with the commission and Identified 1i7 the application: (2) a plat Identifyli7g the property and the property's owners and showing (A)the c:rJordinates of" the plVposed location of the well at the surface/ at the top of each oþjective formr1tion and at total dept/7,. referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordìnate sy.stem for this state as maintained by the National Geodetic Survey in tlie National Oceanic and AtmofJpheric Administration; (C) tile propo:..-ed depth of the well at the top of" each objective formation and at totaf depth; Location at Surface NGS Coordinates Northings: 5,993,865 12551' FNL, 1207' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,052 Pad Elevation /' 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "c" Sand) NGS Coordìnates Northings: 5,988,050 2179' FSL, 607' FEL, Sec 24, T12N, R7E, UM ",....... Eastings: 471,825 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 9647' 5841' 5785' Location at Total Depth 11943' FSL, 782' FEL, NGS Coordinates Northings: 5,987,815 Eastings: 471,650 Sec 24, T12N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: .,r'" 9994' 6027' 5971' and (D) other ìnformation required by 20 AAC 25.0S0(b); Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviated, the application for a Permit to 01'111 (Form 10-401) must (1) ìnclude a plat drawn to a sUItable scale, ShOWli7g the path of the proposed weflboret including all adjacent wellbores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan J ' L(1' ~ r A , I.¡.(: I .' ~ " '. ,; q I I' ~, J" : 1 'II \ . ~ ~ \>" j :1 . ,',~ ,.¡1. 38-21 PERMIT IT. DOC Page 2 of 7 Printed: 17-Feb-03 ') Ap"lli~tion for Permit to Drill, We1l3S-21 , Revision No.O , Saved: 17-Feb-03 and (2) for all wells wtZtlin 200 feet of the proposed wellbore (A) list the names of the operators of those well.'i¡, to the extent that thos-e names are known or discoverable liì public record!:>-; and show tflat each named operator has been furnished a cvpy of the application by certified mall,' or (B) 8tate that the applicant is ttle only afrected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pel7l71t to Drill must be accompanied by each of the following Items; except for an Item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036r or 20 AAC 25.037, as applicable.... ",/ Please reference BOP schematics on file for Nabors 7ES. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be ac(;'Ompanied by each of the tollowlng Items; except for an Item already on file with the (;'(JfT}rTlis...'iion and identitied in the application: (4) infolmatlon on dlilling flazard~ including (A) the maximum downhole pres8ure thlft may be encounterect cl1terla used to detel1Tline i~ and maximum potentl~71 surface pressure bðsed 0/7 a methane gradient; A pressure build-up test performed on Palm lA (3S-26~.i tf7Øl indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or, 11$ppg EMW (equivalent mud weight). ../' The maximum potential surface pressure (MPSP) while drilling 3S-21 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5841' tvd: MPSP =(5841 ft)*(0.62 - 0.11 psi/ft) = 2979 psi / (8) data on potential ga.t; zones~' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally qeo-pressured strata, lost circulation zones, and zones that have ð propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the tollowing item~ except for an item a/ready on file wIth the commission and Identified in the application: (5) ð description of the procedure for conducting formation integrity tests, as required under 20 MC 25, 030(f); A procedure is on file with the commission for performing LOT's. For 3S-21 the procedure will be ,.,- followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) J II~ ¡r /~ F,' 'i~J f r'~} ·L:·¡ ~:/ i ~ ~ 35-21 PERMIT IT. DOC Page 3 of 7 Printed: 17-Feb-03 ) Apr,õ".ation for Permit to Drill, We1l3S-21 , Revision No.O Saved: 17-Feb-03 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit tv Drill must be accompanied by eadJ of tile tollowing item5~ except tor an item already on file with tfle c;vmmission and identifìed in the applk<.ïtion: (6) a i.:vmplete proposed ca~ing and cementing program as required by 20 MC 25.030.- and a descríption of'any slotted liner; pre- perf'orated liner; or screen to be 1Ì7stallect: Casing and Cementing Program Hole /' v'/ Top Btm CsglTbg Size Weight Length MD/TVD MDITVD 00 (in) (in) (lblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated r9 ". BTC / /..-' 9-5/8 12-1/4 4 L-80 3601' 28'/28' 3629'/2612' Lead: 580 sx 10.7 ppg AS Lite /"'" Tail: 300 sx 12.0 ppg 'LiteCRETE' . (Yield=2.40 cuft/sk) ",,"""'\ Planned TOC=Surface , I " BTC-Mod/9966' 7 8-1/2 (j L-80 28'/28' 9994'/6027' 290 sx 15.8 ppg 'G' w/ /" add. ..._''''j Planned TOC=~7'/ MD 3-1/2 9.3 L-80 EUE 8rd 9269' 28' / 28' 9297'/5652' SAB- 3 packer set at Mod 9297' MD. If 7" casing must be top-set above the Kuparuk C sand, a 3 112" production liner will be used and an exception to 20 AAC 25.412 (b) is requested. The distance between seals at the top of the 3 112" liner and the top perforation will exce~OO' MD. In the top-set case, the distance between the seals and the top perforation will be ""400' MD. An adequate leak-off test of the 7" casing shoe, combined with a cement bond log of the liner section below the 7" casing shoe will provide proof of zonal isolation between the seals and the perforated interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following Item5~ except for an item already on file with the commi~-¡on and identifìed in the application: (7) a diagram and de/iC!iption of the divetter system as required by 20 AAC 25.035, unless this requkement is waived by the commission under 20 AAC 25.035(17)(2); Please reference diverter schematic on file for Nabors 7ES. /' 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a PermIt to DI7/1 must be ac.-companied by each or the following items, except for an item already on file with the commission and identIfied in the application: (8) a drilling flUId program" including a diagram and descríption of the dn/ling fluid system" as required by 20 AAC 25. 033/ Drilling will be done using mud systems having the following properties: ~iJ l /:. ,:¡~ ;: I~ L If ,1 ,¥ \,.,~ ~ j iU! 35-21 PERMIT IT.DOC Page 4 of 7 Printed: 17-Feb-03 ) Apr':lltion for Permit to Drill, Well 3S-21 ) Revision No.O . Saved: 17-Feb-03 Surface Hole mud properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value /" Density (ppg) 8.6 9.0-9.2 =:;9.4* <9.4 * Funnel Viscosity 120-150 120-150 120-150 120-150 (seconds) Yield Point 35-55 30-40 30-40 35-55 (cP) Plastic Viscostiy 8-15 11-22 15-30 15-30 (lb1100 sf) 10 second Gel 1 0-30 1 0-30 1 0-30 1 0-30 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 25-50 25-50 Strength (lb1100 sf) pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 8.5- 9.5 API Filtrate(cc) 12-15 <10 <10 <10 Solids (%) 3-7 6-12 6-12 6-12 * 9.4 if hydrates are encountered Production Hole mud properties initial C40 Top Morraine Top HRZ Kuparuk ./ Density (ppg) 9.5 10.2 10.6 10.8 12.3 / U· , Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (lb1100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (lb1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 15-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation InformatiQn Requirements of 20 AAC 25.005 (c)(9) An application (or a PermIt to On/I must be accompanied by each o( the following items; except for an item already on file wIth the commission and Identified li7 the application: (9) for an exploratory or stratigraphic test welt a tabulation setting out the depths of predicted abnormally geo-pressured strata as requked by 20 MC 25. 033(f}; N/A - Application is not for an exploratory or stratigraphic test well. J r: ~ l,",\ ~ " ~ ,,, , : ~r · g ~I<-"¡ ..'¡ "ø 3S-21 PERMIT IT. DOC Page 5 of 7 Printed: 17-Feb-03 ) AP"":<:,.:rtion for Permit to Drill, Well 3S-21 ) Revision No.O Saved: 17-Feb-03 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must' be accompanied by eaä7 of tile followíng item5~ except t(Jr an item already on file with the commíssion and identified in the application: (10) for an exploratory or stratigraphíc test wel¿ a sei~7TJic refraction or reflection analy~is as required by 20 MC 25.061(a},· N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill mlJ!:>t be accompanied by eaä7 of tt7e following Item!:;"", except for an item already on file with the commis.r;;ion and Identified in the applic.:Jtion: (11) for a well dlilled timn an off...;,fJOre platform, mobile bottom-founded structure, jac.*-up tigl' or floating drilling vesse¿ an analysis of seabed conditions as required by 20 AAC 2S:06.l(b),: N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items" f~xcept for an item already 0/7 file with the commi!:l"Sion and Identttìed in the application: (12) eVIdence sÝJowing that the requirements of 20 MC 25,02.5' {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application tor a Pennit to Ol7ïl must be accompanied by each or the following item!'.., exæpt for an item already on file wl¥!l the commission {md Identitìed in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. / 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/S" surface casing point according to directional plan. No LWD logging /- equipment required. 4. Run and cement 9-5/S" 40#, L -SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches ~ t su ace. If cement does not circulate to surface, perform top job. Install and test BOPE to 00 psi. Test casing to 2500 psi. 5. IUout cement and 20' of new hole. Perform LOT. 6. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement. / Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). A cement bond log will be performed prior to perforating the well. 7. Run 3-1/2" 9.3#~~ Srd EUE Srd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer: above top planned perforation, shear out of PBR, P/U tubing hanger, and /' land tubing. Pr re test tubing to 3500 psi. Pressure test 3 112" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. Note: If the 7" 26# L -SO BTCM casing must be top-set above the Kuparuk C sand, 6 l/S" hole will be ~ drilled to total depth according to the directional plan and a 3 V2" 9.3# L-SO SLHT liner will be~na cemented across the productive interval. The cement bond log will be done after moving the rig off the well. O r ~ ,~ ~ ro ~", , 1'~~:.õii2\~ t \; I ~ . m J ~¡þ'¡ Ii 'JI!I 38-21 PERMIT IT. DOC Page 6 of 7 Printed: 17-Feb-03 '\ v Ap...t:~.rtion for Permit to Drill, Well 38-21 } Revision No.O .. Saved: 17-Feb-03 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25,005 (c)(14) An application for a Permit to Drill mu.~tc be accompanied by each of the fol/owing items, except for an item a/ready on file with th{J commission and Identified in the applic.;¡llÒn: (14) a general des-cription of how the operator plans to dispose of drilling mud and cuttings and a .';.tatement of whether the operator lí1tend~ to request authorization under 20 AAC 25'.080 for an annular disposal opera!jon in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 3S pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 35-21 for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. / 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. o ru ,.,¡ d ;j~L 35-21 PERMIT IT. DOC Page 7 of 7 Printed: 17-Feb-03 ';J Sperry-Sun Drilling Services ConocoPhillips Ala - Western Nor, Ku --' c :1:) evised: 17 February, 2003 --"t~.__- _ _ ;~ t='-' " ., - ) ~ . Proposal Report u.~ t;¡--.- 17 February, 2003 Surface Coordinates: 5993865.01 N, 476052.12 E (70023' 39.7235" N, 209048' 18.5518" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 c / -- Kelly Bushing: 55. 80ft above Mean Sea Level c=;r--I' .. -Y-'" If! DRILLING SERVICES A Halliburton Company Proposal Ref: pro 10027 o ~~~..- - 1000 - 2000 - ::J (j) ~ CJ Co u) 3000 - L{) ~~] II aJ ~-. ~ (f;"'-'c ES : . ~ .c Õ. () .' 0 ""-----..;:..-~ (ij ""'-T 4000 - d';~ () t ì~ () > 5000 - it: o o o II .>= o .f;; (¡) 6000- ëõ o rJ) Scale: 1 inch = 1000f! DrillOuest 3.03.02.002 O(~1~~~'~%~~~~,';~' ';,:i ~~~'é~l_.o___ ~-~~_._ = ~_ -' ;; -- ~ ~. p~~~~- 35-21 Target (150' Radius Circle) ~. -~"-~ 5840.80' TVD, 5828.52' S, 4208.47' W / Total Depth: 9994.00ft MD, 6027.07ft TVD (1943' FSL & 782' FEL, SEC. 24-T12N-R7E) I I I I 4000 5000 6000 7000 SHL (2551 FNL & 1207' FEL, SEC. 18- T12N - R8E) / _/ Beg;o D;r @ 2,0"/100' (;0 12-114" Hole). 200,00. MD, 200,000 TVD ~ Continue Dir @ 2.00/100ft : 500.00ft MD, 499.45ft TVD ($)" .<iI" r'::---- locrease;o D;r Rate @ 4,0"/100' . 700,00' MD, 69' A" TVD I I I I End Dir, Start Sail @ 57.55° : 1943.91 ft MD, 1707.98ft TVD ~... 'u(Y.ø'~:; ~ - -- -. . .-- - ---- -~..- - ~ 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 3629.00ft MD, 2612.08ft TVD 9-5/8" Csg PI. MD: 3629,0011 TVD: 2612.0811 o I 1000 I 3000 I 2000 ConocÓÁ,illips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 35-21 (wp07) _s~·.. ...·.·.'\.'k'.~.·... . ....',..... ::T: -----' Reference is True North Well: Current Well Properties 38-21 Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates : 5993865.01 N, 476052.12 E 20.72 N. 402.95 W 70023' 39.7235" N, 2090 48' 18.5518" E 2551' FNL & 1207' FEL, SEC. 18- T12N - R8E 55.8Oft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: A VE Plan SpSi 'I'Y-EiUl1 ÞA1L'LIN-m SER'\iU:eS A Halliburton Company -' 7" Csg PI. MD: 9994.00ft TVD: 6027.0711 I 8000 ') /, ) '?~ ConocoPhillips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) Reference is True North Well: Current Well Properties 3S-21 Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geo9raphical Coordinates: 5993865.01 N, 476052.12 E 20.72 N, 402.95 W ~~~f,3~~t~2~~~~'F~ce'S~~:~'~~i~;~ _ R8E 55.80ft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: 35-21 (wp07) APPROVED Plan -5000 -4000 -3000 -2000 -1000 0 Scale: 1 inch = 1000ft I I I I SHL (2:S1' FNL & 1207' FEL. :EC, 'B. T'2N . RBE) 0-- _ _ ____ _ _Beg;" o;~ ~'~(;" 12~/~:~~D.200~TVD~'_ __ _ __ 0 . . rVD~ Continue Dlr @ 2.00/100ft : 500.00ft MD, 499.45ft / / I Increase in Dir Rate@4.00/100ft:700.00ftMD,697.47ft TVD ~vD.' 16Qrl.00~ End Dir, Start Sail @ 57.55°: 1943.91ft MD, 1707.98ftTVD C/ Q) c: 1: 't:: o Z -3000 - Sp:I!r"r"Y-SUI1 ~RlLLJNG SEAYICES A Halliburton Company - -1000 -1000 - 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 3629.00ft MD, 2612.08ft -2000 - 9-5/8' CS9 PI. MD: 3629.00ft TVD: 2612.08ft - -2000 - -3000 C/ Q) c: 1: t:: o Z -4000 - - -4000 3S-2/ Target (ISO' Radi/ls Cirell') 5840.80' TV/), 582852' S. 420S.47' W -5000 - - -5000 ::::: o o o II .>::. <..1 .~ TARGET: 9646.82ft MD, 5840.80ft TVD (2179' FSL & 601' FEL, Sec 24- T12N-R7E) ::::: o o o II .>::. <..1 .~ 7" CS9 PI. MD: 9994.0011 TVD: 6027.07ft -6000 - - -6000 <D (ã <..1 C/ Total Depth: 9994.00ft MD, 6027.07ft TVD (1943' FSL & 782' FEL, SEC. 24-T12N-R7E) <D (ã <..1 C/ I -5000 I -4000 I -3000 I -2000 I -1 000 o Scale: 1 inch = 1000ft Eastings DrillQuest 3.03.02.002 ORf n.~!ir I ,1 ,1""'0 ~ Of: r::~ t '.c' ~I~ 'i ,",,:¡, \Ic_:' I' " "IIP" ,,1 ConocoPhillips Alaska, Inc. 38-21 (wp07) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS v.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) 0.00 0.00 0.00 -55.80 0.00 0.00 N 0.00 E 5993865.01 N 476052.12 E 0.00 0.00 SHL "-' 200.00 0,00 0.00 144.20 200.00 0,00 N 0,00 E 5993865.01 N 476052.12 E 0,00 0,00 Begin Dir in 12-1/4" Hole 500.00 6.00 180.00 443.65 499.45 15,69 S 0.00 E 5993849.32 N 476052.07 E 2.00 12.73 Continue Dir @ 2.00/100ft 700.00 10.00 180.00 641.67 697.47 43,52 S 0,00 E 5993821.49 N 476051.98 E 2.00 35.30 Increase DSL to 4.0°/1 oott 1678.36 47.04 214.63 1490.00 1545.80 438.54 S 211.74 W 5993427.15 N 475838.98 E A.OO 479.54 B. Permafrost 1943.91 57.55 216.59 1652.18 1707.98 608.95 S 334.09 W 5993257.13 N 475716.08 E 4.00 689,33 End Dir; Start Sail a 2508.31 57.55 216.59 1955.00 2010.80 991.40 S 617.97 W 5992875.60 N 475430,97 E 0.00 1165.58 T. West Sak 3337.72 57.55 216.59 2400.00 2455.80 1553.42 S 1035.15 W 5992314.92 N 475012.00 E 0.00 1865.44 B. West Sak ~~J 3629.00 57.55 216.59 2556.28 2612.08 1750.79 S 1181.65 W 5992118.01 N 474864.86 E 0.00 2111 .22 9-5/811 Csg pt n. Drill out 8-1/211 Hole .-.., 3729.13 57.55 216.59 2610.00 2665.80 1818.64 S 1232.01 W 5992050,33 N 474814.29 E 0.00 2195.71 C-80 (K-10) _ ç~ ') 6357.14 57.55 216.59 4020.00 4075.80 3599.40 S 2553.84 W 5990273.81 N 473486.76 E 0.00 4413.24 C-40 (K-3) ~--~ .., 8500.56 57.55 216.59 5170.00 5225.80 5051,80 S 3631.93 W 5988824.87 N 472404.03 E 0.00 6221.86 Top Morraine 8975.84 57.55 216.59 5425.00 5480.80 5373.86 S 3870.98 W 5988503.58 N 472163.94 E 0.00 6622.90 Top HRZ ~:~ 9311 .33 57.55 216.59 5605,00 5660.80 5601 .19 S 4039.73 W 5988276.79 N 471994.47 E 0.00 6905.99 Base HRZ ~~ 9516.35 57.55 216.59 5715.00 5770.80 5740.12 S 4142.85 W 5988138.20 N 471890.91 E 0.00 7078.99 K-1 9646.82 57.55 216.59 5785.00 5840.80 5828.52 S 4208.47 W 5988050.00 N 471825.00 E 0.00 7189.08 TARGET 9693.42 57.55 216.59 5810.00 5865.80 5860.10 S 4231.91 W 5988018.50 N 471801.46 E 0.00 7228.40 Miluveach 9994.00 57.55 216.59 5971 ,27 6027.07 6063.78 S 4383.09 W 5987815.31 N 471649.62 E 0.00 7482.03 Total Depth ,.. 7" Csg P1. t-' Western North Slope C) :J:~] <&. ~~:~.~..~ c~-_~) ~~_-:-..::".. ~ ~--~~ ~~ Measured Depth (ft) 28.10 100.00 200.00 300.00 400.00 500.00 Incl. 0.00 0.000 Azim, 0.000 0.000 0.000 0.000 2.000 180.000 16.854 20.588 24.404 28.268 32.163 51 .853 55.813 57.552 57.552 57.552 57.552 57.552 57.552 17 February, 2003 - 4:53 0.000 0.000 0.000 4.000 180.000 6.000 180.000 600.00 8.000 180.000 700.00 10.000 180.000 800.00 13.270 191.551 198.439 202.929 206.079 208.41 r 21Q.~1 215.595 216.298 216.586 2000.00 57.552 216.586 2100.00 57.552 216.586 216.586 216.586 216.586 216.586 216.586 Sub-Sea Depth (ft) -55.80 -27.70 44.20 144.20 244.18 344.04 443.65 542.90 641.67 739.61 836.1.7. \iil: ~----:- .-,.-. c·1;jc~9.25-" :_..~c-, _<'__00' ~~~~:~~>¡~:gðgf;;- :.··.~..·.~;!.tfß' ~ ~~~:~~!t"'~~~~:~;<"-2l4.629- 1700.0Ó?:/:;:~1~89a}i214.811 1282.02 1360.76 1435.08 1490.00 1504.63 1569.06 1628.07 1652.18 1682.28 1735.93 1789.58 1843.24 1896.89 1950.54 1955.00 Vertical Depth (ft) 1337.82 1416.56 1490.88 1545.80 1560.43 1624.86 1683.87 1707.98 1738.08 1791.73 1845.38 1899.04 1952.69 2006.34 2010.80 0.00 28.10 100.00 200.00 299.98 399.84 499.45 Sperry-Sun Drilling Services Proposal Report for 35-21 Plan - 35-21 (wp07) Revised: 17 February, 2003 Local Coordinates Northings Eastings (ft) (ft) 88.47 S 118.42 S 153.19S 192.58 S 236.43 S 284.50 S 336.56 S 392.37 S 438.54 S 451.65 S 514.11 S 579.44 S 608.95 S 646.96 S 714.72 S 782.49 S 850.25 S 918.01 S 985.77 S 991.40 S 0.00 N 0.00 E 900.00 1000.00 1100.00 1200.00 1300.00 .' 1800.00 ' 1900.00 1943.91 2200.00 2300.00 2400.00 2500.00 2508.31 0.00 N 0.00 N 0.00 N 1.75 S 0.00 E 0.00 E 2.30W 9.19W 20.63 W 36.56 W 56.92 W 81.60 W 110.48 W 143.42 W 180.26 W 211.74 W 220.82 W 264.91 W 312.30 W 334.09 W 362.31 W 412.60 W 462.90 W 513.20 W 563.50 W 613.79 W 617.97 W Page2of7 Global Coordinates Northings Eastings (ft) ( 5993865.01 N 5993837.13 N 5993821.49 N 5993801.56 N 5993776.57 N 5993746.65 N 5993711.94 N 5993672.61 N 5993628.85 N 5993580.87 N 5993528.91 N 5993473.22 N 5993427.15 N 5993414.07 N 5993351.76 N 5993286.57 N 5993257.13 N 5993219.21 N 5993151.61 N 5993084.01 N 5993016.41 N 5992948.81 N 5992881.21 N 5992875.59 N 476052.11 E 476052.10 E 476052.07 E 476052.03 E 476051.98 E 476049.62 E 476042.65 E 476031.11 E 476015.07 E 475994.58 E 475969.76 E 475940.73 E 475907.62 E 475870.60 E 475838.98 E 475829.85 E 475785.57 E 475737.97 E 475716.08 E 475687.74 E 475637.23 E 475586.71 E 475536.20 E 475485.69 E 475435.17 E 475430.97 E 2.000 2.000 2.000 2.000 2.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ConocoPhillips Comment 0.00 SHL (2551' FNL & 1207' FEL, SEC. 1 T12N - R8E) 0.00 0.00 0.00 Begin Dir @ 2.00/100ft (in 12-114" Hole): 200.00ft MD, 200.00ft TVr 1.42 _I 5.66 12.73 Continue Dir @ 2.00/100ft: 500.00ft MD, 499.45ft TVD 22.61 35.30 Increase in Dir Rate @ 4.00/100ft : 700.00ft MD, 697.47ft TVD 52.81 77.12 108.11 145.63 189.50 239.49 295.37 356.87 423.68 479.54 495.49 B. Permafrost 571.93 652.64 689.33 '-' End Dir, Start Sail @ 57.55° : 1943.91 MD, 1707.98ft TVD 736.66 821.04 905.42 989.80 1074.18 1158.56 1165.58 T. West Sak DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 35-21 Plan - 35-21 (wp07) Revised: 17 February, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) (ft) ( 2600.00 57.552 216.586 2004.19 2059.99 1053.53 S 5992813.61 N 1242.95 2700.00 57.552 216.586 2057.85 2113.65 1121.29 S 5992746.01 N 1327.33 2800.00 57.552 216.586 2111.50 2167.30 1189.05 S 599267 .41 N 1411.71 2900.00 57.552 216.586 2165.15 2220.95 1256.81 S 59 N 1496.09 3000.00 57.552 216.586 2218.80 2274.60 1324.57 S 5 N 1580.47 3100.00 57.552 216.586 2272.46 2328.26 .62 N 475132.09 E 0.000 1664.85 _...........r 3200.00 57.552 216.586 2326.11 2381.91 408.02 N 475081.57 E 0.000 1749.23 3300.00 57.552 216.586 2379.76 2435.56 992340.42 N 475031.06 E 0.000 1833.61 3337.72 57.552 216.586 2400.00 2455.80 5992314.92 N 475012.00 E 0.000 1865.44 B. West Sak 3400.00 57.552 216.586 2433.42 2489.22 5992272.82 N 474980.54 E 0.000 1917.99 3500.00 57.552 216.586 2487.07 116.77W 5992205.22 N 474930.03 E 0.000 2002.37 3600.00 57.552 216.586 2540.72 167.07 W 5992137.62 N 474879.51 E 0.000 2086.75 3629.00 57.552 216.586 2556.28 181.65 W 5992118.01 N 474864.86 E 0.000 2111.22 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: a 3629.00ft MD, 2612.08ft TVD ....~~-. 9 5/8" Casing ~~ ~~.J 3700.00 57.552 216.586 2594: 1798.90 S 1217.36 W 5992070.02 N 474829.00 E 0.000 2171.13 ~. 3729.13 57.552 216.586 ú 26,1 a; 1818.64 S 1232.01 W 5992050.33 N 474814.29 E 0.000 2195.71 C-80 (K-10) r~ ".:' .;..;- 3800.00 57.552 :i~iJ~'~Jr 2703.83 1866.66 S 1267.66 W 5992002.42 N 474778.48 E 0.000 2255.51 3900.00 57.552 2757.48 1934.42 S 1317.96 W 5991934.82 N 474727.97 E 0.000 2339.89 ..._-~, 4000.00 57.5qg{{r 2811 .13 2002.18 S 1368.26 W 5991867.22 N 474677.46 E 0.000 2424.27 - ~_.-:__::~Ã 41 00.Op~?,57 .5~~\; 2864.78 2069.94 S 1418.55W 5991799.62 N 474626.94 E 0.000 2508.65 r-- 4200. o'(k:¿.'~I.552~~;!;( ,êJ¡6.5à6N:: 2862.64 2918.44 2137.71 S 1468.85 W 5991732.02 N 474576.43 E 0.000 2593.03 ".¡: --:-----;,.-. ¡~.-_. - 4300. 00;~,1 è·h5~2 ';>;?16.586 2916.29 2972.09 2205.47 S 1519.15 W 5991664.42 N 474525.91 E 0.000 2677.41 4400.00>' 57.552 0'216.586 2969.94 3025.74 2273.23 S 1569.45 W 5991596.82 N 474475.40 E 0.000 2761.79 4500.00 ';' 57.552 216.586 3023.59 3079.39 2340.99 S 1619.74 W 5991529.22 N 474424.88 E 0.000 2846.17 -'---, 4600.00 57.552 216.586 3077.25 3133.05 2408.75 S 1670.04 W 5991461.62 N 474374.37 E 0.000 2930.55 4700.00 57.552 216.586 3130.90 3186.70 2476.51 S 1720.34 W 5991394.02 N 474323.86 E 0.000 3014.93 4800.00 57.552 216.586 3184.55 3240.35 2544.27 S 1770.64 W 5991326.42 N 474273.34 E 0.000 3099.31 4900.00 57.552 216.586 3238.21 3294.01 2612.03 S 1820.94 W 5991258.83 N 474222.83 E 0.000 3183.69 5000.00 57.552 216.586 3291 .86 3347.66 2679.79 S 1871.23 W 5991191.23 N 474172.31 E 0.000 3268.07 5100.00 57.552 216.586 3345.51 3401.31 2747.55 S 1921.53 W 5991123.63 N 474121.80 E 0.000 3352.46 5200.00 57.552 216.586 3399.16 3454.96 2815.31 S 1971.83 W 5991056.03 N 474071.28 E 0.000 3436.84 17 February, 2003 - 4:53 Page30f7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 38-21 Plan - 38-21 (wp07) Revised: 17 February, 2003 ConocoPhillips Western North Slope Global Coordinates Northings Eastings . (ft) (ft Local Coordinates Northings Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Measured Depth (ft) Comment Incl. Azim. 5990988.43 N 5990920.83 N 599085 .23 N 59 N 5 N 2883.08 S 2950.84 S 3018.60 S 3086.36 S 3154.12S 3521.22 3605.60 3689.98 3774.36 3858.74 3452.82 3506.4 7 3560.12 3613.77 3667.43 3508.62 3562.27 3615.92 3669.57 3723.23 216.586 216.586 216.586 216.586 216.586 5300.00 5400.00 5500.00 5600.00 5700.00 57.552 57.552 57.552 57.552 57.552 .43 N 582.83 N . 990515.23 N 5990447.63 N 5990380.03 N 473768.20 E 473717.68 E 473667.17 E 473616.65 E 473566.14 E 0.000 0.000 0.000 0.000 0.000 3943.12 4027.50 4111.88 4196.26 4280.64 3721.08 3774.73 3828.38 3882.04 3935.69 3776.88 3830.53 3884.18 3937.84 3991.49 216.586 216.586 216.586 216.586 216.586 57.552 57.552 57.552 57.552 57.552 5800.00 5900.00 6000.00 6100.00 6200.00 -' 473515.63 E 473486.76 E 473465.11 E 473414.60 E 473364.08 E 2525.10 W 2553.84 W 2575.40 W 2625.70 W 2675.99 W 5990312.43 N 5990273.81 N 5990244.83 N 5990177.23 N 5990109.63 N 0.000 0.000 0.000 0.000 0.000 4365.02 4413.24 4449.40 4533.78 4618.16 4045.14 4075.80 409~:ßO ' 4152.45 - 42Q6.tO 3989.34 4020.00 4043.00 4096.65 4150.3 57.552 57.552 57.552 57.552 57.552 216.586 216.586 216.586 216.586 216.586 6300.00 6357.14 6400.00 6500.00 6600.00 C-40 (K-3) S ;-õ3696.21 S 3763.97 S 'Q ::F_1 JltlJ{J~~!~ 5990042.03 N 5989974.44 N 5989906.84 N 5989839.24 N 5989771.64 N 473313.57 E 473263.05 E 473212.54 E 473162.02 E 473111.51 E 3831.73 S 3899.49 S 3967.25 S 4035.01 S 4102.77 S 2726.29 W 2776.59 W 2826.89 W 2877.18 W 2927.48 W 0.000 0.000 0.000 0.000 0.000 4702.54 4786.92 4871.30 4955.68 5040.06 25 5 ..'4313.41 4367.06 4420.71 4474.36 57.552 57.552 57.552 57.552 57.552§ 6700.00 6800.00 6900.00 7000.00 7100.00 ~: ) ~~ ........,.... _...·"21 Hgg'g~1e:'!~i~~ç,~~:i!f 7500.00·:;-;. 57.552 ' 216.586 7600.00': 57.552 216.586 2977.78 W 3028.08 W 3078.37 W 3128.67 W 3178.97 W 5989704.04 N 5989636.44 N 5989568.84 N 5989501 .24 N 5989433.64 N 473061.00 E 473010.48 E 472959.97 E 472909.45 E 472858.94 E 4170.53 S 4238.29 S 4306.06 S 4373.82 S 4441.58 S 0.000 0.000 0.000 0.000 0.000 5124.44 5208.82 5293.20 5377.58 5461.97 4472.22 4525.87 4579.52 4633.17 4686.83 4528.02 4581.67 4635.32 4688.97 4742.63 cl'--- ',~ 3229.27 W 3279.56 W 3329.86 W 3380.16 W 3430.46 W 5989366.04 N 5989298.44 N 5989230.84 N 5989163.24 N 5989095.64 N 472808.42 E 472757.91 E 472707.39 E 472656.88 E 472606.37 E 4509.34 S 4577.10 S 4644.86 S 4712.62 S 4780.38 S 0.000 0.000 0.000 0.000 0.000 5546.35 5630.73 5715.11 5799.49 5883.87 4740.48 4794.13 4847.78 4901.44 4955.09 4796.28 4849.93 4903.58 4957.24 5010.89 57.552 57.552 57.552 57.552 57.552 216.586 216.586 216.586 216.586 216.586 7700.00 7800.00 7900.00 8000.00 8100.00 5989028.04 N 5988960.44 N 5988892.84 N 5988825.24 N 5988824.87 N 472555.85 E 472505.34 E 472454.82 E 472404.31 E 472404.03 E 4848.14 S 4915.90 S 4983.67 S 5051.43 S 5051.80 S 3480.75 W 3531.05 W 3581.35 W 3631.65 W 3631.93 W 0.000 0.000 0.000 0.000 0.000 5968.25 6052.63 6137.01 6221.39 6221.86 Top Morraine 5008.74 5062.40 5116.05 5169.70 5170.00 5064.54 5118.20 5171.85 5225.50 5225.80 216.586 216.586 216.586 216.586 216.586 8200.00 8300.00 8400.00 8500.00 8500.56 57.552 57.552 57.552 57.552 57.552 Dril/Quest 3.03.02.002 17 February, 2003 - 4:53 Page4of7 Sperry-Sun Drilling Services Proposal Report for 35-21 Plan - 35-21 (wp07) Revised: 17 February, 2003 ConocoPhíllips Western North Slope Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (~ Sub-Sea Depth (ft) Vertical Depth (ft) Measured Depth (ft) Comment Incl. Azim. 5988757.64 N 5988690.04 N 598862 .45 N 59 N 5 N 5119.19S 5186.95 S 5254.71 S 5322.47 S 5373.86 S 5223.35 5277.01 5330.66 5384.31 5425.00 5279.15 5332.81 5386.46 5440.11 5480.80 6305.77 6390.15 6474.53 6558.91 6622.90 Top HRZ 6643.29 6727.67 6812.05 6896.43 6905.99 Base HRZ 57.552 57.552 57.552 57.552 57.552 216.586 216.586 216.586 216.586 216.586 8600.00 8700.00 8800.00 8900.00 8975.84 .25 N 419.65 N . 988352.05 N 5988284.45 N 5988276.79 N 472151.74 E 472101.22 E 472050.71 E 472000.19 E 471994.47 E 0.000 0.000 0.000 0.000 0.000 5437.96 5491.62 5545.27 5598.92 5605.00 5493.76 5547.42 5601.07 5654.72 5660.80 57.552 57.552 57.552 57.552 57.552 216.586 216.586 216.586 216.586 216.586 9000.00 9100.00 9200.00 9300.00 9311.33 .-" 4084.33 W 4134.62 W 4142.85 W 4184.92 W 4208.47 W 5988216.85 N 5988149.25 N 5988138.20 N 5988081.65 N 5988050.00 N 471949.68 E 471899.16 E 471890.91 E 471848.65 E 471825.00 E 0.000 0.000 0.000 0.000 0.000 6980.81 7065.19 7078.99 7149.57 7189.08 5652.57 5706.23 5715.00 5759.88 5785.0.\&;: 5708.37 5762.03 577q.;~0" .581 5fô8c·. ~40._80 57.552 57.552 57.552 57.552 57.552 216.586 216.586 216.586 216.586 216.586 9400.00 9500.00 9516.35 9600.00 9646.82 S ¿c.5796.80 S 5828.52 S K-1 c:::, ~::1 TARGET: 9646.821t MD, 5840.80ft TVD (2179' FSL & 607' FEL, Sec 24- T12N-R7E) Kuparuk Target - 3S-21 , 150.00 Radius., Currel Target ·~;~~~i::~~o! --'::"'~~3 ~- "0"· .,:. ;~..:';:.'- i~~~.~I~i¡!~;~;!.~~'··· 9994.00·C;!; 57.552'216.586 4231.91 W 4235.22 W 4285.52 W 4335.81 W 4383.09 W 5988018.50 N 5988014.05 N 5987946.45 N 5987878.85 N 5987815.31 N 471801.46 E 471798.14 E 471747.62 E 471697.11 E 471649.62 E Miluveach 5860.10 S 5864.56 S 5932.32 S 6000.08 S 6063.77 S 0.000 0.000 0.000 0.000 0.000 7228.40 7233.95 7318.33 7402.71 7482.03 5810.00 5813.53 5867.19 5920.84 5971.27 5865.80 5869.33 5922.99 5976.64 6027.07 __.:J ç=- Total Depth: 9994.00ft MD, 602- TVD (1943' FSL & 782' FEL, .~ SEC. 24-T12N-R7E) 7" Casing All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 3S-21. Northings and Eastings are relative to 3S-21. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 3S-21 and calculated along an Azimuth of 215.8000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9994.00ft., The Bottom Hole Displacement is 7482.04ft., in the Direction of 215.8610 (True). 17 February, 2003 - 4:53 Dri/lQuest 3.03.02.002 PageS oi7 CJ =0 ~>.J-:-.._'I r-~-· .~~ -;~) -~~ M---~ Western North Slope Comments Sperry-Sun Drilling Services Proposal Report for 35-21 Plan - 35-21 (wp07) Revised: 17 February, 2003 Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ConocoPhillips 0.00 200.00 500.00 700.00 1943.91 0.00 0.00 N 200.00 0.00 N 499.45 15.69 S 697.47 43.52 S 1707.98 608.96 S 2612.08 1750.79 S 5840.80 5828.52 S 6027.07 6063.77 S 3629.00 9646.82 9994.00 Formation Toos Measured Depth (ft) Vertical Depth (ft) ·:üi~~~i~ 1678.36:. 2508.31;;' 3337.72.':; 3729.13,!/ 6357.14'· 1 545:~6° ';, ;;1jia,(} 4075.80" ÚfQft'ôò 19S:~pO 2400.00 2610.00 4020.00 -~ 8500.56 5225.80 5170.00 8975.84 5480.80 5425.00 9311.33 5660.80 5605.00 9516.35 5770.80 5715.00 9646.82 5840.80 5785.00 9693.42 5865.80 5810.00 17 February, 2003 - 4:53 0.00 E 0.00 E 0.00 E 0.00 E 334.09 W SHL (2551' FNL& 1207' Begin Dir @ 2.0 Contin ue Inerea End Dir; 2N - R8E O.OOft MD, 200.00ft TVD D, 499.45ft TVD : 700.00ft MD, 697.47ft TVD . 1943.91ft MD, 1707.98ft TVD -' Drill out 8-1/2" Hole: 3629.00ft MD, 2612.08ft TVD ET: 9 .82ft MD, 5840.80ft TVD (2179' FSL & 607' FEL, See 24-T12N-R7E) epth : 9994.00ft MD, 6027.07ft TVD (1943' FSL & 782' FEL, SEC. 24-T12N-R7E) -' Eastings Dip Up-Dip Formation Name (ft) Angle Dim. 438.54 S 211.74W 0.000 359.816 B. Permafrost 991.40 S 617.97 W 0.000 359.816 T. West Sak 1 553.42 S 1035.15 W 0.000 359.816 B. West Sak 1818.64S 1232.01 W 0.000 359.816 C-80 (K-1 0) 3599.40 S 2553.84 W 0.000 359.816 C-40 (K-3) / -- 5051.80 S 3631.93 W 0.000 359.816 Top Morraine 5373.86 S 3870.98 W 0.000 359.816 Top HRZ 5601.19 S 4039.73 W 0.000 359.816 Base HRZ 5740.12 S 4142.85 W 0.000 359.816 K-1 5828.52 S 4208.47 W 0.000 359.816 Kuparuk 5860.10 S 4231.91 W 0.000 359.816 M iluveaeh Page6of7 DrillQuest 3.03.02.002 <J :Jr:1 L: ') -""'" .- _....;::_~_-1Â1 c-~ t~ Sperry-Sun Drilling Services Proposal Report for 35-21 Plan - 35-21 (wp07) Revised: 17 February, 2003 Western North Slope Casing details Fr om Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Casing Detail <Surface> <Surface> 3629.00 2612.08 <Surface> <Surface> <Run-TO> <Run-TO> 9 5/8" Casing 7" Casing Tarqets associated with this welloath Target Name Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape 3S-21 5840.80 5828.52 S 4208.47 W 5785.00 5988050.00 N 471825.00 E 700 22' 42.3835" N 2090 46' 15.3794" E Circle Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Target Radius: 150.00ft 17 February, 2003 - 4:53 Page 7 of 7 ConocoPhi/lips -" Target Type Current Target ---' DrillQuest 3.03.02.002 ¡:::: ,S2 ... C':.$ ~ C':.$ 0.- Q.) r./) Q.) ~ ... ¡:::: a ~ -.o~_. ~.:,.~ r- .~ ;-e." .Q.) '"' í;:) ":.'ß J~'--....J-~ Plan:3S-21fPlan: 3S-21 r--I 4:: ~ 36,O-=:~- ~ 2.0 Measured Depth [ft] 3S-09 (3S-09) 3S-16 (3S-16 (Rig Surveys» 3S-26 (3S-26) Plan: 3S-19 (Plan 3S-19F) 3S-1O (3S-1O) 3S-18 (3S-18) 3S-26 (3S-26A) Plan: 3S-19 (Plan: 3S-19) 3S-15 (3S-15) 3S-22 (Plan: 3S-22) Plan: 3S-17 (Plan: 3S-17F) Plan: 3S-24 (plan: 3S-24) 3S-14 (3S-14) 3S-22 (3S-22 (Rig Surveys» Plan: 3S-17 (Plan: 3S-17) Plan: 3S-23 (Plan: 3S-23) ) SPERRY_SUN DES Anticollision Report ) ',."¢~rt1~#by£ "l\i~ld:," .'. ..' ,..' 'R~feF~nce'Si~~.: : 1,~èf~r'~ric¢:W~I(i ..' ,'R~f~J:'~*t~, Wënø~thi'" f'h'inipS; ÄI~sKå ,Oci," .··.,·.KuparukRiver U~it , Kupa'ruk á.S~ád Plån:3S72l, . , Plan:3S~21 ,Jjate: ,. ?/17/2QP$ ',,,',. Tiooe:<O~:Ò4:53 ,..' I' "P~ge: 1 'J' ,I:..',"': : ',: :,..1"',,,,', :,:",:.." "':',1" "',,' ",', ,,',': :' ,"",.',',' '::: ",' ":.:,",1,' : ,I ,::·"1,,,.' ::,1'«':,:"',' "":-:',"'1,"" ,I:" ::1 "" ',:' ",:,,:': ,":'" ,', ':';" :":'," ,.',:' 'I ". .Cø.ørdiJ)ate(NE)R~rel'~n~e:...· ,'Well:Plam3$-21,lirueNofth' ,Verti()aÌ (1:VD) Refere,u¢e: ' RK~,==q~.~¡,M$h5,5,.,8," "" , " .1' i ,Db:,OraGI'e,' NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.10 to 9994.00 ft Maximum Radius: 1215.30 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/15/2002 Validated: No Planned From To Survey ft ft 28.10 500.00 500.00 9994.00 Version: 2 Toolcode Tool Name Planned: 3S-21 (wp07) V11 Planned: 3S-21 (wp07) V11 CB-GYRO-SS MWD Camera based gyro single shot MWD - Standard Casing Points " T'Vi). 'IÐif)rJ:¡ete'r I, ft,.i~ 3629.00 2612.01 9.625 9994.00 6026.73 7.000 fiol~'~lz~' in' . 12.250 8.500 95/8" 7" Summary Ref~fèl;t¿~ I ()tf~et.· Ct~·C~r'~()·(;.o '. ,.4.W~b!.e ,',,:,._ ,. ,,','1 ".1",".'1" <:,' ',"'_": ,I ':-',"'."'::'.::''':''1 'I ~J)' ·;Ml), .' '" Disu.nce·· .·A:re~' .......... ··Deviåt.on 'WarWu '. . n' ·.'t( , : ,'.Jf. 'ft> . H..',' .', """""""~ Kuparuk 3S Pad 3S-09 3S-09 V2 199.29 200.00 240.94 3.80 237.15 Pass: Major Risk Kuparuk 3S Pad 3S-10 3S-10 V6 199.48 200.00 220.49 3.95 216.54 Pass: Major Risk Kuparuk 3S Pad 3S-14 3S-14 V2 298.55 300.00 140.52 4.99 135.55 Pass: Major Risk Kuparuk 3S Pad 3S-15 3S-15 V4 395.94 400.00 119.30 5.69 113.63 Pass: Major Risk Kuparuk 3S Pad 3S-16 3S-16 (Rig Surveys) V3 298.87 300.00 101.19 4.63 96.57 Pass: Major Risk Kuparu k 3S Pad 3S-18 3S-18 V4 496.24 500.00 52.50 7.08 45.51 Pass: Major Risk Kuparu k 3S Pad 3S-22 3S-22 (Rig Surveys) V8 349.99 350.00 17.78 5.20 12.59 Pass: Major Risk Kuparuk 3S Pad 3S-22 Plan: 3S-22 V5 Plan: 3 349.99 350.00 17.78 5.20 12.59 Pass: Major Risk Kuparuk 3S Pad 3S-26 3S-26 V2 795.68 800.00 89.01 11.26 77.89 Pass: Major Risk Kuparuk 3S Pad 3S-26 3S-26A V3 795.68 800.00 89.01 11.26 77.89 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-17 Plan: 3S-17 V1 Plan: 3 495.65 500.00 76.90 8.46 68.47 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-17 Plan: 3S-17F V1 Plan: 495.65 500.00 76.90 8.30 68.63 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-19 Plan 3S-19F V2 Plan: 3 497.06 500.00 36.78 8.09 28.74 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-19 Plan: 3S-19 V1 Plan: 3 497.06 500.00 36.78 8.09 28.74 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-20 Plan: 3S-20 V1 Plan: 3 598.29 600.00 12.19 8.79 3.62 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-23 Plan: 3S-23 V1 Plan: 3 300.27 300.00 40.07 5.67 34.40 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-24 Plan: 3S-24 V1 Plan: 3 250.23 250.00 60.48 4.87 55.61 Pass: Major Risk 0"· I j ~,....-.\:: I:~: "', - i ' ,: ß ,g Ii II \vJJ ~ : , ~ ,i ,= WElL DErAIlS ~ +~·S +fl·W Sonhing Eosting Latitude Longitude Slot 'S·21 20.73 ..W2.96 5993865.00 476052.15 70'23'39.723N 150'1l'41A47W NlA SURVEY PROGRAM Depth Fm Depth To SUIVey/Plan Tool 28.10 500.00 Planned: 3S-21 (wp07) VI CB-GYRO-SS 500.00 9994.00 Planned: 3S-21 (wp07) VI MWD WElLPATH DErAIlS PIan:3S·21 Rig: N7ES Rei. Datum: RKB = 55.8' MSL 55.8Oft V.Section Origin :k~ ~~VD AngI" +NI-S 228.0 0.00 0.00 0.00 COMPA}'¡ì'DEfAllS Phillip. AJaska Inc. ~ CalcuJation M<Ú!Od: MinÌII1m1 C1Ir\'ature r:;:~= ~~;V¿~ North &ror Surface: Elliptical + Casing WmnirIg Memod: Rub; Base<! ANTI-COLLISION SETTINGS 50.00 9994.00 Plan: 3S-21 (wp07 Interval: Tb: Reference: Interpolation Method:MD Depth Range From: 28,10 Maximum Range: 1215.30 ToMD 200 300 500 700 900 1100 1300 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 10000 -- I '- Colour 90 FTom o 200 300 500 700 900 1100 1300 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 35-19 (plan::m>-Im)) o 3S-22 ToMD 200 300 500 700 900 1100 1300 1500 2000 ~ògg -M 4000 5000 -40 6000 7000 8000 9000 10000 -30 PIa,: 3S-20 (Plan: Colour ..ßJ ¡p %- ~ ~ -10 f1> 'ft 'ã-. .';t Q ~. ~1~3S-23 (pI~n: 3S-23) ~ ~ - 0 27, L< ~ "2:/ -30 -40 -M -10 -20 -20 From o 200 300 500 700 900 1100 1300 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 18 (3S-18 -105 -100 r ":=- -'-50 :..:::.! '----- -75 -75 180++ 3S-21 (wp07) Approved Plan Target 3S (2 VSoc 0.00 0.00 10.50 29.12 655.77 7028.01 7314.69 ITace 0.00 0.00 180.00 0.00 41.22 0.00 0.00 DLeg 0.00 0.00 2.00 2.00 4.00 0.00 0.00 100 l!~J05 SECflON Off AILS +FJ-W 0.00 0.00 0.00 0.00 -334.13 4208.92 4383.24 +NI-S 0.00 0.00 -15.69 ·43.52 -609.00 5829.09 6063.94 TVD 28.10 200.00 499.45 697.47 1708.02 5840.80 6026. 7 3 Azi 0.00 0.00 180.00 180.00 216.59 216.59 216.59 c 0.00 0.00 6.00 10.00 57.56 57.56 57.56 MD 28.10 200.00 500.00 700.00 1943.98 9647.43 9994.00 Soc 1 , 3 4 5 6 7 -100 -105 Centre Separation [20ft/in] Centre to [deg] VS Travelling Cylinder Azimuth (TFO+AZI) Centre Separation [50ft/in] Centre to [deg] vs Azimuth (TFO+AZI Travelling Cylinder ) ) 35-21 Drillinq Hazards Summary 12-1/4" Hole / 9-5/8" Casing Interval Event Broach of Cond uctor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation Risk Level I Mitigation Strategy Low Monitor cellar continuously during interval. Low Moderate Moderate Low Low 8-1/2" Hole / 7" CasinQ Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Low Moderate Moderate Moderate If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. r-' Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM I Mitigation Strategy Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. /' / 3S-21 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 OR ~ ,A"":, ~ ~:..,~ A L '.'.., . ¡, n , 1 i U ,J J~j ii' ..\ Page 1 of 1 KRU - 35-21 InjE:..~\or Proposed Completion Schematic Single Completion 16"x30" insulated ~ ~ conductor @ ~ ~ +/- 108' MD I I I I i! I TAM 9-5/8" PortJJ. d Collar Stnd ~ Grade BTC ~ Threads (+/- , 1000' MD/TVD) ~ I ~ Surface csg. ~ 9-5/8"40# L-80 ~ BTC (3629' MD / ~ 2612' TVD) Casing point 100' above the C80 sand C Sand Perfs (to be done after rig moves off) Production csg. 7" 26# L-80 BTCM (+/- 9994' MO) I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ .J ....._-~ :-:-) ~ ~ - o J ï:; ._y~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ q~~~~ l i ~ ~ I I ~ I I ~ I I ~ I L.... ~~ ~~ ~r ~ I ~ I ~ I ~ I..... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ /" ~ ~ ~ ~ ~ ~ ~ ~ ~ ~::;- r _¡.n ï_" ~ ~ ~ ~ ~ ~ ~ J ~ ~ ~ ~ )~ ConocoPhillips 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RO pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Cameo DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. Use of port collar at the discretion of the drilling team. /' 3-1/2" x 1-1/2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'DS' nipple w/2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-112", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +/- 350' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'D' nipple w/2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-112" WL Re-entry Guide w/ shear out sub. Tubing tail 320' above top planned perforation. ./ TO @ 9,994' MD /6,027' TVO (300' MO below Miluveach) Scott L Lowry 02/17/03 O r~ . ,,~,' ;~:,~ f . . \",,.,,1:.: ':' ,,~ ,:f' I ,/ ~I ~,"f! I ~ ~ \¡~Î ,~1 ~', h~ DA;E ~~~1i4(~41311 PAYTOTHE 5í A7 /3 ()~A-t.¡¡'$tÆ /IfCbCe OR-=-OJ¡¿ ~ cJ,~~j~hf» . - . ! S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 700G ST. ATO 1530 ANCHORAGE AK 99501 . ...... CHASE Chase Manhattan Bank USA, N.A. VaJid~P To Dollars '-, 200 White Clay Center Dr, Newark. DE 19711 rt7h MEMO IÞ I: 0 3 ¡. ¡. 0 0 ¡. I. 1.1: 2 ¡. BODO 0 I. 2 7 2 5 711'¡' 0 2 7 ~ 'ife","-c''''~~'~~.·~~~---''''~~'~'1 ,,,,,- ~--;;: -"\!iI. iii~¡¡;¡¡¡'_~' "V ',;~'1T'~' 1$, (ct), fX) .. 0. _....... DOLL.ARS ., . w· .:='&,..... . ; . ~ ) ), . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME I-<Rc\ ~ s -2( PTD# ~ ~ ~ - 63, ! CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (H API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production .should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception tbat may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST ' C()MPANY(C'''I,K'~ (fltill; f'r WELL NAME 1<' f\\JL 35-·21 , FIELD & POOL 0: q ð I. C C2 INIT CLASS / - Lv,4.. C ~ IN ,,1 ADMINISTRATION 1. Permit fee attached. .................... (Q..N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . ~ . ~ N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. .'. . "" N 6. W ell located proper distance from other wells.. . . . . . . . . ~ N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . ~ ~ J1 ~~~~~3~: ~~:~~~¿~~~ ~~~~~;~ ~~~~~I~d~~.: : : : : : : : : : : : : : ~ N 10. Operator has appropriate bond in force. '. . . . . . . . . . . . ge N 11. Permit can be issued without conservation order. . . . . . . . ® N 12. Permit can be issued without administrative approval.. . . . . œ N (Service Well Only) 13. Well located w(in area & strata authorized by injection order#;¿Bø N , (Service Well Only) 14. All wells w/in X mile area ofreview identified. . . . . . . . .. ~N tJø ~u...R.lt~ ,),...... Ao IL " ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . f. N lcP" X ~O I( ~ 108 \ 'rIl) . 16. Surface casing protects all known USDWs. . . . . . . . . . . . N II 1_ 1:- 17. CMT vol adequate to circulate on conductor & surf csg. . . ., . " N 1+ð-ep ~ It~.. . f\~~sÇ , 18. CMT vol adequate to tie-in long string to SUrf. cs. g. . . . . . ", . ~. . "r;.tt--1 b J2 ~.~ A-ù, 19. CMT will cover all known productive horizons. . . . . . . . . . N 20. Casing de.signs adequate for C: T, B.& permafrost. , . . . . . . N .. ¡.~. .' . G ~ 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . , N f\J. 0 .. ~ 1 . 22. If a re-drill, has a 10-403 for abandonment been approved. . . ~ /Út, 23. Adequate wellbore separation proposed.. .'.' . . . . . .. . . N 24. If diverter required,does 'it meet regulations. . '. . . . . . ,.. . ., N 25. Drilling fluid program schema~ic & equip list adequate. . . . . ~' .....' N ;~1A,1l, lJ/t.ttJ I 2-. ~. pPj 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . . N P' . f , APPR DATE ~7: BOPE press rating appropriate; test to 5000 psig. ,'~ /Vl ç 2. q 1 't f)Ç". I. /I~ A I I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . .' N ~/~ ~ '-4-.05 .29. Work will occur without operation shutdown. . . . . . . . . . . , " .ÞI""' 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y úY, (.u.. (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . .V-N- "'/A v.!L o(,/Oø1/ e. -t'" I q , GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . {} N" ,~_._,,_.... APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . Y N -"-. . ._.-.......~..,_..."., l ,""', ^ 34. Seismic analysis of shallow gas zones. . . , . . . . . . . . . Y N :-::::-::>-r~ l~ )~l hJJ~~> 35. Seabed condition survey (if.off-shore). .. . . . . . . . . . . . X."N· ,.' (Exploratory Only) 36. Contact namelphone for weekly progress reports. . . . . . '.' .,.,y N PROGRAM: Exp _ Dev _ Redrll _ Re-Enter _ Serv V-" Wellbore seg _ GEOL AREA ~ 9. ~ UNIT# 1 \ \ ~ ~ ON/OFF SHORE ~ t-l (' ( ~,-, Rev: 10/15/02 SFD_ ...,,;" WGA v' MJW UIC ENGINEER COMMISSIONER: JBR S.p ~ cF:;?~ DTS MLB Comments/Instructions: GEOLOGY: RPC~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH G:\geology\perm its\checklist.doc ) ) 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 APPEN.DIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri. )ng Services LIS Scan Utility ) $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 14:03:48 2003 ~3- 031 \ \ lo6~ Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number. . . . . .01 Previous Reel Name...... . UNKNOWN Comments......... ....... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3S-21 501032045200 Conoco Phillips Alaska, Inc. Sperry Sun 17-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0002323379 P. ROGER D. BURLEY MWD RUN 4 MW0002323379 P. SMITH D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2551 1207 MSL 0) .00 56.95 27.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3643.0 6.130 7.000 8509.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. ~) ) 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 100-200 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 300-400 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), STABILIZED LITHO-DENSITY (SLD) I AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 5. MWD DATA ARE CONSIDERED PDC PER GKPA GEOSCIENCE GROUP. 6. MWD RUNS 1-4 REPRESENT WELL 3S-21 API#:50-103-20452-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9857'MD / 6010'TVD. SROP SGRC SEXP SESP SEMP SEDP SFXE TNPS CTFA CTNA SBD2 SC02 SNP2 SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY COMBINED. SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR SLIDE = ORIENTED DRILLING INTERVALS AT BIT DEPTHS. COMPENSATED NEUTRON POROSITY PROCESSING PARAMETERS: HOLE SIZE: 8.5" MUD WEIGHT: 8.7-10.6 PPG MUD SALINITY: 500 PPM FORMATION WATER SALINITY: 25000 PPM FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE PEF ROP NCNT FCNT 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3625.0 3625.0 3625.0 3625.0 STOP DEPTH 9781.5 9857.0 9767.0 9767.0 -. ) ) NPHI 3625.(, 9767.0 GR 3630.0 8487.5 RPX 3633.5 9821.0 FET 3633.5 9821.0 RPS 3633.5 9821.0 RPM 3633.5 9821.0 RPD 3633.5 9821.0 DRHO 3648.5 9781.5 RHOB 3648.5 9781.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 3 4 MERGE TOP 3625.0 8490.0 MERGE BASE 8490.0 9857.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3625 9857 6741 12465 3625 9857 ROP MWD FT/H 2.16 799.88 153.333 12465 3625 9857 GR MWD API 47.14 174.79 115.2 9716 3630 8487.5 RPX MWD OHMM 1.27 2000 4.78618 12338 3633.5 9821 RPS MWD OHMM 0.07 1701.89 4.65862 12338 3633.5 9821 RPM MWD OHMM 1.04 2000 8.28002 12338 3633.5 9821 RPD MWD OHMM 0.02 2000 7.94402 12338 3633.5 9821 FET MWD HOUR 0.1619 85.9659 1.18635 12338 3633.5 9821 NPHI MWD PU 11.87 52.9 31.9892 12169 3625 9767 FCNT MWD CNTS 154 2503.5 823.126 12168 3625 9767 ) ) NCNT MWD CNTS 15776. 'I 199525 112501 12168 3625 9767 RHOB MWD G/CM 1.989 3.164 2.33203 12136 3648.5 9781.5 DRHO MWD G/CM -0.251 0.329 0.064796 12118 3648.5 9781.5 PEF MWD BARN 1.68 12.27 3.53749 12165 3625 9781.5 First Reading For Entire File......... .3625 Last Reading For Entire File.......... .9857 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NPHI PEF NCNT ROP GR FET RPS RPD RPM RPX RHOB DRHO $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 3625.0 3625.0 3625.0 3625.0 3625.0 3630.0 3633.5 3633.5 3633.5 3633.5 3633.5 3648.5 3648.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 8431.0 8431.5 8444.5 8431.0 8519.0 8487.5 8480.0 8480.0 8480.0 8480.0 8480.0 8444.5 8444.5 29-MAR-03 Insite 6.02 Memory MINIMUM ANGLE: MAXIMUM ANGLE: ') # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 55.2 60.3 TOOL NUMBER 155790 136749 151842 150918 8.500 3643.0 LSND 10.60 44.0 8.2 500 4.9 3.500 2.280 3.000 3.700 68.0 108.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3625 8519 6072 9789 3625 8519 ROP MWD030 FT/H 2.16 799.88 165.684 9784 3625 8519 GR MWD030 API 47.14 174.79 115.2 9716 3630 8487.5 RPX MWD030 OHMM 1.31 2000 4.26398 9694 3633.5 8480 RPS MWD030 OHMM 0.07 18.41 3.95327 9694 3633.5 8480 RPM MWD030 OHMM 1.53 2000 5.58665 9694 3633.5 8480 RPD MWD030 OHMM 0.02 2000 6.37288 9694 3633.5 8480 FET MWD030 HOUR 0.1619 59.2173 0.975056 9694 3633.5 8480 NPHI MWD030 PU 11.87 52.9 32.9588 9614 3625 8431.5 FCNT MWD030 CNTS 556.2 2503.5 959.661 9613 3625 8431 NCNT MWD030 CNTS 107660 199525 136549 9613 3625 8431 RHOB MWD030 G/CM 1.989 2.811 2.30184 9593 3648.5 8444.5 DRHO MWD030 G/CM -0.073 0.329 0.0695454 9593 3648.5 8444.5 PEF MWD030 BARN 1.68 12.05 2.94748 9640 3625 8444.5 First Reading For Entire File......... .3625 Last Reading For Entire File.......... .8519 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Next File Name...... .... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT GR RPX RPD RPM RPS FET RHOB PEF DRHO ROP 3 header data for each bit run in separate files. 4 .5000 START DEPTH 8490.0 8490.0 8490.0 8490.0 8499.5 8499.5 8499.5 8499.5 8499.5 8510.5 8519.5 8519.5 8519.5 STOP DEPTH 9767.0 9767.0 9767.0 9814.0 9821.0 9821.0 9821.0 9821.0 9821.0 9781.5 9781.5 9781.5 9857.0 $ ') # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction,............... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 03-APR-03 Insite 0.43 Memory 49.8 57.5 TOOL NUMBER 62456 112439 100983 73634 6.130 8509.0 LSND 11.00 47.0 10.0 350 1.0 2.000 1.354 2.200 1.600 78.0 118.4 78.0 78.0 Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) ) RPX MWD040 OHMM 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8490 9857 9173.5 2735 8490 9857 ROP MWD040 FT/H 6.95 227.13 108.36 2676 8519.5 9857 GR MWD040 API 50.39 511.3 146.507 2649 8490 9814 RPX MWD040 OHMM 1.27 1825.29 6.70078 2644 8499.5 9821 RPS MWD040 OHMM 1.19 1701.89 7.24471 2644 8499.5 9821 RPM MWD040 OHMM 1.04 2000 18.155 2644 8499.5 9821 RPD MWD040 OHMM 0.99 2000 13.7045 2644 8499.5 9821 FET MWD040 HOUR 0.2181 85.9659 1.96104 2644 8499.5 9821 NPHI MWD040 PU 13.01 44.4 28.3405 2555 8490 9767 FCNT MWD040 CNTS 154 872.8 309.423 2555 8490 9767 NCNT MWD040 CNTS 15776.7 37118 22020.1 2555 8490 9767 RHOB MWD040 G/CM 2.2 3.164 2.44591 2543 8510.5 9781.5 DRHO MWD040 G/CM -0.251 0.231 0.0467521 2525 8519.5 9781.5 PEF MWD040 BARN 3.3 12.27 5.79002 2525 8519.5 9781.5 First Reading For Entire File......... .8490 Last Reading For Entire File.......... .9857 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services ') ') Physical EOF Physical EOF End Of LIS File