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203-011
Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' 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" B 108' 9-5/8" L-80 2565' 7" L-80 6074' 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 8412' SIZE DEPTH SET (MD) 2556' FNL, 1227' FEL, Sec. 18, T12N, R8E, UM 2038' FSL, 1472' FEL, Sec. 13, T12N, R7E, UM 2002' FSL, 1685' FEL, Sec. 13, T12N, R7E, UM 27' 62.5# 40# 108' 27' WT. PER FT.GRADE CEMENTING RECORD 5993192 SETTING DEPTH TVD 5993157 TOP HOLE SIZE Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 85 bbls 15.8 ppg PermaFrost cement w/ LCM in lead 50 bbls Surf-4478' 193 bbls 15.8 ppg Class G cement Perforations: 8124-8154' MD and 5874-5894' TVD (cemented) 5291-5441' Perf Wash Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing OA Cement Surf-Shoe @ 3049' 4473-5466' PLUGGED AND ABANDONED Gas-Oil Ratio:Choke Size: 38 bbls Class G Cement 7760' MD PACKER SET (MD/TVD) 42" 12-1/4" 59 bbls Arctic Crete 29'543 sx AS IIIL, 275 sx LiteCrete 30' 3050'29' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# AMOUNT PULLED 470979 470766 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 1666' MD/ 1625' TVD N/A P.O. Box 100360, Anchorage, AK 99510-0360 476033 5993861 Surface/ Surface 8423' MD/ 6081' TVD ADL0380107, ADL0025544 ALK2639 50-103-20446-00-00 KRU 3S-22 February 12, 2003 February 21, 2003 9. Ref Elevations: KB: 28' Kuparuk River Field/ N/A Abandoned STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/25/2024 203-011/ 323-412 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/ GasBlok8-1/2" 7792'3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 10:13 am, Apr 08, 2024 Abandoned 3/25/2024 JSB RBDMS JSB 041524 xGDSR-4/23/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1666' 1625' Top of Productive Interval N/A 31. List of Attachments: Schematic, Summary of Operations, Photos 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. TPI (Top of Producing Interval). 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. Formation Name at TD: 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 - Plugged and Abandoned Authorized Name and 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 - Plugged and Abandoned Authorized Title: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2024.04.08 09:01:04 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,198.0 3S-22 2/19/2020 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&A to 7' below tundra, marker verified by AOGCC (Kam STjohn) 3S-22 3/25/2024 mouser Notes: General & Safety Annotation End Date Last Mod By NOTE: P&A to 7' below tundra,Marker verified by AOGCC (Kam STjohn) 3/25/2024 mouser NOTE: Injector 3S-22 waivered for water-only injection due to TxIA communication on gas. 8/16/2018 kautzr 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 37.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 37.0 3,049.9 2,565.4 40.00 L-80 BTC PRODUCTION 7 6.28 37.0 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 7,420.4 Set Depth … 7,792.4 Set Depth … 5,646.6 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-90 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) 7,659.7 5,558.1 48.70 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 7,705.6 5,588.4 48.25 NIPPLE 4.520 DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 7,743.9 5,614.1 48.00 SEAL ASSY 5.875 LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 3.010 7,745.9 5,615.4 47.99 PBR 4.000 BAKER 80-40 PBR w/XO BAKER 80-40 3.000 7,759.6 5,624.6 47.91 ANCHOR 4.730 KBH-22 ANCHOR TUBIGN SEAL NIPPLE KBH-22 3.000 7,760.5 5,625.2 47.90 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,765.4 5,628.5 47.87 MILL 4.500 80-40 MILL OUT EXTENSION 3.710 7,784.5 5,641.3 47.76 NIPPLE 4.540 CAMCO D NIPPLE w/ 2.75 NO GO CAMCO D 2.750 7,791.5 5,646.0 47.72 WLEG 5.000 WLEG w/ SHEAR OUT SUB 2.992 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) 36.5 36.5 0.22 MARKER PLATE NES Welder prepped the well stub for the marker plate. Kam St John witnessed the top of cement and the marker plate 3/25/2024 0.000 5,466.0 4,132.8 49.31 CIBP 5.61" CIBP MID-ELEMENT @ 5467' RKB, OAL = 1.6' LEGACY HPBP 00056 10- 002 9/6/2023 0.000 7,420.0 5,402.2 48.92 CUT 238 WELLTEC TUBING CUT AT 7420' RKB 5/27/2023 2.992 7,690.0 5,578.1 48.40 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER 5/7/2023 0.000 7,690.0 5,578.1 48.40 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER 5/7/2023 0.000 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN REPLACED WITH DUMMY VALVE 12/28/2003 2/28/2003 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,291.0 5,315.0 4,018.1 4,033.8 9/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASING 5,317.0 5,357.0 4,035.1 4,061.4 9/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASING 5,359.0 5,399.0 4,062.7 4,088.9 9/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASING 5,401.0 5,441.0 4,090.3 4,116.5 9/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASING 8,124.0 8,154.0 5,873.7 5,894.3 C-4, 3S-22 3/10/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60° phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,291.0 5,441.0 4,018.1 4,116.5 Cement Squeeze Perf Wash Cement 5291-5441' 7,791.5 8,254.0 5,646.0 5,963.1 Cement Plug 5/7/2023 7,690.0 7,791.5 5,578.1 5,646.0 Cement Plug 5/7/2023 7,760.5 8,254.0 5,625.2 5,963.1 Plug – Plug Back / Abandonment Plug 32.4 BBL, 15.8 PPG, CLASS G BELOW RETAINER 5/7/2023 7,440.0 7,760.5 5,415.4 5,625.2 Plug – Plug Back / Abandonment Plug 2.4 BBL, 15.8 PPG, CLASS G ABOVE RETAINER 5/7/2023 37.0 4,478.0 37.0 3,492.0 Plug – Plug Back / Abandonment Plug 193 BBLS, 15.8 PPG CLASS G CEMENT 2/28/2024 3S-22, 4/5/2024 2:03:28 PM Vertical schematic (actual) FISH; 8,420.0 PRODUCTION; 37.0-8,412.2 IPERF; 8,124.0-8,154.0 Cement Plug; 7,791.5 ftKB PACKER; 7,760.5 Plug – Plug Back / Abandonment Plug; 7,760.5 ftKB CEMENT RETAINER; 7,690.0 CEMENT RETAINER; 7,690.0 Cement Plug; 7,690.0 ftKB GAS LIFT; 7,659.7 Plug – Plug Back / Abandonment Plug; 7,440.0 ftKB CUT; 7,420.0 CIBP; 5,466.0 APERF; 5,401.0-5,441.0 APERF; 5,359.0-5,399.0 Cement Squeeze; 5,291.0 ftKB APERF; 5,317.0-5,357.0 APERF; 5,291.0-5,315.0 Plug – Plug Back / Abandonment Plug; 4,478.0 ftKB SURFACE; 37.0-3,049.9 Cement Casing; 37.0 ftKB CONDUCTOR; 37.0-108.0 Plug – Plug Back / Abandonment Plug; 37.0 ftKB Surface String Cement; 37.0 ftKB MARKER PLATE; 36.5 KUP INJ KB-Grd (ft) 34.10 RR Date 2/24/2003 Other Elev… 3S-22 ... TD Act Btm (ftKB) 8,412.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044600 Wellbore Status INJ Max Angle & MD Incl (°) 51.40 MD (ftKB) 2,837.14 WELLNAME WELLBORE3S-22 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 4,473.0 5,466.0 3,488.8 4,132.8 Plug – Plug Back / Abandonment Plug 38 BBLS, 15.8 PPG CLASS G CEMENT 2/10/2024 5,141.0 5,467.0 3,920.3 4,133.4 Cement Plug 15.8 PPG Class G (Milled out Cement) 1/30/2024 9/12/2023 37.0 3,049.9 37.0 2,565.4 Surface String Cement 9/12/2023 3S-22, 4/5/2024 2:03:29 PM Vertical schematic (actual) FISH; 8,420.0 PRODUCTION; 37.0-8,412.2 IPERF; 8,124.0-8,154.0 Cement Plug; 7,791.5 ftKB PACKER; 7,760.5 Plug – Plug Back / Abandonment Plug; 7,760.5 ftKB CEMENT RETAINER; 7,690.0 CEMENT RETAINER; 7,690.0 Cement Plug; 7,690.0 ftKB GAS LIFT; 7,659.7 Plug – Plug Back / Abandonment Plug; 7,440.0 ftKB CUT; 7,420.0 CIBP; 5,466.0 APERF; 5,401.0-5,441.0 APERF; 5,359.0-5,399.0 Cement Squeeze; 5,291.0 ftKB APERF; 5,317.0-5,357.0 APERF; 5,291.0-5,315.0 Plug – Plug Back / Abandonment Plug; 4,478.0 ftKB SURFACE; 37.0-3,049.9 Cement Casing; 37.0 ftKB CONDUCTOR; 37.0-108.0 Plug – Plug Back / Abandonment Plug; 37.0 ftKB Surface String Cement; 37.0 ftKB MARKER PLATE; 36.5 KUP INJ 3S-22 ... WELLNAME WELLBORE3S-22 DTTMSTART JOBTYP SUMMARYOPS 5/7/2023 CHANGE WELL TYPE SET CEMENT RETAINER AT 7690' RKB, +12' CORRECTION TO D-NIP AT 7705'. PUMPED 32.4 BBLS OF 15.8 PPG CEMENT LAID 2.4 BBLS ON TOP OF RETAINER DRESSED OFF CEMENT TOP AT 7460' FREEZE PROTECT WELL 23 BBLS OF DIESEL RDMO 5/11/2023 CHANGE WELL TYPE TAG TOC @ 7420' SLM. CONDUCT PASSING MIT-T TO 1500 PSI. READY FOR SW, IN PROGRESS. 5/12/2023 CHANGE WELL TYPE STATE WITINESS (CAM ST.JOHN) TAG TOC @ 7418' SLM. CONDUCT PASSING MIT-T TO 1500 PSI. CEMENT PROCEDURE COMPLETE, NEXT UP PRE-RIG TBG CUT. 5/27/2023 CHANGE WELL TYPE TAG TOP OF CEMENT AT 7440'. CUT TUBING WITH WELLTEC MECHANICAL CUTTER AT 7420'. TATTLETALE AT SURFACE INDICATES BLADES EXTENDED PAST 3.50" TBG OD. JOB COMPLETE 5/29/2023 CHANGE WELL TYPE CMIT TxIA TO 1500 PSI, RIGGED UP TO IA AND PUMPED 2.5 BBLS DIESEL TO 1500 PSI; 15 MIN TBG LOST 25 PSI, IA LOST 25 PSI; 30 MIN TBG LOST 0 PSI, IA LOST 0 PSI. ***PASSED*** JOB COMPLETE 5/31/2023 CHANGE WELL TYPE (P&A) T X IA DDT (COMPLETE) 7/15/2023 CHANGE WELL TYPE (P & A) BLEED OA FOR BUR (COMPLETE). 8/4/2023 CHANGE WELL TYPE MITT TO 3000 PSI - FAILED PUMPED 3 BBLS DSL DWN TBG BLED T/I/O TO STARTING PRESSURES SEE LOG FOR DETAILS 8/6/2023 RECOMPLETI ON Complete ops on 3S-19, move rig to 3S-22, rig up and safe out, berm around rigj, take on fluid start rigging up for displacement operations 8/7/2023 RECOMPLETI ON Complete flow check of well no flow, install BPV and test dart, Nipple down production tree, nipple up BOPs, Test BOPs 250/2500 AOGCC witness waived Brian Bixby, rig down test equipment, pull BPV, make up landing jt, pull hanger, circulate S x S , 9.6# observed at choke house, 325 bbls = 125% of hole volume pumped, OWFF no flow 8/8/2023 RECOMPLETI ON Complete flow check, lay down hanger and 3.5" completion tubing 9/2/2023 ACQUIRE DATA PERFORM JUNK BASKET RUN TAGGED AT 7416' RIH WITH USIT (IBC-CBL) AS PRE-PERF CEMENT EVALUATION LOG, PERFORM PASSES AT 5DEG 6", 5DEG 3" AND 5DEG 1.5" FROM 7416' TO 4300' JOB CONTINUE 9/3/2023 ACQUIRE DATA RIH WITH USIT (IBC-CBL) AS PRE-PERF CEMENT EVALUATION LOG, PERFORM PASSES AT 5DEG 6", 5DEG 3" AND 5DEG 1.5" FROM 7416' TO 4300', JOB COMPLETED 9/6/2023 ACQUIRE DATA SET AKA ELINE CIBP AT 5467' JOB CONTINUED 3S-22 Plug and Abandon Summary of Operations 9/7/2023 ACQUIRE DATA PERFORM PERFORATION RUNS WITH BELOW INTERVALS WITH 4.72" POWERFLOW HSD GUNS, 21 SPF, 60 DEG PHASING: 5421'-5441' 5401'-5421' 5379'-5399' 5359'-5379' 5337'-5357' 5317'-5337' 5295'-5315' 5291'-5295' POST PERFORATION JUNK BASKET/GAGE RING RUN STARTED ***JOB CONTINUED*** 9/8/2023 ACQUIRE DATA FINISH POST PERFORATION JUNK BASKET/GAGE RING RUN. RDMO 9/11/2023 CHANGE WELL TYPE STBY FOR WELLS SUPPORT TO MOVE RIG UP. MIRU CTU6, RIH W/ HYDRAWELL PERF WASH TOOL. POOH TO SWAP PUMPS, SLB MPF PUMP HAS BLOW BURST DISK. RU LRS, RIH WITH PERF WASH TOOL, TAG AT 5438' CORRECTED TO 5436' START PERF WASHING @ 3.3 BPM 4000 PSI @ 1 FPM **** JOB IN PROGRESS **** 9/12/2023 CHANGE WELL TYPE FINISHED W / PERF WASH AT SURFACE STBY FOR CHANGE OUT TO PUMP CEMENT AND LOAD FLUIDS. MAKE 1 PERF WASH PASS AT 5 FPM FROM 5,291' TO 5,441'. DROP 5/8" BALL TO OPEN CEMENTING NOZZLE. LAY IN CEMENT FROM 5,466' TO 5,141'. PUMP POWERVIS PILL AND CHASE RETURNS TO SURFACE. FREEZE PROTECT CASING. READY FOR TAG AND TEST IN 48 HRS. 9/16/2023 CHANGE WELL TYPE TAG TOC @ 5107' SLM, MIT TO 1500 PSI AFTER SEVERAL FAILED TEST HAND TESTING OFF TO LRS. COMPLETE. 9/16/2023 ACQUIRE DATA PRE WITNESS MIT T TO 1500 PSI FAILED, SEE LOG FOR DETAILS JOB COMPLETE 9/23/2023 ACQUIRE DATA OA INJECTIVETY TEST PUMPED 8 BBLS DSL DWN OA INJECTS 2 BPM @ 1200 PSI 9/26/2023 CHANGE WELL TYPE PUMPED OA CEMENT DOWN SQUEEZE f/ SURFACE TO SHOE w/ 85 BBLS OF 15.8 PPG PERMA FROST CEMENT w/ LCM IN LEAD 50 BBLS. PERFORMED 10 MIN SHUT DN HESITATION & PUMP THE LAST OF THE TAIL CEMENT. READY FOR THE NEXT STEP OF P&A. 9/29/2023 ACQUIRE DATA (P&A) OA DDT PASSED TO 0 PSI, OA TOC @ 21'3". 10/2/2023 CHANGE WELL TYPE (P&A) VAC FLUID FROM OA (COMPLETE) TOC = ~21' 8" 1/26/2024 CHANGE WELL TYPE (-33F) MIRU CTU 4 W/ 2" COIL, LOAD UPRIGHT'S WITH SEA WATER, & RIH W/ MOTOR & 6" BEAR CLAW MILL. 1/27/2024 CHANGE WELL TYPE RAN MOTOR & 6" BEAR CLAW MILL TAGGING STRINGS FROM 5111' TO TOP OF CEMENT @ 5125' CTMD. MILLED @ 1 FPM DOWN TO 5138' (PUH AND FREEZE PROTECT WHILE TANKS ARE GETTING FILLED). STANDBY DUE TO AMBIENT TEMPERATURE @ -39F. 1/28/2024 CHANGE WELL TYPE STANDBY DUE TO -39F. 1/29/2024 CHANGE WELL TYPE WEATHER DELAYED START DUE TO -39F TEMPERATURES. MILL FROM 5137' CTMD - 5441' CTMD (5457'MECH) CIBP @ 5,466' RKB W/ 6" BEAR CLAW MILL (.4-.6 FPM ROP W/ CIRC PSI @ 4000 PSI). PUMP 20 BBL GEL PILL & RBIH TO DRY TAG. 1/30/2024 CHANGE WELL TYPE DRY TAG W/ MILL IN HOLE POST GEL SWEEP @ 5442' CTMD; MAKE 2 FPM UNDERREAMING PASS DOWN FROM 5,100' -> 5,435' CTMD & 5 FPM UNDERREAMING UP PASS FROM 5,435' -> 5,100'. W/ 2.88 NOZZLE TAG @ 5445' CTMD. PUMP 20 BBL GEL PILL AND CHASE TO SURFACE AT 4 BPM. FREEZE PROTECT WELL TO 2,500' READY FOR E-LINE LOGGING (START WEEKLY BOP TEST) 1/31/2024 CHANGE WELL TYPE COMPLETE WEEKLY BOP TEST & RIG DOWN CTU 4. 2/1/2024 CHANGE WELL TYPE CHANGE OUT CREWS. PREP TOOLS AND EQUIPMENT FOR USIT JOB. BEGIN SPOTTING UNIT AND SUPPORT EQUIPMENT ON LOCATION. 2/2/2024 CHANGE WELL TYPE STANDBY WAITING FOR 3RD PARTY CRANE TO BE RELEASED FROM SLICKLINE ON 3S-615, LEAVE LOCATION FOR RIG JOB ON NORDIC 3, WILL RETURN AFTER RIG JOB JOB POSTPONED. 2/3/2024 CHANGE WELL TYPE PREPARE FOR IBC-CBL, DRIVE AND SPOT EQUIPMENT 2/4/2024 CHANGE WELL TYPE PERFORM JUNK BASKET/GAUGE RING RUN, TAG AT 5451', BEGIN LOGGING IBC/CBL PASSES JOB IN PROGRESS 2/5/2024 CHANGE WELL TYPE PERFORM CEMENT EVALUATION LOG FROM 5445' TO 5000' DATA UPLOADED FOR RUSH PROCESSING JOB COMPLETE 2/10/2024 CHANGE WELL TYPE LAY IN 38 BBL OF 15.8 PPG CLASS G CEMENT FROM TAG AT 5,438' CTMD TO 4,447' CTMD. PUMP 10 BBL POWERVIS PILL AND CHASE RETURNS TO SURFACE. FREEZE PROTECT WELL WHILE POOH. READY FOR WITNESSED TAG AND TEST IN 48 HRS. 2/11/2024 CHANGE WELL TYPE RIG DOWN CTU. 2/14/2024 CHANGE WELL TYPE STATE WITNESS TAG TOC @ 4445' SLM / EST 4478' RKB, GOOD CEMENT, PASSING MIT PRODUCTION CASING. READY FOR CTU 2/19/2024 ACQUIRE DATA (P&A) T x IA DDT (PASS), OA DDT (PASS) 2/27/2024 CHANGE WELL TYPE TAGGED TOC @ 4458' CTMD; (LET 3 BBLS GET AROUND CT BEFORE PUH) BEGIN LAYING IN 15.8 PPG CLASS G CEMENT PUMPING 1.2 BPM WHILE PUH @ 31' FPM W/ CT CURRENTLY @ 3600' CTMD. IN PROGRESS. 2/28/2024 CHANGE WELL TYPE LAY IN 193 BBLS OF 15.8 PPG CLASS G CEMENT FROM 4458' CTMD TO SURFACE @ 1:1 (21 BBLS EXCESS). CONFIRMED BY SAMPLES, GOOD CEMENT AT SURFACE. CLOSED MASTER VALVE, WASH UP BOP'S & TREE, CYCLED MV. READY FOR DHD IN 48 HRS. 3/2/2024 ACQUIRE DATA (P&A) VERIFY 0 PSI ON IA & OA, VERIFIED TOC THROUGH TREE CAP (FOUND ICE LENSE JUST BELOW UPPER SWAB VALVE) REMOVED IA CASING VALVES (CEMENT VISIBLE @ IA CASING SPOOL) *NEXT STEP: DEMO SCAFFOLDING & REMOVE DOUBLE SWAB VALVES* 3/3/2024 ACQUIRE DATA (P&A) (IN-PROGRESS) REMOVED TREE VALVES, CEMENT BRIDGE INSIDE SWAB VALVES, TOC @ 7'7", ~5' OF FLUID IN IA. * IA/OA = 0/0, 4 way gas readings H2S 0 PPM, C/O 0 PPM, O2 20.9 %, LEL 0 %* 3/19/2024 CHANGE WELL TYPE (P&A) DEGAS THE OA (COMPLETE) CEMENTED THE OA TO SURFACE (COMPLETE) CEMENTED THE T X I TO SURFACE (COMPLETE) 3/20/2024 CHANGE WELL TYPE (P&A) CUT & REMOVE THE WELLHEAD (COMPLETE) REMOVE THE CELLAR (IN PROGRESS) 3/21/2024 CHANGE WELL TYPE (P&A) EXCAVATION (IN PROGRESS ~5') REMOVE CELLAR (IN PROGRESS) 3/22/2024 CHANGE WELL TYPE (P&A) EXCAVATION (IN PROGRESS ~12') REMOVE CELLAR (COMPLETE) 3/23/2024 CHANGE WELL TYPE (P&A) EXCAVATED TO ~14' (COMPLETE), CUT AND REMOVE 10' OF WELL STUB (COMPLETE) PREP FOR MARKER PLATE (IN PROGRESS) 3/24/2024 CHANGE WELL TYPE (P&A) PREP THE WELL STUB FOR THE MARKER PLATE (COMPLETE) AOGCC WITNESS TOC (COMPLETE KAM STJOHN *7' BELOW TUNDRA*) WELD THE MARKER PLATE (COMPLETE) BACKFILL AND PULL SHORING CAN (IN PROGRESS) 3/25/2024 CHANGE WELL TYPE (P&A) REMOVE THE SHORING CAN AND BACKFILL EXCAVATION (COMPLETE) FINAL SITE CLEARANCE (KAM STJOHN COMPLETE) SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-22 Plug and Abandonment April 4, 2024 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-22, commencing operations on September 2, 2023 and completing the Plug and Abandonment on March 25, 2024. After successful suspension of the Kuparuk formation and rig operations to remove tubing, a bond log was run to determine top of cement in the 7” x OH annulus and to establish intervals for Perf/Wash/Cement operations. A CIBP was set at 5,467ft KB, the production casing was perforated from 5,291 to 5,441ft KB, then wash and cement operations 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. After state 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. 2024-0325_Surface_Abandon_KRU_3S-22_ksj Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 03/25/2024 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-22 ConocoPhillips Alaska, Inc. PTD 2030110; Sundry 323-412 03/24/2024: I witnessed the final surface abandonment of KRU 3S-22 with CPAI representative Brennen Green. Verified the information on the marker plate was correct – PTD #, API #, operator name, and well name. The casing cutoff was clean and flush and the cement was hard in all sections of the tubing and casing. The cutoff depth was at 7 feet below tundra level. Cement in 9 5/8-inch casing annulus was a little crumbly on top but hard - verified by hitting with a hammer. The marker plate was fit as per regulations and welded in place. No follow up needed. 03/25/2024: I returned to KRU 3S-22 for a location inspection with CPAI’s Brennen Green. All looked good with a good mound over the well excavation. Attachments: Photos (4) 2024-0325_Surface_Abandon_KRU_3S-22_ksj Page 2 of 3 Surface Abandonment – KRU 3S-22 (PTD 2030110) Photos by AOGCC Inspector J. StJohn 3/24/2024 2024-0325_Surface_Abandon_KRU_3S-22_ksj Page 3 of 3 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:8423 ft MD Lease No.:ADL 0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 3050 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8412 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 7792 Feet Tbg Cut@ 7420 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 5466 ft 4445 ft 9.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1750 1675 1640 IA 1750 1675 1640 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: When finished at KRU 3S-23A, they rigged up on KRU 3S-22. We discussed the plan forward and proceded. They picked up 10 ft of weight pipe, 13 ft of oil jars and spangs, and a 5 ft bailer with a 2-1/2" OD and a ball valve/ mule shoe - estimated weight of 200 lbs. Tagged up at 4445 ft RKB which is the corrected depth. Cement sample looked great. Nice hard sample. MIT was performed and went well. The test pressures on both MIT-Casing were identical, if I wasn't there to witness I may not have believed it. However we did pump and get back the same amount of fluid on both wells. February 15, 2024 Josh Hunt Well Bore Plug & Abandonment KRU 3S-22 ConocoPhillips Alaska Inc. PTD 2030110; Sundry 323-412 Photos (2) Test Data: P Casing Removal:Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0215_Plug_Verification_KRU_3S-22_jh Plug Verification – KRU 3S-22 (PTD 2030110) Photos by AOGCC Inspector J. Hunt 2/15/2024 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: 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: 2038' FNL, 1472' FEL S13 T12N R7E 9. Ref Elevations: KB: 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: 23. BOTTOM 16" B 108'59bbls ArcticCrete 9.625" L-80 2565' 7" L-80 6074' 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 Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SETTING DEPTH MD 2.4 bbl of 15.8ppg Class G above retainer If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 8124-8154' MD and 5874-5894' TVD (cemented) Gas-Oil Ratio:Choke Size: 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. N/A N/A 29' 30' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 27' 62.5# 40# 108' 27' 8412' SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 42" 5993861 Kaparuk River Field/Suspended ADL0380107/ ADL0025544 ALK2639 29' 30' 3050' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): WT. PER FT.GRADE 470979 470766 CEMENTING RECORD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 203-011/323-2338/8/2023 12-1/4" 543 sx AS IIIL, 275 sx LiteCrete CASING 50-103-20446-00-00 KRU 3S-22 2/12/2003 8423'MD/6081'TVD 7418'MD/5401'TVD 28' P.O.Box 100360, Anchorage, AK 99510-0360 476033 2556' FNL, 1227' FEL S18 T12N R8E 2002' FNL, 1685' FEL S13 T12N R7E 2/21/2003 1666'MD/1625'TVD SETTING DEPTH TVD 5993157 TOP HOLE SIZE AMOUNT PULLEDTOP 5993192 7418-7690' 7690-8254' 32.4 bbls of 15.8 Class G below retainer ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/GasBlok8-1/2" 7792'3.5" 7760'MD/5625'TVD BOTTOM Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 9:33 am, Aug 30, 2023 Suspended 8/8/2023 JSB RBDMS JSB 090623 xG DSR=10/25/23 Sidewall Cores:Yes NoConventional Core(s): 30. TVDMD Surface Surface 1666' 1666' N/A SuspendedN/A Suspended N/A SuspendedN/A Suspended 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Digital Signature with Date: Contact Phone:907-263-4597 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: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, andItem 31: 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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). Authorized Name and INSTRUCTIONS Contact Email: shane.germann@conocophillips.com 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. Formation Name at TD: g 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 NAME Permafrost - Top Permafrost - Base FORMATION TESTS29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) Top of Productive Interval: Submit in PDF format to aogcc.permitting@alaska.govForm 10-407 Revised 10/2022 31. List of Attachments: Well Schematic, Operations Summary 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. Authorized Title:Senior CTD/RWO Engineer vv Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location:Date: 2023.08.30 09:09:18-08'00' Foxit PDF Editor Version: 12.1.2 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,198.0 3S-22 2/19/2020 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 3S-22 5/27/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Injector 3S-22 waivered for water-only injection due to TxIA communication on gas. 8/16/2018 kautzr NOTE: View Schematic w/ Alaska Schematic9.0 12/27/2010 ninam 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 29.5 3,049.9 2,565.4 40.00 L-80 BTC PRODUCTION 7 6.28 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,420.4 Set Depth … 7,792.4 Set Depth … 5,646.6 String Ma… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-90 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) 7,659.7 5,558.1 48.70 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 7,705.6 5,588.4 48.25 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 7,743.9 5,614.1 48.00 SEAL ASSY 5.875 LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 3.010 7,745.9 5,615.4 47.99 PBR 4.000 BAKER 80-40 PBR w/XO BAKER 80-40 3.000 7,759.6 5,624.6 47.91 ANCHOR 4.730 KBH-22 ANCHOR TUBIGN SEAL NIPPLE KBH-22 3.000 7,760.5 5,625.2 47.90 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,765.4 5,628.5 47.87 MILL 4.500 80-40 MILL OUT EXTENSION 3.710 7,784.5 5,641.3 47.76 NIPPLE 4.540 CAMCO D NIPPLE w/ 2.75 NO GO CAMCO D 2.750 7,791.5 5,646.0 47.72 WLEG 5.000 WLEG w/ SHEAR OUT SUB 2.992 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) 7,420.0 5,402.2 48.92 CUT 238 WELLTEC TUBING CUT AT 7420' RKB 5/27/2023 2.992 7,690.0 5,578.1 48.40 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER 5/7/2023 0.000 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN REPLACED WITH DUMMY VALVE 12/28/2003 2/28/2003 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4, 3S-22 3/10/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg. phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,760.5 8,254.0 5,625.2 5,963.1 Plug – Plug Back / Abandonment Plug 32.4 BBL, 15.8 PPG, CLASS G BELOW RETAINER 5/7/2023 7,440.0 7,760.5 5,415.4 5,625.2 Plug – Plug Back / Abandonment Plug 2.4 BBL, 15.8 PPG, CLASS G ABOVE RETAINER 5/7/2023 3S-22, 8/29/2023 10:33:13 AM Vertical schematic (actual) FISH; 8,420.0 PRODUCTION; 26.6-8,412.2 IPERF; 8,124.0-8,154.0 PACKER; 7,760.5 Plug – Plug Back / Abandonment Plug; 7,760.5 ftKB CEMENT RETAINER; 7,690.0 GAS LIFT; 7,659.7 Plug – Plug Back / Abandonment Plug; 7,440.0 ftKB CUT; 7,420.0 SURFACE; 29.5-3,049.9 CONDUCTOR; 30.0-108.0 KUP INJ KB-Grd (ft) 34.10 RR Date 2/24/2003 Other Elev… 3S-22 ... TD Act Btm (ftKB) 8,412.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044600 Wellbore Status INJ Max Angle & MD Incl (°) 51.40 MD (ftKB) 2,837.14 WELLNAME WELLBORE3S-22 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Page 1/2 3S-22 Report Printed: 8/29/2023 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) 8/6/2023 18:00 8/6/2023 20:30 2.50 MIRU, MOVE MOB P Pull off 3S-19 , stage in front of 3S-22 // Set matting boards for pulling over 3S- 22 // Spot rig over 3S-22 0.0 0.0 8/6/2023 20:30 8/6/2023 22:00 1.50 MIRU, MOVE RURD P Spot herculite // spot pits to rig // set matting boards for pits 0.0 0.0 8/6/2023 22:00 8/6/2023 23:00 1.00 MIRU, MOVE RURD P Safe out rig // Put up berming // Work on rig accept checklist 0.0 0.0 8/6/2023 23:00 8/7/2023 00:00 1.00 MIRU, MOVE RURD P *** Rig Accepted 23:00 on 8/6/23 *** Take on fluid to pits // Rig up to swap well to seawater 0.0 0.0 8/7/2023 00:00 8/7/2023 01:30 1.50 MIRU, MOVE OTHR P Take on fluid for well kill operations // Check tiger tank line with air all good for circulation 0.0 0.0 8/7/2023 01:30 8/7/2023 02:30 1.00 MIRU, WELCTL DISP P Circulate 9.6# brine into well // .25 bbl/min @ 3600 psi // Consult with town decision made to shut down and monitor well for flow 0.0 0.0 8/7/2023 02:30 8/7/2023 04:00 1.50 MIRU, WELCTL OWFF T Open well to observe flow on IA and Tubing // Found well to be u-tubing likely due to 15 bbls 9.6 pumped into tubing // Line up well to U-Tube 30 min // no change in flow 0.0 0.0 8/7/2023 04:00 8/7/2023 04:30 0.50 MIRU, WELCTL DISP T Attempt to displace to 9.6 // .25 bbls/min 3600 psi 0.0 0.0 8/7/2023 04:30 8/7/2023 09:00 4.50 MIRU, WELCTL OWFF T Let well U-tube from tubing to IA and open the well for flow. 0.0 0.0 8/7/2023 09:00 8/7/2023 09:30 0.50 MIRU, WELCTL OWFF P Flow check the well. No flow. 0.0 0.0 8/7/2023 09:30 8/7/2023 10:30 1.00 MIRU, WELCTL MPSP P Set BPV. 0.0 0.0 8/7/2023 10:30 8/7/2023 11:30 1.00 MIRU, WELCTL NUND P ND the tree, inspect hanger threads, install dart valve. 0.0 0.0 8/7/2023 11:30 8/7/2023 12:00 0.50 MIRU, WELCTL SVRG P Service the rig 0.0 0.0 8/7/2023 12:00 8/7/2023 14:30 2.50 MIRU, WELCTL NUND P Nu BOPE, DSA to wellhead,install turnbuckles riser and obtain RKBS. 0.0 0.0 8/7/2023 14:30 8/7/2023 15:30 1.00 MIRU, WELCTL RURD P Perform shell test of BOP. 0.0 0.0 8/7/2023 15:30 8/7/2023 21:00 5.50 MIRU, WHDBOP BOPE P Test BOPE Test annular with 3 1/2" test joint to 250/2500 PSI F/5 min. All other test to 250/2500PSI F/5 min each, UVBR with 3 1/2" test joint, Test blinds rams, Choke valves #1 to #16, upper/lower IBOP valves. Test 3-1/2" HT-38 FOSV/Dart Valve, Test 2" rig floor Demco kill valves, Test manual and HCR kill and choke valves.Test two ea 2-1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3200 PSI, after closure = 1550 PSI, 200 PSI attained = 12 sec, full recovery attained = 114 sec. UVBR = 5 sec, Annular = 28 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 1950 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Brian Bixby witness waived. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/8/2023 Page 2/2 3S-22 Report Printed: 8/29/2023 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) 8/7/2023 21:00 8/7/2023 22:00 1.00 COMPZN, RPCOMP MPSP P Break down test jt // Pick up BPV pulling t-bar // Check for pressure under BPV, no pressure // Pull BPV 0.0 0.0 8/7/2023 22:00 8/7/2023 22:30 0.50 COMPZN, RPCOMP THGR P Pick up 3.5" EUE landing jt, make up to tubing hanger and TD, Set down 15K, BOLDS, Pull hanger off seat 95K pick up 10' prep well for displacement 7,420.0 7,410.0 8/7/2023 22:30 8/7/2023 23:30 1.00 COMPZN, RPCOMP DISP P Displace well with 9.6# brine // 325 bbls = 125% hole volume // Clean 9.6# observed at choke house 7,410.0 7,410.0 8/7/2023 23:30 8/8/2023 00:00 0.50 COMPZN, RPCOMP OWFF P OWFF // No Flow 7,410.0 7,410.0 8/8/2023 00:00 8/8/2023 01:00 1.00 COMPZN, RPCOMP PULL P Pull and lay down 3.5" completiion from well 7,410.0 6,500.0 8/8/2023 01:00 8/8/2023 01:30 0.50 COMPZN, RPCOMP SVRG P Service rig // Tighten solenoid on skate hydraulic bank 6,500.0 6,500.0 8/8/2023 01:30 8/8/2023 07:30 6.00 COMPZN, RPCOMP PULL P Pull and lay down 3.5" completion from well 6,500.0 0.0 8/8/2023 07:30 8/8/2023 08:30 1.00 COMPZN, RPCOMP OTHR P Blow down surface lines prep for NUND 0.0 0.0 8/8/2023 08:30 8/8/2023 11:00 2.50 COMPZN, WHDBOP NUND P Nipple down BOPs, nipple up dry hole tree. 0.0 0.0 8/8/2023 11:00 8/8/2023 12:00 1.00 COMPZN, WHDBOP PRTS P Fill tree with diesel and PT to 1500 psi for 30 minutes. Rig release at 12 noon. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/8/2023 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8423'8420' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-4131 Staff Well Intervention Engineer KRU 3S-22 6081' 7440' 5415' 1440 7440' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: jill.simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7760' MD and 5625' TVD 497' MD and 497' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107, ADL0025544 203-011 P.O. Box 100360, Anchorage, AK 99510 50-103-20446-00-00 Kuparuk River Field N/A - Suspended (Kuparuk River Oil Pool) ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Abandoned (Kuparuk River Oil Pool) TVD Burst 7792' MD 108' 2565' 108' 3050' 6074'8412' 16" 9-5/8" 78' 3020' 8124-8154' 8386' 5873-5894' 7" Perforation Depth TVD (ft): 8/1/2023 3-1/2" Packer: Baker SAB-3 Packer SSSV: Camco DS Nipple w/ NoGo Perforation Depth MD (ft): L-90 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:26 pm, Jul 19, 2023 323-412 Jill Simek Digitally signed by Jill Simek Date: 2023.07.19 14:40:40 -08'00' X VTL 7/24/2023 DSR-7/19/23 AOGCC inspection is required after cutoff and before any remedial cementing. MDG 7/24/2023 10-407 XX GCW 07/24/2023JLC 7/24/2023 07/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.07.25 09:33:53 -08'00' RBDMS JSB 072523 3S-22 Plug and Abandon Procedure PTD #203-011 Page 1 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 Production Engineer: Brian Lewis Surveillance Reservoir Engineer: Lynn Aleshire Estimated Start Date: August 1, 2023 Interventions Engineer: Jill Simek (265-4131/ jill.simek@conocophillips.com) Current Operations: This well is currently suspended with cement across Kuparuk. Rig operations are planned to cut and pull tubing from 7,420ft KB. Well Type: Injector Scope of Work: Perform Plug and Abandonment of 3S-22: Perf/Wash/Cement in production casing x OH annulus, cement well to surface, excavate and remove wellhead. MPSP: 1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Sl/El/Coil will be exposed to pressure once perf guns are fired. Procedure Eline 1. MIRU. 2. RIH with CBL and log 7.0” casing to confirm TOC of original cement job. POOH a. If TOC is BELOW Top of Moraine, then do additional production casing x open hole (OA) perf/wash/cement 50’ into Moraine and 100’ into confining zone above it to isolate for a total of ~150’ cement OA plug. 3. RIH and set 7” CIBP at base of perforation zone, approximately 5,467ft KB. POOH. 4. RIH with perf guns and perforate 7.0” casing as required to get exposure to top ~50’ of Coyote formation and ~100’ into the confining zone above it. (Note CIBP set depth and perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 5. RDMO Coil 6. MIRU. 7. RIH with wash/cement tool. Gently tag the CIBP. 8. PU and wash perfs per wash/cement tool’s vendor procedure. 9. After wash procedure, cement OA through perforations per wash/cement tool’s vendor procedure. POOH. Job is planned for ~67.8bbls cement, including excess. 10. Leave Top of Cement in production casing ~150ft above top perforation at ~5,141ft KB (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 11. RDMO. Wait on cement. Slickline 12. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 13. MIRU. 14. SL: RIH and tag top of cement (witnessed) 15. SL: Perform MIT on production casing (witnessed) 16. RDMO. 3S-22 Plug and Abandon Procedure PTD #203-011 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 197 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 3,049ft KB. Job is planned for 106 bbls of cement, including excess. 22. RDMO. Wellhead Excavation / Final P&A: 23. Confirm production casing and production casing x surface casing annulus pressures are at 0psi. 24. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 25. Remove the tree, in preparation for the excavation and casing cut. 26. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 27. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 28. Send the casing head w/ stub to materials shop. Photo document. 29. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 3S-22 PTD #: 203-011 API #: 50-103-20446-00 30. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 31. Obtain site clearance approval from AOGCC. RDMO. *If two plugs are deemed to be required due to Moraine formation exposure in the OA to the Coyote, then a lower plug will be performed first with the above steps to isolate top of Moraine. Then a 2nd plug will be performed as described at the top of the Coyote. Current Completion Proposed P&A 3S-22 P&A PTD #: 203-011 16” 62.5# H-40 Conductor @ 108' KB JS 7-18-2023 7" 26# L-80 Production Casing @ 8,412' KB 3-½” 9.3# L-80 Tubing @ 7,791' KB 9 5/8" 40# L-80 Surface Casing @ 3,049' KB Perfs: 8,124' – 8,154' KB Calculated Top of Cement (7" x Open Hole) = 7,070' KB Kuparuk HRZ/Kalubik Shales Moraine 7,089' – 7,350' KB Coyote 5,391' – 6,257' KB Packer depth = 7,760' KB Torok Basinal Shales Tubing cut at 7,420ft KB TOC (tubing) at 7,440ft KB Cement retainer set at 7690' KB Cement Plug (Production Casing x Open Hole Annulus) Approx. 5,291' – 5,441' KB CIBP @ ~5,467' KB Cement Plug (Production Casing x Surface Casing Annulus) 3,049' KB to Surface Cement Plug (Production Casing) Approx. 5,467' KB to Surface Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 3S-22 5/27/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Injector 3S-22 waivered for water-only injection due to TxIA communication on gas. 8/16/2018 kautzr NOTE: View Schematic w/ Alaska Schematic9.0 12/27/2010 ninam 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 29.5 3,049.9 2,565.4 40.00 L-80 BTC PRODUCTION 7 6.28 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.7 Set Depth … 7,792.4 Set Depth … 5,646.6 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-90 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) 24.7 24.7 0.15 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 497.3 497.3 0.15 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 7,659.8 5,558.1 48.70 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 7,705.6 5,588.5 48.25 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 7,743.9 5,614.1 48.00 SEAL ASSY 5.875 LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 3.010 7,745.9 5,615.4 47.99 PBR 4.000 BAKER 80-40 PBR w/XO BAKER 80-40 3.000 7,759.6 5,624.6 47.91 ANCHOR 4.730 KBH-22 ANCHOR TUBIGN SEAL NIPPLE KBH-22 3.000 7,760.5 5,625.2 47.90 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,765.5 5,628.5 47.87 MILL 4.500 80-40 MILL OUT EXTENSION 3.710 7,784.6 5,641.3 47.76 NIPPLE 4.540 CAMCO D NIPPLE w/ 2.75 NO GO CAMCO D 2.750 7,791.5 5,646.0 47.72 WLEG 5.000 WLEG w/ SHEAR OUT SUB 2.992 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) 7,420.0 5,402.2 48.92 CUT 238 WELLTEC TUBING CUT AT 7420' RKB 5/27/2023 2.992 7,690.0 5,578.1 48.40 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER 5/7/2023 0.000 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN REPLACED WITH DUMMY VALVE 12/28/2003 2/28/2003 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) 7,659.8 5,558.1 48.70 1 GAS LIFT DMY RK 1 1/2 0.0 8/8/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4, 3S-22 3/10/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg. phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,760.5 8,254.0 5,625.2 5,963.1 Plug – Plug Back / Abandonment Plug 32.4 BBL, 15.8 PPG, CLASS G BELOW RETAINER 5/7/2023 7,440.0 7,760.5 5,415.4 5,625.2 Plug – Plug Back / Abandonment Plug 2.4 BBL, 15.8 PPG, CLASS G ABOVE RETAINER 5/7/2023 IPERF; 8,124.0-8,154.0 PACKER; 7,760.5 Plug – Plug Back / Abandonment Plug; 7,760.5 ftKB CEMENT RETAINER; 7,690.0 GAS LIFT; 7,659.8 Plug – Plug Back / Abandonment Plug; 7,440.0 ftKB CUT; 7,420.0 SURFACE; 29.5-3,049.9 CONDUCTOR; 30.0-108.0 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" B 108' 9-5/8" L-80 2565' 7" L-80 6074' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/ GasBlok8-1/2" 7792'3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 5/12/2023 203-011/ 323-242 P.O. Box 100360, Anchorage, AK 99510-0360 476033 5993861 7418' MD/ 5401' TVD 8423' MD/ 6081' TVD ADL0380107, ADL0025544 ALK2639 50-103-20446-00-00 KRU 3S-22 February 12, 2003 February 21, 2003 9. Ref Elevations: KB: 28' Kuparuk River Field/ N/A Suspended AMOUNT PULLED 470979 470766 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 1666' MD/ 1625' TVD N/A 7760' MD PACKER SET (MD/TVD) 42" 12-1/4" 59 bbls Arctic Crete 29'543 sx AS IIIL, 275 sx LiteCrete 30' 3050'29' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 7418-7690' 2.4 bbl 15.8 ppg Class G above retainer Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 7690-8254' SUSPENDED Perforations: 8124-8154' MD and 5874-5894' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 32.4 bbl 15.8 ppg Class G below retainer 8412' SIZE DEPTH SET (MD) 2556' FNL, 1227' FEL, Sec. 18, T12N, R8E, UM 2038' FSL, 1472' FEL, Sec. 13, T12N, R7E, UM 2002' FSL, 1685' FEL, Sec. 13, T12N, R7E, UM 27' 62.5# 40# 108' 27' WT. PER FT.GRADE CEMENTING RECORD 5993192 SETTING DEPTH TVD 5993157 TOP HOLE SIZE Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 9:03 am, May 24, 2023 Suspended 5/12/2023 JSB RBDMS JSB 052523 xGDSR-6/1/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1666' 1625' 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 Jill Simek Digitally signed by Jill Simek Date: 2023.05.23 16:02:48 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,198.0 3S-22 2/19/2020 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SET CMT RETAINER, CMT SQZ 3S-22 5/7/2023 condijw Notes: General & Safety Annotation End Date Last Mod By NOTE: Injector 3S-22 waivered for water-only injection due to TxIA communication on gas. 8/16/2018 kautzr NOTE: View Schematic w/ Alaska Schematic9.0 12/27/2010 ninam General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / WKM / GEN 5 / 5M TREE CAP CONNECTION: TOP 5.75"" ACME W/3.5"" EUE8RD THREAT 2/23/2003 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 29.5 3,049.9 2,565.4 40.00 L-80 BTC PRODUCTION 7 6.28 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.7 Set Depth … 7,792.4 Set Depth … 5,646.6 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-90 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) 24.7 24.7 0.15 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 497.3 497.3 0.15 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 7,659.8 5,558.1 48.70 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 7,705.6 5,588.5 48.25 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 7,743.9 5,614.1 48.00 SEAL ASSY 5.875 LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 3.010 7,745.9 5,615.4 47.99 PBR 4.000 BAKER 80-40 PBR w/XO BAKER 80-40 3.000 7,759.6 5,624.6 47.91 ANCHOR 4.730 KBH-22 ANCHOR TUBIGN SEAL NIPPLE KBH-22 3.000 7,760.5 5,625.2 47.90 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,765.5 5,628.5 47.87 MILL 4.500 80-40 MILL OUT EXTENSION 3.710 7,784.6 5,641.3 47.76 NIPPLE 4.540 CAMCO D NIPPLE w/ 2.75 NO GO CAMCO D 2.750 7,791.5 5,646.0 47.72 WLEG 5.000 WLEG w/ SHEAR OUT SUB 2.992 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) 7,690.0 5,578.1 48.40 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER 5/7/2023 0.000 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN REPLACED WITH DUMMY VALVE 12/28/2003 2/28/2003 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) 7,659.8 5,558.1 48.70 1 GAS LIFT DMY RK 1 1/2 0.0 8/8/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4, 3S-22 3/10/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg. phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,760.5 8,254.0 5,625.2 5,963.1 Plug – Plug Back / Abandonment Plug 32.4 BBL, 15.8 PPG, CLASS G BELOW RETAINER 5/7/2023 7,418.0 7,760.5 5,400.9 5,625.2 Plug – Plug Back / Abandonment Plug 2.4 BBL, 15.8 PPG, CLASS G ABOVE RETAINER 5/7/2023 3S-22, 5/23/2023 11:06:18 AM Vertical schematic (actual) FISH; 8,420.0 PRODUCTION; 26.6-8,412.2 IPERF; 8,124.0-8,154.0 PACKER; 7,760.5 Plug – Plug Back / Abandonment Plug; 7,760.5 ftKB CEMENT RETAINER; 7,690.0 GAS LIFT; 7,659.8 Plug – Plug Back / Abandonment Plug; 7,418.0 ftKB SURFACE; 29.5-3,049.9 CONDUCTOR; 30.0-108.0 KUP INJ KB-Grd (ft) 34.10 RR Date 2/24/2003 Other Elev… 3S-22 ... TD Act Btm (ftKB) 8,412.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044600 Wellbore Status INJ Max Angle & MD Incl (°) 51.40 MD (ftKB) 2,837.14 WELLNAME WELLBORE3S-22 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 5/1/2023 CHANGE WELL TYPE DRIFT W/ 8' x 2.125'' STEM, 2.75'' DMY CA-2 PLUG (DMY CEMENT RETAINER ASSEMBLY) TO D-NIP @ 7785' RKB; LRS PERFORM STEP RATE INJECTIVITY TEST FROM .5 BPM TO 3 BPM (SEE BODY); LRS ESTABLISH OA LLR OF 2 BPM @ 1200 PSI. READY FOR COIL. 5/4/2023 ACQUIRE DATA (P&A) : FUNCTION TESTED T&IC-LDS/GN'S (ALL GOOD), POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED. 5/7/2023 CHANGE WELL TYPE SET CEMENT RETAINER AT 7690' RKB, +12' CORRECTION TO D-NIP AT 7705'. PUMPED 32.4 BBLS OF 15.8 PPG CEMENT LAID 2.4 BBLS ON TOP OF RETAINER DRESSED OFF CEMENT TOP AT 7460' FREEZE PROTECT WELL 23 BBLS OF DIESEL RDMO 5/11/2023 CHANGE WELL TYPE TAG TOC @ 7420' SLM. CONDUCT PASSING MIT-T TO 1500 PSI. READY FOR SW, IN PROGRESS. 5/12/2023 CHANGE WELL TYPE STATE WITINESS (CAM ST.JOHN) TAG TOC @ 7418' SLM. CONDUCT PASSING MIT-T TO 1500 PSI. CEMENT PROCEDURE COMPLETE, NEXT UP PRE-RIG TBG CUT. 3S-22 Suspend Summary of Operations 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:8423 ft MD Lease No.:ADL 0380107 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 3050 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8412 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 7792 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 7640 ft 7418 ft 7.2 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1775 1710 1695 IA 0 0 0 OA 300 300 300 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Had a good solid tag with good cement sample from the bailer. Top of cement was supposed to be about 7460 ft MD and they tagged at 7418 ft MD. MIT-T Passed (0.36 bbls in, 0.4 bbls back). May 12, 2023 Kam StJohn Well Bore Plug & Abandonment KRU 3S-22 ConocoPhillips Alaska Inc PTD 2030110; Sundry 323-242 none Test Data: P Casing Removal: rev. 11-28-18 2023-0512_Plug_Verification_KRU_3S-22_ksj 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8412'8420' Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8124-8154' 8385' 5874-5894' 3-1/2" 7" 16" 9-5/8" 78' 3020' Perforation Depth MD (ft): MD 110' 2565' 110' 3050' 6074'8412' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6074' 8198' 5924' 1440 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544 203-011 P.O. Box 100360, Anchorage, AK 99510 50-103-20446-00-00 ConocoPhillips Alaska, Inc. KRU 3S-22 N/AKapruk River Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: 7761'MD/5625'TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-90 7792' 6/1/2023 Packer: Baker SAB-3 SSSV: None 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 and Digital Signature with Date: AOGCC USE ONLY Jill Simek jill.simek@conocophillips.com (907) 263-4131 Well Interventions Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-242 By Kayla Junke at 9:00 am, Apr 21, 2023 Digitally signed by Will Earhart DN: OU=Engineering Supv, O=Well Integrity and Intervention, CN=Will Earhart, E=william.c.earhart@ conocophillips.com Reason: I have reviewed this document Location:Date: 2023.04.20 13:58:07-08'00' Foxit PDF Editor Version: 12.0.1 Will Earhart DSR-4/26/23 6081'SFD 10-407 X VTL 5/2/2023 SFD 5/2/2023 SFD X 8423' SFD Suspension approved through 12/31/2023. P&A, including surface abandonment must be completed by 12/31/2023 KuparukADL0380107, JLC 5/2/2023 GCW 05/03/23 05/03/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.03 09:20:06 -08'00' RBDMS JSB 050423 JS Date: April 19, 2023 Subject: 3S-22 Suspend Procedure Network Number: 10450521 Prepared By: Jill Simek Telephone: 907 980-7503 Approved By: Will Earhart Telephone: 540 448-1789 Procedure Justification: Injector 3S-22 (PTD: 203-011) was drilled and completed in the Kuparuk C4 in 2003. The well is currently shut-in as the producers in its pattern are all shut-in for low production and/or water handling constraints. Subsequently, 3S-22 has been identified as a P&A candidate, to allow for slot recovery and slot optimization for Coyote Development. 3S-22 will require rig-assisted P&A operations which are currently being developed. Due to 2023 rig schedule constraints and upcoming planned 3S Pad Sim-Ops, ConocoPhillips plans to perform rigless suspension operations on 3S-22 immediately, with P&A operations to follow later in the year. Suspension operations will reduce the work scope and timeline for future P&A operations, thus limiting Sim-Ops during the high pad activity planned later this year. The well is completed with 3 ½” tubing run to 7,791ft KB and a Baker SAB-3 packer set at 7,760ft KB. Surface casing is 9-5/8”, and production casing is 7”. Perforations are from 8,124ft to 8,154ft KB. Per this procedure, suspend operations will be performed by pumping 30 bbls of 15.8 ppg Class “G” cement through a cement retainer at approximately 7,690ft KB to treat both the Moraine and Kup C, then placing 2 bbls on top of the retainer. A tag and pressure test will confirm integrity post-job. Well Status/History: x The well is currently shut-in. x Last MIT: MIT-IA passed to 3,610psi on 8/13/22; MIT-OA failed 7/8/2006 (LLR = 1.75bpm at 1,550psi due to open shoe) x SBHP = 4,049psi @ 6,200ft SS. (5/4/2018) x Min ID = 2.75” @ 7,784ft KB (Camco D Nipple w/ 2.75” No-Go) x Last Drift/Tag: Drift clean to 7,784ft KB (5/3/2018) JS Procedure: Slickline/Little Red Services: Objective: Drift for cement retainer, perform injectivity test to confirm adequate rates for cementing operations 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH with dummy cement retainer tool string to Camco D-nipple (2.812” no-go) at 7,705 KB. 4. Rig up LRS. With ~20 bbls diesel pumping down tubing, perform step rate injectivity test from 0.5 – 3 bpm, in ½ bpm increments, up to a maximum pressure of 3,000 psi, to ensure adequate rates for cementing operations. Record Results. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. Establish/confirm OA LLR for cement downsqueeze (previous LLR = 1.75bpm at 1550psi, performed 7/8/2006) 6. RDMO. Coiled Tubing / Cementing: Objective: Place a cement plug across the perforations and squeeze some cement into perforations. Cement Volume Calculations (TOC approximately 7,460ft KB in tubing): x 7” production csg, 100ft below perfs to tubing tail: (0.03826 bbl/ft) * (8,254ft – 7,791ft) = 17.7 bbls x 3 ½” tubing, tubing tail to TOC: (0.008696 bbl/ft) * (7,791ft – 7,460ft) = 2.9 bbls x Squeeze volume = 10.4 bbls x Total volume = 17.7 + 2.9 + 10.4 = 30 bbls 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Cementers a week before the scheduled Suspend date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for 30 bbls of 15.8# Class “G” cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 2/20/2020 schematic and tubing details for depth correlation. Use Camco D-nipple (2.812” no-go) at 7,705ft KB for correlation. 6. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. JS 7. Set cement retainer at approximately 7,690ft KB (middle of full joint, above D- nipple), or as deep as the retainer will safely drift. 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 20 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. Pump 10 bbls freshwater spacer 11. Pump 28 bbls (30 bbl job volume) of 15.8 ppg Class “G” Cement through the cement retainer. If squeeze pressure is seen before pumping total cement volume, stop pumping and begin next step. 12. Shut down, un-sting from retainer 13. Lay in remaining 2.0 bbls cement above retainer (equates to ~ 230’ of cement above the retainer, leaving TOC ~7,460ft KB) 14. POOH above TOC. Circulate CTU clean. 15. Wash up surface equipment. RDMO. Slickline / Little Red Objective: State witnessed tag of TOC, MIT-T, CMIT-TxIA, DDT-T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 7,460ft KB. Record Results. TAG MUST BE AOGCC WITNESSED Note: Job will be deemed successful for as long as cement is tagged above retainer. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. PRESSURE TEST MUST BE AOGCC WITNESSED 7. Perform CMIT-TxIA to 1,500 psi. Record results. 8. Perform DDT-T. Record results. 9. Report issues and results to Well Interventions Engineer. 10. RDMO JS Schematic: JS Suspend Diagram: Current Completion Proposed Suspend 3S-22 Suspend PTD #: 203-011 16” 62.5# H-40 Conductor @ 108' KB WCE 4-19-2023 7" 26# L-80 Production Casing @ 8,412' KB 3-½” 9.3# L-80 Tubing @ 7,791' KB Cement Plug (Perforations, Casing, & Tubing) 8,254' – 7,460' KB 15.8 ppg Class “G” 9 5/8" 40# L-80 Surface Casing @ 3,049' KB Perfs: 8,124' –8,154' KB Cement Retainer at ~7,690' KB Calculated Top of Cement (7" x Open Hole) = 7,070' KB Kuparuk HRZ/Kalubik Shales Moraine 7,089' – 7,350' KB Coyote 5,391' – 6,257' KB Packer depth = 7,760' KB Torok Basinal Shales 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8412'8420' Casing Collapse Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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 and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 RWO/CTD Engineer Tubing Grade: Tubing MD (ft): Packer: 7761'MD/5625'TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-90 7792' 6/1/2023 Packer: Baker SAB-3 SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544 203-011 P.O. Box 100360, Anchorage, AK 99510 50-103-20446-00-00 ConocoPhillips Alaska, Inc. KRU 3S-22 N/AN/AKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6074' 8198' 5924' 1440 None MD 110' 2565' 110' 3050' 6074'8412' 16" 9-5/8" 78' 3020' Perforation Depth MD (ft): 8124-8154' 8385' 5874-5894' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-233 By Kayla Junke at 3:54 pm, Apr 18, 2023 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.18 15:13:08-08'00' Foxit PDF Editor Version: 12.0.1 BOP test to 2500 psig Annular preventer test to 2500 psig DSR-4/18/23 8423'SFD SFD X SFD 5/2/2023 10-407 ADL0380107, X 6081' VTL 5/23/2023GCW 05/24/23 JLC 5/24/2023 05/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.24 12:33:53 -05'00' RBDMS JSB 052423 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 18, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 3S-22 (PTD# 203-011). Well 3S-22 was drilled and completed as a Kuparuk Injector in February 2003. The well has been slated to be P&A'd for development of the Coyote formation. If you have any questions or require any further information, please contact me at +1406-670-1939. After a traditional Kuparuk P&A (that will have a different sundry), the tubing will be cut above tubing cement retainer/top of cement. Then a rig will come and pull the 3.5" tubing and stack two 7-1/16" valves on the wellhead. This will give eline and coiled tubing access to the 7" casing. The OA cement and final P&A details of the well will be submitted in a separate sundry. This sundry is just for the rig portion of the work that requires pulling the 3.5" tubing. Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.18 15:12:28-08'00' Foxit PDF Editor Version: 12.0.1 3S-22 RWO Procedure Kuparuk Injector Suspend PTD # 203-011 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Cut the tubing above tagged top of cement. 3. Prepare well for rig 48-72 hours before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3S-22. (No BPV will be install pre-rig due to internal risk assessment for N7ES for MIRU/RDMO without a BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut. a. On POOH with tubing, circulate well over to diesel freeze protect as necessary. 6. Perform 30 minute NFT. ND BOP, NU Tree 7. ND BOPE. NU two 7-1/16” tree valves and any adapter spool. 8. RDMO. Post-Rig Work - Post-rig scope will be submitted as a separate sundry for OA cement job and final P&A. 3S-22 RWO Procedure Kuparuk Injector Suspend PTD # 203-011 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 6/4/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in the lower Kuparuk is P&A’d. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Stack two 7-1/16” valves for Eline and coil unit OA cement operations post-rig. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A, none recent. (Well will be P&A’d and tubing will be cut for RWO.) MIT-IA Passed to 3600 psig on 8/13/2022. MIT-OA None recent IC POT & PPPOT N/A, to be tested in pre-rig. TBG POT & PPPOT N/A, to be tested in pre-rig. MPSP: 1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Rig work should be done over P&A’d well and not exposed to formation pressure during Rig portion of work. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,198.0 2/19/2020 3S-22 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replace DV 7/8/2018 3S-22 cjkenne Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.5 Set Depth (ftKB) 3,049.9 Set Depth (TVD) … 2,565.4 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.6 Set Depth (ftKB) 8,412.2 Set Depth (TVD) … 6,073.7 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.7 Set Depth (ft… 7,792.4 Set Depth (TVD) (… 5,646.6 Wt (lb/ft) 9.30 Grade L-90 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.7 24.7 0.15 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.3 0.15 NIPPLE CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 7,705.6 5,588.5 48.25 NIPPLE CAMCO DS NIPPLE w/ 2.812" NO GO 2.812 7,743.9 5,614.1 48.00 SEAL ASSY LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 3.010 7,745.9 5,615.4 47.99 PBR BAKER 80-40 PBR w/XO 3.000 7,759.6 5,624.6 47.91 ANCHOR KBH-22 ANCHOR TUBIGN SEAL NIPPLE 3.000 7,760.5 5,625.2 47.90 PACKER BAKER SAB-3 PACKER 3.250 7,765.5 5,628.5 47.87 MILL 80-40 MILL OUT EXTENSION 3.710 7,784.6 5,641.3 47.76 NIPPLE CAMCO D NIPPLE w/ 2.75 NO GO 2.992 7,791.5 5,646.0 47.72 WLEG WLEG w/ SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN REPLACED WITH DUMMY VALVE 12/28/2003 2/28/2003 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4, 3S-22 3/10/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg. phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,659.8 5,558.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/8/2018 Notes: General & Safety End Date Annotation 8/16/2018 NOTE: Injector 3S-22 waivered for water-only injection due to TxIA communication on gas. 12/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3S-22, 2/20/2020 9:27:26 AM Vertical schematic (actual) FISH; 8,420.0 PRODUCTION; 26.6-8,412.2 IPERF; 8,124.0-8,154.0 WLEG; 7,791.5 NIPPLE; 7,784.6 MILL; 7,765.4 PACKER; 7,760.5 ANCHOR; 7,759.6 SEAL ASSY; 7,743.9 NIPPLE; 7,705.6 GAS LIFT; 7,659.8 SURFACE; 29.5-3,049.9 NIPPLE; 497.3 CONDUCTOR; 30.0-108.0 HANGER; 24.7 KUP INJ KB-Grd (ft) 34.10 Rig Release Date 2/24/2003 3S-22 ... TD Act Btm (ftKB) 8,412.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044600 Wellbore Status INJ Max Angle & MD Incl (°) 51.40 MD (ftKB) 2,837.14 WELLNAME WELLBORE3S-22 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 3S-22 Proposed Suspended Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.06 62.5 H40 Welded Welded Surface 3050 2565 9.625 8.835 40 L80 BTC BTC Production/ Intermediate 8412 6073 7 6.28 26 L80 BTCM BTCM PROPOSED COMPLETION 3.5" Completion REMOVED Install two 7-1/16" Gate Valves (Freeze Protect when pulling 3.5" out of hole.) REMAINING COMPLETION LEFT IN HOLE P&A'd lower Kuparuk (Already done.) 3.5" Tubing Stub Top Approximately ~7670' RKB Surface Casing 7" Production Casing Conductor C and A-sand perfs ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3S-22 KUPARUK RIV UNIT 3S-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3S-22 50-103-20446-00-00 203-011-0 W SPT 5626 2030110 3000 2750 2750 2750 2750 180 310 280 250 REQVAR P Kam StJohn 8/13/2022 MIT I/A to maximum anticipated injection pressure per AIO 2C.062 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3S-22 Inspection Date: Tubing OA Packer Depth 1250 3610 3520 3510IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220813195912 BBL Pumped:2.2 BBL Returned:1.9 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 AIO 2C.062 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:52:34 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor I ej� FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 2, 2020 SUBJECT: Mechanical Integrity Tests ConoccPhillips Alaska, Inc. 3S-22 KUPARUK RIV UNIT 3S-22 Src: Inspector Reviewed By: p` P.I. SuprvI = Comm Well Name KUPARUK RIV UNIT 3S-22 API Well Number 50-103-20446-00-00 Permit Number: 203-011-0 Insp Num: mitRCN201121170254 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 11/21/2020 , Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3S-22 Type Inj ITVD 5626 Tubing 1775 1775 1775. 1775 ' - -W PTD 2030110 -'Type Test SPT Test pSi2750 IA 960 3310 3250 3250 BBL Pumped: 2.3 BBL Returned: 2 QA 180 300 260 - 240 ' Intervale REQVARP7-1/F P Notes' MIT -IA to maximum anticipated injection pressure of 2750 psi. per AIO 2C.062 Wednesday, December 2, 2020 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday,June 1, 2018 11:06 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, Kuparuk injection 3S-22 (PTD 203-011) is nearing the end of a 30-day monitor on water injection commenced after the IA was circulated out with clean fluids. CPAI intends to extend the water monitor period an additional 30-days to confirm if recently noted slow IA pressure increase is due merely to thermal response. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: NSK Well Integrity Supv CPF3 and WNS JUN 0 6 /018 Sent:Saturday,April 14, 2018 7:16 AM To: 'Wallace,Chris D(DOA)'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, Kuparuk injector 3S-22 (PTD 203-011) is about a week into its 30-day monitor on water injection and operations is having a difficult time keeping the IA pressure bled down. It seems that they have been primarily bleeding gas,which suggests the IA fluid is entrained with a fair amount of gas. Operations plans to shut in and freeze protect the well as soon as reasonably possible. CPAI intends to circulate the IA with clean fluids and restart the 30-day water monitor to confirm if the IA pressurization is primarily a result of gas entrained fluids in the IA. Please let us know if you have any, questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From. Well Integrity Supv CPF3 and WNS Sent:Tuesday, • • it 3,2018 5:14 PM To: 'Wallace,Chris D I: ' '<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.T ler.Sen• -• • conoco•hilli.s.com> Subject: RE: KRU 3S-22 (PTD 203-011) IA - urization Report Chris, • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday, April 14, 2018 7:16 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, Kuparuk injector 3S-22 (PTD 203-011) is about a week into its 30-day monitor on water injection and operations is having a difficult time keeping the IA pressure bled down. It seems that they have been primarily bleeding gas,which suggests the IA fluid is entrained with a fair amount of gas. Operations plans to shut in and freeze protect the well as soon as reasonably possible. CPAI intends to circulate the IA with clean fluids and restart the 30-day water monitor to confirm if the IA pressurization is primarily a result of gas entrained fluids in the IA. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450SCAN pp�� From: NSK Well Integrity Supv CPF3 and WNS Sent:Tuesday,April 3,2018 5:14 PM To: 'Wallace,Chris D(DOA)'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, WAG injector KRU 3S-22 (PTD 203-011) passed basic diagnostics including packoff testing and an MITIA to 3000 psi. However,when put back on gas injection,the IA again demonstrated pressurization. The well was shut-in and freeze-protected. Our intent is to WAG the well to water injection and observe the IA pressure trend on water injection. Additionally,we will circulate the IA to clean fluid. Following this circ out,our intent is to attempt another monitoring period on gas injection. Please let us know if you have any questions or disagree with this plan. Travis Fr.,-•• SK Well Integrity Supv CPF3 and WNS Sent:Tuesday, . - $ 018 8:39 AM To: 'Wallace,Chris D (DOA)'<chris. • . - • alaska.:ov> Cc:Senden, R.Tyler<R.T Ier.Senden • conoco• • om> Subject: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,April 3, 2018 5:14 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, WAG injector KRU 3S-22 (PTD 203-011) passed basic diagnostics including packoff testing and an MITIA to 3000 psi. However,when put back on gas injection,the IA again demonstrated pressurization. The well was shut-in and freeze-protected. Our intent is to WAG the well to water injection and observe the IA pressure trend on water injection. Additionally,we will circulate the IA to clean fluid. Following this circ out,our intent is to attempt another monitoring period on gas injection. Please let us know if you have any questions or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Tuesday, March 20, 2018 8:39 AM SCANS To: 'Wallace,Chris D (DOA)'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 3S-22 (PTD 203-011) IA Pressurization Report Chris, WAG injector KRU 35-22 (PTD 203-011) has exhibited suspect IA pressurization while on gas injection. Operations reported this morning that the IA pressure had increased from—600 psi to^'1750 psi and noted that it didn't seem tied to a rate or temperature change in the well. The IA was subsequently bled down and CPAI intends to monitor the well closely,as well as have DHD investigate with initial diagnostics(including a MITIA). A plan forward will be sent based on the diagnostic results. Attached is a 90-day TIO plot and a well schematic. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-04501 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, March 20, 2018 8:39 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3S-22 (PTD 203-0111 IA Pressurization Report Attachments: 3S-22 Well Schematic.pdf; KRU 3S-22 TIO Plot 90-day 3-20-18 jpg Chris, WAG injector KRU 3S-22 (PTD 203-011) has exhibited suspect IA pressurization while on gas injection. Operations reported this morning that the IA pressure had increased from "600 psi to^'1750 psi and noted that it didn't seem tied to a rate or temperature change in the well. The IA was subsequently bled down and CPAI intends to monitor the well closely, as well as have DHD investigate with initial diagnostics(including a MITIA). A plan forward will be sent based on the diagnostic results. Attached is a 90-day TIO plot and a well schematic. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-04501 SCANNED 1 ti OF 7.4 • • eg.* I//jy THE STATE Alaska Oil and Gas �w '!�►�—'—�A Of TACommission Conservation Commissionri F' �Jl 1 - _- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "4\ Main: 907.279.1433 ALASltP Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineertota 1: i 3. Jii°' ConocoPhillips Alaska, Inc. SEN PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-22 Permit to Drill Number: 203-011 Sundry Number: 318-037 Dear Mr. Burke: 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 . Foerster Commissioner DATED this/4 day of February, 2018. r•, w • • RECEIVED STATE OF ALASKA JAN 3 0 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate IU Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: DAD ACID STIMULATE U 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 203-011 t 3.Address: Stratigraphic ❑ Service El, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20446-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Y KRU 3S-22 Will planned perforations require a spacing exception? Yes ❑ No U 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25544 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,423' 6,081' 8244• 5956 • 2533psi NONE 8420 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 108' 108' Surface 3,020' 12" 3,050' 3,050' Production 8,386' 10" 8,412' 6,074' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8124-8154 ' 5874-5894 3.500" L-90 7,792' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER SAB-3 PACKER SSSV NONE • MD=7761 TVD=5625 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 12/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer /�/, Contact Email: Jason.Burke@cop.com J/30' Contact Phone: (907)265-6097 res_ gate —430 Signatu , '�//`_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 - 034 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS L L . FEB ; LC18 Post Initial Injection MIT Req'd? Yes ❑ No Li' Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /d — 4 0 zi-- n APPROVED BY Approved by: fes _ COMMISSIONER THE COMMISSION Date:244-4 fll !hikte , � f /�JJPINAL "// Submit Form and Form 10-403 Revised 4/2017 Approved applica ion is valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 3S-22 Acid Treatment (10402910) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Objectives: Cleanout well post MARCIT and spot DAD treatment • Coiled Tubing: Perform FCO and spot 100 bbl of DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH down to 8100' MD. 3. Bring pump up to clean out rate and begin washing out sand. a. Top of sand was 8132' MD 4. Wash down to 8160' MD and pump a gel sweep and a full bottom up volume while sweeping back to tubing tail at 7790' MD. 5. When returns are clean,RIH to 8160' MD. 6. When CT has reached depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH to 7790'. Continue injecting DAD into formation following with produced water or diesel a. Do not exceed 2600 psi surface pressure 7. After an additional 5 bbl of fluid has been injected behind the treatment POOH, RDMO Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal November 1, 2017 3S-22 Well Work Procedure Page 1 of 1 KUP 3S-22 Conoco Phillips Well Attrib Max Ang e Q MD TD 1"" Wellbore APVUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) Al, k<;T.)I/Q.:. 501032044600 KUPARUK RIVER UNIT INJ 51.40 2,837.14 8,412.0 ConocaYh 9196. Comment H2S(ppm) Date Annotation End Date I KB-Grd(ft) -Rig Release Date ••• SSSV:NIPPLE Last WO. 34.10 2/24/2003 3S-22,1/30120181:04:46 PM Last Tag Verocal schemaop(actual} Annotation Depth(ftKB) End Date Last Mod By Last Tag:SLM 8,123.0 1/1/2017 pproven Last Rev Reason Annotation End Date Last Mod By Rev Reason TAG 1/3/2016 pproven a Casing Strings HANGER.24.2 -t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread •' CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED IA. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 29.5 3,049.9 2,565.4 40.00 L-80 BTC -. Y -. Casing Description OD(in) ID(in) Top(580) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Ir Tubing Strings E . Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ibfft) Grade Top Connection TUBING 31/2 2.992 24.7 7,792.4 5.646.6 9.30 L-90 EUE8RDMOD Completion Details Top(TVD) Top Ind J_r�./ ,, Top(ftKB) (ftKB) El Item Des Nominal Com ID(in) 24.7 24.7 0.15 HANGER FMC GEN V TUBING HANGER 3.500 CONDUCTOR 30.0-108.0-• • 497.3 497.3 0.15 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 7,705.6 5,588.5 48.25 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 NIPPLE;497.3 Yom.- 7,743.9 5,614.1 48.00 SEAL ASSY LOCATOR SUB 8 PBR 12'SEAL ASSEMBLY(SPACED OUT) 3.010 AS 7,745.9 5,615.4 47.99 PBR BAKER 80-40 PBR w/XO 3.000 . 7,759.6 5,624.6 47.91 ANCHOR KBH-22 ANCHOR TUBIGN SEAL NIPPLE 3.000 7,760.5 5,625.2 47.90 PACKER BAKER SAB-3 PACKER 3.250 / 7,765.5 5,628.5 47.87 MILL 80-40 MILL OUT EXTENSION 3.710 7,784.6 5,641.3 47.76 NIPPLE CAMCO D NIPPLE w/2.75 NO GO 2.992 7,791.5 5,646.0 47.72 WLEG WLEG w/SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ,' Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) SURFACE;29.53049.9-' ¢ 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN 2/28/2003 is REPLACED WITH DUMMY VALVE 12/28/2003 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/t Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com • GAS LIFT;7,659.8 I• 8,124.0 8,154.0 5,873.7 5,894.3 C-4,3S-22 3/10/2003 6.0 IPERF 2.5"HSD 2506 PJ,60 deg. phase Mandrel Inserts St on Top(TVD) Valve Latch Port Size TRO Run IariiN Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;7,705.8 1 7,659.8 5,558.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/28/2003 Notes:General&Safety End Date Annotation II12/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY,7,743.9 - IM I= ANCHOR 7,7598 i..... •[( As Al :iii' PACKER;7,780.5 �r MILL;7,765.4 raj NIPPLE;7,784.6 MIIIR I 32- WLEG;7,791.5 IPERF;8,124.08,154.0 PRODUCTION;28.88,412.2- FISH,8,420.0 RECEIVED STATE OF ALASKA ALA KA OIL AND GAS CONSERVATION COMMI ION JAN 3 0 2018 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ '. =tlbtI n ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: DAD ACID TRTMT 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory ❑ 203-011 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-103-20446-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 35-22 ADL 25544 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8,423 feet Plugs measured None feet true vertical 6,081 feet Junk measured 8420 feet Effective Depth measured 8,244 feet Packer measured 7,761 feet true vertical 5,956 feet true vertical 5,625 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 108'MD 108 TVD SURFACE 3,020 feet 9 5/8" 3,050'MD 3050 TVD PRODUCTION 8,386 feet 7II 8,412'MD 6074 TVD Perforation depth Measured depth _8124-8154 feet True Vertical depth 5874-5894 feet Tubing(size,grade,measured and true vertical depth) 3.5" L-90 7,792' MD 5,646'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER SAB-3 PACKER 7,761' MD 5,625'TVD SSSV -NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A . s 4 ) _ t� SCA1 + t4NEU Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-i1cf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 500 1463 Subsequent to operation: 0 0 532 525 3767 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service (] Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer Contact Phone: (907)265-6097 Authorized Signat • --" ----- -� Date: Vg0//g v rr- 3/1 /Iv ,, i` t RDDMS (,v FEB - 1 2C18 • Form 10-404 Revised 4/2017 Submit Original Only • • 3S-22 DAD ACID TREATMENT DTTMST/JOBTYP SUMMARYOPS 12/25/17 MISC RIH TO 8,160' CTM (8,182' RKB), NO OBSTRUCTIONS OR TAGS. PUMP RES SURV GEL SWEEP AND CIRCULATE AROUND PUMPING SLICK DIESEL BOTTOMS UP. CIRCULATE DAD ACID TO END OF COIL, CLOSE CHOKE/SI WELL. SQUEEZE DAD ACID TO PERFS. MAX TREATING PRESSURE =2600 WHP. INITIAL PR= 0.8 BPM AT 2380 WHP. 15 BBL DAD SQUEEZED PR = 0.3 AT 2600 WHP. DPE INCREASES MTP =2720. SWAP TO COIL VOLUME DISPLACEMENT WITH 53 BBL DAD PUMPED (100 BBL PLANNED). 30 BBL DAD SQUEEZED, WHP= 2676 AND PRESSURE BREAKS BACK. DISPLACED COIL VOLUME WITH 3 BBL FRESH WATER AND 35 BBL SLICK DIESEL (8 BBL COIL VOLUME OVER DISPLACEMENT). FINAL INJECTION RATE = 0.3 BPM AT 2581 WHP. POOH FREEZE PROTECTING WELL WITH SLICK DIESEL. RDMO. ****JOB COMPLETE**** KUP Ia 3S-22 co ocoP flips 4 Well Attribut Max Angleilk TD * T i1 II Wellbore APl/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) 0 Alaska,I:x: 501032044600 KUPARUK RIVER UNIT INJ 5140 2,837.14 8,412-0 Cpr10e WtBtPS Comment I-12S(ppm) Date Annotation End Date I KB-Grd(ft) Rig Release Date °.. SSSV.NIPPLE Last WO: 34.10 2/24/2003 3S-22,1/30/2018 6;44:17 AM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag:SLM 8,123.0 10/2017 pproven Last Rev Reason Annotation End Date Last Mod By Rev Reason TAG 1/3/2016 pproven 11 1 A I -& Casing Strings HANGER;24.7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 1 CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED 1!«^ Cas ng Descr ption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I .Grade Top Thread 1• SURFACE 9 5/8 8.835 29.5 3,049.9 2,565.4 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 6276 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings Tu bmg Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/k) Grade Top Connection F TUBING I 31/21 2.9921 2471 779241 5,64661 9.301 L-90 IEUEBRDMOD I Completion Details "" Top(ND) Top Incl Nominal Wyk Top(ftKB) (ftKB) (°) Item Des Com ID(in) / 24.7 24.7 0.15 HANGER FMC GEN V TUBING HANGER 3.500 CONDUCTOR 30.0.108.0 497.3 497.3 0.15 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 I 7,705.6 5,588.5 4825 NIPPLE CAMCO DS NIPPLE w/2.812'NO GO 2.812 MIIIP NIPPLE;497.3 Mb 7,743.9 5,614.1 48.00 SEAL ASSY LOCATOR SUB&PBR 12'SEAL ASSEMBLY(SPACED OUT) 3.010 7,745.9 5,615.4 47.99 PBR BAKER 80-40 PBR w/X0 3.000 7,759.6 5,624.6 47.91 ANCHOR KBH-22 ANCHOR TUBIGN SEAL NIPPLE 3.000 7,760.5 5,625.2 47.90 PACKER BAKER SAB-3 PACKER 3.250 7,765.5 5,628.5 47.87 MILL 80-40 MILL OUT EXTENSION 3.710 • 7,784.6 5,641.3 47.76 NIPPLE CAMCO D NIPPLE w12.75 NO GO 2.992 7,791.5 5,646.0 47.72 WLEG WLEG w/SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) SURFACE;29.5-3.049.9•-•- 8,420.0 6,0792 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN 2/28/2003 REPLACED WITH DUMMY VALVE 12/28/2003 Perforations&Slots Shot Den Top(ND) Btm(TVD) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4,3S-22 3/10/2003 6.0 IPERF '2.5"HSD 2506 PJ,60 deg. GAS LIFT;7,859.8 L phase Mandrel Inserts st 111 oi Nn Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model 0D(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;7,705.8 i 1 7,659.8 5,558.1 CAMCO MMG 1 1/2 GAS LIFT DMV RK 0.000 0.0 2/28/2003 Ian II Notes:General&Safety End Date Annotation 12/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY;7,743.9 ANCHOR 7,759.8 ) ll; 11111 PACKER;7,750.5 MILL;7,705.4 Ph 111 NIPPLE,7,784.6 'IRS I WLEG;7,791.5111 . IPERF;6,124.0-8,154.0:-. PRODUCTION;28.6-8,412.2--.- FISH;B,420.0.------A STATE OF ALASKA RECEIVED • AL•CA OIL AND GAS CONSERVATION COMIRION REPORT OF SUNDRY WELL OPERATIONS OCT 19 2011 1.Operations Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ hutdown ❑ Performed: Suspend❑ Perforate ❑ Other Stimulate El Casing ❑eleirforat ❑ Plug for Redrill❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Marcit Gel Trtmnt 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. ment Develo Exploratory❑ P lorato ry ❑ 203-011 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic ❑ Service ❑r 6.API Number: 99510 50-103-20446-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3S-22 ADL 25544 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8423' feet Plugs measured None feet true vertical 6081' feet Junk measured 8420' feet Effective Depth measured 8132' feet Packer measured 7,761 feet true vertical 5879' feet true vertical 5,625 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16" 108'MD 108' TVD SURFACE 3,020 feet 9-5/8" 3,050' MD 2565'TVD PRODUCTION 8,386 feet 7" 8,412'MD 6074'TVD Tubing(size,grade,measured and true vertical depth) 3.5" L-90 7,792'MD 5,646'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER SAB-3 PACKER 7,761'MD 5,625'TVD SSSV TYPE : NONE N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED DEC. 1 8 2017 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: - - 4800 900 2800 Subsequent to operation: Shut-In - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development p ❑ Service 2 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑✓ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-321 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells En'ineer iii g ' ' 0101.- Contact Phone: (907)265-6097 Authorized Si natur= _ Ammo.— '= Date:/� l /7 vri— / /77/7- It 1X17/1,7 REr<swis LCCT 2 2617 Form 10-404 Revised 4/2017 Submit Original Only KUP INJ 3S-22 ConocoPhillips Well Attribu, Max Angle D TD Al.7k,-1 111::. Wellbore API/UWI Field Name Wellbore Status ncl It) MD(ftKB) Act Btm(ftKB) ConocoPhiltips 501032044600 KUPARUK RIVER UNIT INJ 51.40 2,837.14 8,412.0 °°° Comment I12S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3S-22.10111/20171110.26 AM SSSV:NIPPLE _ Last WO: 34.10 2/24/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'.SLM 8,123.0 1/1/2017 Rev Reason:TAG pproven 1/3/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread Li '-- CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED It Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I .Grade Top Thread HANGER;24.7 r SURFACE 9 5/8 8.835 29.5 3,049.9 2,565.4 40.00_L-80 BTC .l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I..Grade Top Thread Ica. PRODUCTION 7 6.276 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings Tubing Description String Ma...I10(in) I Top(ftKB) I Set Depth(ft..JSet Depth(TVD)(...I Wt(Ib/ft) !Grade I Top Connection TUBING 31/2 2.992 247 7,79241 5,64661 9.30 L-90 EUE8RDMOD - Completion Details 1I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 'j 24.7 24.7 0.15 HANGER FMC GEN V TUBING HANGER 3.500 ,0uw, 497.3 497.3 0.15 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 7,705.6 5,588.5 48.25 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 CONDUCTOR;30.0-106.0 7,743.9 5,614.1 48.00 SEAL ASSY LOCATOR SUB 8 PBR 12'SEAL ASSEMBLY(SPACED 3.010 OUT) NIPPLE,497.3 i 7,745.9 5,615.4 47.99 PBR BAKER 80-40 PBR w/XO 3.000 7,759.6 5,624.6 47.91 ANCHOR KBH-22 ANCHOR TUBIGN SEAL NIPPLE 3.000 7,760.5 5,625.2 47.90 PACKER BAKER SAB-3 PACKER 3.250 7,765.5 5,628.5 47.87 MILL 80-40 MILL OUT EXTENSION 3.710 7,784.6 5,641.3 47.76 NIPPLE CAMCO D NIPPLE w/2.75 NO GO 2.992 7,791.5 5,646.0 47.72 WLEG WLEG w/SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°I Des _ Corn Run Date ID(in) 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN 2/28/2003 REPLACED WITH DUMMY VALVE 12/28/2003 SURFACE;29.5-3,049.9 - Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date ft) Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4,3S-22 3/10/2003 6.0 IPERF 2.5"HSD 2506 PJ,60 deg.phase GAS LIFT;79590 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run 14 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 7,659.8 5,558.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/28/2003 NIPPLE 77056 Notes:General&Safety NM End Date Annotation 12/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY,7,7439 ii ANCHOR;7,759.6 `I ll :1 n l€! •a, PACKER;5760.5 MILL,7,765.4 ,/I NIPPLE;7,784.6 t1!' MD 111 WLEG;7791.511 IPERF,8,124.0-8,154.0-. I PRODUCTION;26.6-8,412.2--°. FISH;8,420.0 • of /111 110 Well History By Date Ca 3S-22 ConocoPhillips API/UWI Legal WeIlName Field Name 5010320446 3S-22 KUPARUK RIVER UNIT Well Type Original KB/RT Elevation(ft) Well Status Development 57.10 INJ Daily Operations Legal WeIlName Start Date End Date Job Typ Job SubTyp Last 24hr Sum 3S-22 9/19/2017 9/22/2017 MISC RES SURV ZX03 Pumping/ 06:00 18:00 Load Well After an abbreviated Injectivity test we started injecting 3000 ppm Marcit gel at 4:15 pm on 09/19/2017. The objective of this job was to achieve 100%shutoff of the limited 8'of perforations that were open at the top. We pumped the following Gel products in the following stages: Gel Pumped: 1550 bbls @ 3000-ppm 2887 bbls @ 5000-ppm 1008 bbls @ 7000-ppm 899 bbls @ 10,000-ppm 1350 Bbls @ 12,000-ppm 20 bbls of sea water 22 bbls of diesel 30 min shut in pressure=2040-psi.Total gel pumped was 7700 bbls. Halliburton pump report attached. Job Complete. Page 1/1 Report Printed: 10/18/2017 • y OF 77 4,s� THE STATE Alaska Oil and Gas ofT c 1 Conservation Commission Witt z 333 West Seventh Avenue 1/4 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572Main: 907.279.1433 5 Fax: 907.276.7542 www.aogcc.alaska.gov Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. SEWED G 2.01 7 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-22 Permit to Drill Number: 203-011 Sundry Number: 317-335 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 . Foerster Commissioner DATED this (..s-dayay f July, 2017. RBDMS lam- JUL 2 7 2017 � � RECEIVED STATE OF ALASKA JUL 2 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 40'7%r 7/25 /'7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Repair Well LJ Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Conductor Extensior0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 203-011 3.Address: 6.API Number: Stratigraphic El . P. O. Box 100360,Anchorage,Alaska 99510 501032044600 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will planned perforations require a spacing exception? Yes ElNo it .? KRU 35-22 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025544 ' Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effectiv tyID: Effectiv De thh 1VD: MPSP(psi): Plugs(MD): Junk(MD): 8,412' 6,074' �� 6 ,7M 2,532 N/A 8,420 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 108' 108' Surface 3,020' 12" 3,050' 2,565' Intermediate Production 8,386' 7" 8,412' 6,074' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,124'-8,154' • 5,874'-5,894' 3.500" L-90 7,792' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV.Camco DS Nipple w/2.875"NO-GO MD=497',TVD=497' . PACKER-BAKER SAB-3 PACKER MD=7761 TVD=5625 , 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 E, GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Mouser Roger Mouser/Roger Winter Contact Name: Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@cop.com Contact Phone: (907)659-7506 Authorized Signature: 1. 7ppl001440 0144 Date:07/19/17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k7-335 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 Post Initial Injection MIT Req'd? Yes ❑ No ]! RBDMS L �.1UL 1 71017 Spacing Exception Required? Yes ❑ No WI Subsequent Subsequent Form Required: JO 04. APPROVED BY Approved by: 913-‘414._ COMMISSIONER THE COMMISSION Date: 7-5 _ /7 P7. /�i6 74.067 V1 ?/�5 i R V + II IQ1 1� � Submit Form and Form 10-403 Revised 4/2017 V d S valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 202017 July 19, 2017 AGC 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-22, PTD 203-011 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-22 (PTD 203-011) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 19, 2017 This application for Sundry approval for Kuparuk well 3S-22 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-22 ConocoPhillips ° Well Attributes Max Angle&MD TD F11,3yK:i,It li:. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cv�ocovwll� 501032044600 KUPARUK RIVER UNIT INJ 51.40 2,837.14 8,412.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 30-22.1/3/2017 12 38:59 PM SSSV:NIPPLE Last WO: 34.10 2/24/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,168.0 8/20/2011 Rev Reason:TAG pproven 1/3/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread /. CONDUCTORill fp16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED 1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,zap Il rSURFACE 9 5/8 8.835 29.5 3,049.9 2,565.4 40.00 L-80 BTC Casing Descnptian i ITubing Strings OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread II PRODUCTION 7 6.276 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 24.7 7,792.4 5,646.6 9.30 L-90 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intl(°( Item Des Com (in) 24.7 24.7 0.15 HANGER FMC GEN V TUBING HANGER 3.500 _ 497.3 497.3 0.15 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 T '�' 7,705.6 5,588.5 48.25 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 CONDUCTOR;30S-108.0 7,743.9 5,614.1 48.00 SEAL ASSY LOCATOR SUB&PBR 12'SEAL ASSEMBLY(SPACED 3.010 OUT) 7,745.9 5,615.4 47.99 PBR BAKER 80-40 PBRw/XO 3.000 NIPPLE;497.3 !• 7,759.6 5,624.6 47.91 ANCHOR KBH-22 ANCHOR TUBIGN SEAL NIPPLE 3.000 7,760.5 5,625.2 47.90 PACKER BAKER SAB-3 PACKER 3.250 7,765.5 5,628.5 47.87 MILL 80-40 MILL OUT EXTENSION 3.710 7,784.6 5,641.3 47.76 NIPPLE CAMCO D NIPPLE w/2.75 NO GO 2.992 7,791.5 5,646.0 47.72 WLEG WLEG w/SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) Ci Des Com Run Date ID(in) 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN 2/28/2003 REPLACED WITH DUMMY VALVE 12/28/2003 SURFACE;29.5-3,049.9-^ Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shotsB Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,124.0 8,154.0 5,873.7 5,894.3 C-4,3S-22 3/10/2003 6.0 (PERF 2.5"HSD2506 PJ,60 deg.phase GAS LIFT;7,869.6 Mandrel Inserts St as on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type _ Type (in) (psi) Run Date Corn 1 7,659.8 5,558.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/28/2003 Notes:General&Safety NIPPLE;7,705.6 j_.. End Date Annotation 12/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY;7,743.9 ANCHOR;7,759.6 '0- ., PACKER;7,760.5 .. MILL;7,765.4 I I NIPPLE;7,784.6NB I WLEG;7,791.5 IPERF;8,124.0-8,154.0-- PRODUCTION;28.8-8,412.2 , FISH;8,420.0 i • Bettis, Patricia K (DOA) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Thursday,July 20, 2017 1:42 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-22 (PTD 203-011): Sundry Application Good afternoon Patricia, The current Effective depth for 3S-22 PTD 203-011 as of 1/18/2017 was: MD=8,132' and TVD=5,879'. 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 10:59 AM To: NSK Well Integrity Field Supv<N1927@conocophillips.com> Subject: [EXTERNAL] KRU 3S-22 (PTD 203-011): Sundry Application Good morning Roger, Please provide the current effective depth for KRU 3S-22 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 10:59 AM To: NSK Well Integrity Field Supv Subject: KRU 3S-22 (PTD 203-011): Sundry Application Good morning Roger, Please provide the current effective depth for KRU 3S-22 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 • IP • VOF T� � � yy� � THE STATE Alaska Oil and Gas ofALA c KA Conservation Commission ''.41;11-1611;*-- ' _ 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke SCANNED 2 Staff Wells Engineer J UL ' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-22 Permit to Drill Number: 203-011 Sundry Number: 317-321 Dear Mr. Burke: 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, hsS. French Chair DATED this L I day of July,2017. RBDMS v•-JUL 1 7 2017 • • RECEIVED EIVE STATE OF ALASKA JUL 1 1 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ' Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT GEL TRTMTO, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 203-011 • 3.Address: Stratigraphic ❑ Service 0 , 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20446-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A -' Will planned perforations require a spacing exception? Yes ❑ No 0 / KRU 3S-22 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25544 t Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,423' 6,081' % 8244 • 5956 ` 2490 NONE 8420 Casing Length Size MD ND Burst Collapse Structural Conductor 78' 16" 108' 108' Surface 3,020' 12" 3,050' 3,050' Intermediate Production 8,386' 10" 8,412' 6,074' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8124-8154 1 5874-5894 3.500" L-90 7,792' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER SAB-3 PACKER . MD=7761 TVD=5625 SSSV: NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development❑ Service 0 . 14.Estimated Date for 8/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 + GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engin r Contact Email: Jason.Burke@cop.com _,-._ Contact Phone: (907)265-6097 Authorized Signatur Date: 7/1/12//I COMSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 k7- 3 21 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: • Post Initial Injection MIT Req'd? Yes 0 No0 — ¢ RBDMS U-' JUL 1 7 2017 Spacing Exception Required? Yes ❑ No ZSubsequent Form Required: tia:g"---\_ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: X)(,\ 1 . ?i'.// -- Jay V`T- 3//31/.' A _v RpI n /•` LalidppSubs in Form ane lForm 10-403 Revised 4/2017 r+VJ�I �a�t for 12 months from the date of approval. Attachments in Duplicate S Proposed 3S-22 MARCIT Gel Treatment 3S-22 water injectivity has fluctuated over time and this well has moderate injectivity(<2 bpd/psi) and the wellhead pressure is high. The well has interactions with 4 offset producers (3S-03, 3S- 18, 3S-19 and 3S-23A) based on the gas injection-production correlations and had rapid tracer breakthrough (— 10 days) to the 3S-19 offset producer. 3S-03, 3S-19 and 3S-23A have rapidly increasing water-oil-ratios. The 2007 injection profile indicated that 100%of injection was going to 8,124' — 8,132' at all flow rates and the base of the injection was at 8,154'. No crossflow was observed. The 2017 injection profile indicated a possible casing leak at 7,870' and there could be some scale deposition at 7,850'. Objective of the proposed conformance treatment for 3S-22 is to partially fill the void space conduit with a full bore Marcit gel treatment. ✓ Procedure 1. Perform MIT-T and MIT-IA on tubing and inner annulus to confirm integrity. 2. Cover the top of sand to(6"to 1')with graded calcium carbonate to prevent gel penetration into the lower perforations. 3. Conduct a step rate injection test to set a baseline before job execution to compare against the job rates and pressure. a. Start at an injection rate of --- 1000 BPD or — 0.69 BPM and establish stable conditions for—4hrs. b. Step injection rate up to—2000 BPD or— 1.39 BPM and establish stable conditions for—4hrs. c. Step injection rate up to—3000 BPD or—2.08 BPM and establish stable conditions for—4hrs. d. Step injection rate up to—4000 BPD or—2.78 BPM and establish stable conditions for—4hrs. 4. Pressure up inner annulus to 500 psi. 5. Start injecting produced water until gel is mixed. 6. Once a stable rate and pressure has been reached and the gel is ready for pumping, start gel pumping as shown below at the desired concentrations and rates in stages.Final two stages (7,000 ppm and 10,000 ppm polymer concentrations) of polymer injection will need to be with seawater. Keep polymer concentrations as stable as possible and provide pump rate and pressure data. Monitor changes in pressure as this may be an indication regarding the nature of the void space conduit. Target Concentration Design Volume Treatment Rate Total Treatment Rate Target Polymer PU24 Polymer Concentration (ppm) (bbl) (bpd) (bpm) (#/day) (ppm) Days 3000 12000 4500 3.13 4720 5400 2.7 5000 4500 4500 3.13 7867 9000 1.0 7000 3000 2500 1.74 6119 7000 1.2 10000 1500 2500 1.74 8741 10000 0.6 Total 15000 5.5 7. Evaluate pressure changes over time to target final pump rate and pressure • • 8. After pumping the gel, inject 46 bbls of produced water and then inject 22 bbls of diesel for surface freeze protection. 9. Once gel has been displaced,monitor the pressure for— 1 hour. 10. Leave the well shut-in and wait for gel to cure—4 days to allow the polymer to cross link. 11. Perform a fill cleanout and assure one to one return inside the wellbore. Wash the lower perforations 12. Bring the well online (start from 25%of target rate)and gradually increase the rate. KUP a1 3S-22 Minim . ConocoPl ulhps Well AttriMILIF Max Ang MD TD AIetsk<t.Int, • Wellbore APIIUWI Reld Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) GJrl000hhilips 501032044600 KUPARUK RIVER UNIT INJ 51.40 2,837.14 8,412.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 35-22,7/62017115558 AM SSSV:NIPPLE Last WO' 34.10 2/24/2003 Velma)schematic(actuS) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,123.0 1//2017 Rev Reason:TAG pproven 1/3/2016 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread a CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED ill Casing Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen p...Grade Top Thread HANGER.24.7 I �,., SURFACE 9 5/8 8.835 29.5 3,049.9 2,565.4 40.00 L-80 BTC �;i Casing Description 08(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread �r1,w; PRODUCTION 7 6.276 26.6 8,412.2 6,073.7 26.00 L-80 BTCM Tubing Strings AWL.- Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection ;:. TUBING 31/2 2.992 24.7 7,792.4 5,646.6 9.30 L-90 EUE8RDMOD Completion Details Nominal ID I FJ Top(ftKB) Top(ND)(ftKB) Top Incl(°) tem Des Com (in) .111 24.7 24.7 0.15 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.3 0.15 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 inrvenriP'Imp,' ".,P4 PIM Pli 7,705.6 5,588.5 48.25 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 CONDUCTOR;30.0-108.011 SEAL ASSY LOCATOR • 3.010 • 80-40 1 • 3.000 NIPPLE;497.3 , 7,759.6 5,624.6 47.91 •• ••TUBIGN SEAL NIPPLE 3.000 1 13.250 • 80-40 MILL OUT EXTENSION3.710 Other• 7,784 6 5,641.3 47.76 NIPPLE CAMCO D NIPPLE w/2.75 NO GO 2.992 . 7,791 5 5,646 0 47 72 WLEG VVLEG w/SHEAR OUT SUB 2.992 REPLACEDTop(TVD) Top Inc! • 8,420.0 6,079.2 45.36 FISH FISH VALVE DROPPED TO BOTTOM WHEN 2/28/2003 WITH• 12/28/2003 SURFACE;29.53,049.8 Perforations&Slots Shot - Dens • Top(ftKB) Btm(fIKB) (ftKB) (ftKB) Zone ate ft) Type Com I 8,124 1 1 I'II •1 •250661 deg.phase GAS LIFT,7,6598 4ll Mandrel Inserts St I ati on Top(TVD) Valve Latch Port Size TRO Run Nr Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 7,659.8 5,558.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/28/2003 NIPPLE;77056 Notes:General&Safety Entl Dale Annotation 12/27/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY;7,743 9 --' 11. ANCHOR,7,759.6 )1 PACKER;7,780.5 rI. MILL:7,785.4- , I NIPPLE;7,784.8 116 Mi WLEG;7,791.5 'A0 (PERF;8,124.0-8,154.0-. PRODUCTION;26.6-8,412.2-. FISH;8,420.0 O c j • • O o co ) a; Ln° ` 6 U Q > ) a o in 0 pfl T tIn 0 NI (}N ^ Y O O E a) - W C C — —. ' •r r tC (0 +, O vi CU t.. �s m o a c c +� o ¢may d @ ate, 1.6 'C 4 '6 11 ,_ oNs m o ° a c .. T ¢ 0 U E > a m 0 W r r r r r r t v Ou L J a E s .0 o v7 ¢ - c c c c c c +� J Ia f6 A f6 f6 16 :� C of -, -> -, 7 7 7 C c U t S _6 Q N N N M UU C a3 O U Z Q CI a1 > E .D u O C a F 00 N N OU F- 0 0 0 0 0 0 c ` v 0 W J J J J J J 0 C 'C U 9O } W W W W W W v O F- LL LL LL LL LL LL a)a > - O ¢ J J J J J J v N C _C 4- Z Z in a z z z z z z • U CO av, ° v LL LL LL LL LL LL CC •C > 00 C W_ 4-, i > C a, E +' O L O c ai U 0 , a a u > O Z C 0 a3 �, U .`C. 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O a) wC N In In In In )n _ o• N G C - - m in QJ u •� U C.en o) C C W Q - C CO u maK '° a.) • all f" aj rl Q c0 N 'R a0 y�'',, 4.1• F- _ OD z r N O r t0 i_ d Eoe �n Jtnd) XYm �j E J M M N N vt Z N r Q W C *'' N v1 C ,� U f� , ��., f0 .0 a) co 0 CA a al < i a` a Q ') Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q3 - 0 1 L Well History File Identifier Organizing (done) ~WO-Sided 11I1111111111111111 ~scan Needed If , R~AN ~ Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No.~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: BY: Helen ..(Maria ") o Other:: , . iJ Date: If/:J.!6 a.'1 151 m . NOTES: Project Proofing BY: HelenC MariV ~- Datelf :J-<2. OS 151 V\1P Scanning Preparation ~ x 30 = (00 . I + Q = TOTA_ PAGES IoQ I (Count do~s not ìlclude cover shelr.) Date: if d..-8 o:s 151 , 1 f)1J BY: HelenCMaria) Production Scanning Stage 1 Page Count from Scanned File: 7 0 (Count does include c7' sheet) Page Count Matches Number in Scanning Preparation: V YES Stage 1 If NO in stage 1 page( s) discrepancies were found: NO Date: if :;.g 103 151 M ';J , YES NO BY: Heier(.. Maria ) BY: Helen Maria Date: 151 IIIIII1 Scanning is complete at this point unless rescanning is required. ReScanned II 11111 BY: Helen Maria Date: 151 Comments about this file: Quality Checked "I "11111111111111 • MEMORANDUM Tai Jim Regg L / P.I. Supervisor ~(j V Ji'~i /u FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3 S-22 KUPARUK RIV UNIT 3S-22 Src: Inspector NON-CONFIDENTIAL Reviewed By: r P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 35-22 Insp Num: mitRCN100809162208 Rel Insp Num: API Well Number: 50-103-20446-00-00 Permit Number: 203-011-0 Inspector Name: Bob Noble Inspection Date: 8/x/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ss-zz ' Type Inj. ~ w TVD 5626 ~ IA 1220 1840 - 1830 1830 y P.T.D 2osollo' TypeTest SPT Test psi ~ Isao OA Igo 2IO zto 2Io Interval avRTST p~F P -Tubing z~2o 2no z~2o z~2o Notes: tit; ~1, (z' ~ ~~ -~S~ ~ ~~~; Tuesday, August 10, 2010 Page 1 of 1 • MICROFILMED 03/01/2008 • DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~L,aserFiche\CvrPgs_Inserts~Microfilm_Marker.doc ~~' -~ Œ ScbllDlbepg8P RECEIVED Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth APR 0 6 Z007 ~ 011 & Gas Coos. Commission Anchorage ~?R 1 () 1JJf)7 SG~NEO () x¿. 00"3 -0 l { WeU Job# Log Description Date 04/05/07 NO. 4205 Company: Alaska Oil & Gas Cons Comm Atin: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 2M,12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1 H-02 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331' N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 1'6 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 03/20/07 Schlumberger ., '\ft--.¡ ..1 / ~. / i_ L .. / / ^~" NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth tt~R ~J, 2. Z007 Oil (;O!nr~NED APR 0 3- 2007 Company: Alaska Oil & Gas Cons C'omm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ()IC- 803 -0 l( Well Job # Log Description Date BL Color CD 1 C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1 E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1E-117 11626471 INJECTION PROFILE 03/14/07 1 1Q-09 11638839 INJECTION PROFILE 03/16/07 1 3S-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1 C-1 0 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 1D-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. l-S~ . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Librarian 333 West 7th A venue, 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- <903 -03\ ~ L.ß~ Digital Log Images: 50-103-20452-00 1 CD Rom 3S-22: U:r:c... ~03-o II ti: ~ 1'-/3 (0'1) Digital Log Images: 50-103-20446-00 1 CD Rom 3S-23: ¿)ó3 -ö4S- * 1'-1365"" Digital Log Images: scANNED JAN 3 0 2007 50-103-20453-01 1 CD Rom 3S-24: Qó3 -0-=4 tL ILl3~1- Digital Log Images: 50-103-20456-00 1 CD Rom c. U---- - . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim ReggK?/,/ ~1Sï:-)IL~" P.I. Supervisorl -"i~l DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests eONoeOPHILLIPS ALASKA INe 3S-22 KUPARUK RIV UNIT 3S-22 tt\\\ ~02('V FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvlT-"~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3S-22 API Well Number 50- I 03-20446-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060829122302 Permit Number: 203-011-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 35-22 Type Inj. w TVD 5626 IA 1120 1730 1700 1700 P.T. 2030110 TypeTest SPT Test psi 1500 OA 220 240 240 240 Interval 4YRTST PIF P / Tubing 2300 2300 2270 2270 Notes 1.1 BBLS diesel pumped. 1 well house inspected; no exceptions noted. SCANNED SE? 0 8200B Wednesday, August 30, 2006 Page I ofl . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 :! Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 'dvD 3 - 0 II óS-~'}..- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). 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. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 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 ConselVation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage,AJaska 99501 February 18, 2004 1?J Li7LP RE: MWD Formation Evaluation Logs 3S-22, AK-MW-2280031 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 3S-22: Digital Log Images 50-103-20446-00 J03-0ll 1 CD Rom 4~~~J) ~2)991[)(() )~ ~ì{s~\~ DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 APllf.~j/;t;±~ ) ~0 Permit to Drill 2030110 Well Name/No. KUPARUK RIV UNIT 3S-22 Operator CONOCOPHILLlPS ALASKA INC MD 8423'--- -----.------- ------ TVD 6081 /' Completion Date 3/10/2003'-- Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -- --~- DATA INFORMATION Types Electric or Other Logs Run: GRI RES/ DEN/ NEUT Well Log Information: Log/ Data Digital !ypyMed/Fnnt ft69 /, 09 ~ - :~/ ~ !~ i i ¥'pt ~. ~ ¡ðÝ D I bt . ,~ Las ~ (data taken from Logs Portion of Master Well Data Maint) Electr Dataset Number . N~e 'P'ê'rforation Directional Survey 11644 L-:G Vt:,lncallon ~ r ~ -4"" Log Log Run Interval OH/ ~. Scale Media No Start Stop CH Received Comments 5 Blu 1 7590 8190 Case 4/14/2003 0 8423 Open 4/22/2003 MWD 6 3029 8390 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/28/2003. 0 8423 Open 4/22/2003 MWD 6 3029 8390 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 3029 8390 Open 4/29/2003 REPLACED BY NEW DATA RCVD 07/24/2003 Directional Survey LIS Verification LIS Verification ~'ent Evaluation Directional Survey 11644 ys \/erif¡eation[ VI j ~~... 5 Col 7655 8190 Case 4/14/2003 -' 0 8423 Open 4/22/2003 3029 8390 Open 4/29/2003 REPLACED BY NEW DATA RCVD 07/24/2003 0 8423 Open 4/22/2003 7640 8175 Case 5/4/2004 CGM PDF TIF GRAPHICS 7640 8175 Case 5/4/2004 DSN 12559 Sample Set Number Comments Directional Survey 12559 Injection Profile ~ction Profile Blu Well Cores/Samples Infonnation: Name Interval Start Stop Received Sent DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030110 Well Name/No. KUPARUK RIV UNIT 35-22 Operator CONOCOPHILLlPS ALASKA INC MD 8423 TVD 6081 Completion Date 3/10/2003 Completion Status WAGIN ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Chips Received? ('(~ Formation Tops Analysis Received? ~ -~ Comments: --- ¡JC1 ---------~ Compliance Reviewed By: API No. 50-103-20446-00-00 Current Status WAGIN 8N WN Date: UIC Y ~-" J ~ 11(1 ~ \- --- J¿Slf. ) WELL LOG TRANSMITTAL ,} ProActive Diagnostic Services, Inc. ;}o) - a ( t To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 ~"7;(~ L\-- ZL\-Ö\.! Res. Eva!. CH 1 1 ~~~\ (rP\~ 1 )' )) ')- ct Mech. CH Caliper Survey 1 Rpt or 2 Color Signed: Date: Print Name: PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 ~ó9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com 1. Operations Performed: Abandon ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . 0 Suspend· O· Operation Shutdown 0 . O· Repair Well· 0.; . Plug perforations·. 0 o Pull Tubing . 0 Perforate Nevi Pool ·0 4. Current Wøll Statu.s: . Development: . 0 . Exploratory· O· . Stratigraphic 0 Service 0 Perforate. 0·. . StimlJlate··O·· ¿J;:¡::¡W -JIll' 6.) It<;, Variance 0 ~nnular Disp. 0 Time.l;xtel1sion. O. . Re-emter:S.lIspended Well. 0 5. Permit to Drill Number: 203-0111 6. API Number: 50-103-20446-00 Other 0· . . . '. Alter Casing . . Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 57' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 9. Well Name and Number: 3S-22 10. Field/Pool(s): Kuparuk Oil Pool Total Depth Effective Depth measured 8423' feet 6081' feet 8244 feet 5956 feet Size MD Plugs (measured) Junk (measured) measured true vertical true vertical Casing Structural Length TVD Burst Collapse SURFACE PRODUCTION 3023' 8386' 9-5/8" 7" 3049' 8412' 2565' 6071' Perforation depth: Measured depth: 8124-8154 RECEIVED MAK 1 2 2004 Ala8ka on & GIs Cons. Commiaeion ~ true vertical depth: 5874-5894 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7792' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 497' 14.'Stimülatio~òfçerhEmt~qÚ~~;zesÜlT1m~rY: . .:' .." .... .... . ".. . ,":"". .. . ... . . . . .... ... I ntervalstreäted(rneastlred) . ... .. .. ... ..' . Treatmel1td$striPtìonsincluding VcSlurheSLJSed and finCilpressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubinç¡ Pressure Prior to well operation 4034 1600 2464 Subsequent to operation 4130 400 3066 14. Attachments 15. Well Class after proposed work: Copies of Logs and SuryeysJun '--- ExploratoryO Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasO WAG0 GINJD WINJD WDSPLO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Jeff Spencer@ ·659-7226 p~inted Na~ jRo~ D. 9}ri~nsen J.sen SlgnaturelJ~ ~ Form 10-404 Revised 2/2003 · ~8\rl. Title Phone .:...~\ ,."'\ ~~ Production Engineering Technician ¡ .: ...659-7535 Date '3 JIb/AU I ~ t ~ / ¡ 70' J t'ð\~~~.\ I SUBMIT IN DUPLICATE ) 3S~2 ) DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02l27/04lCommented WAG EOR Injection. ) i '(~ Conoc~hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26,2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ) ~ECI2IJ ø /..", ' V€D 4'~Q'¡& . 0 .1 2{JOJ GaS Q,h, ~, Dear Mr. Maunder: 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 surface 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 notification 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. /~~I MJZ / ConocoPhillips Problem Well Supervisor Attachment J:.\.\ ~r'<)~<t ~,'Of""\~~ ~,,-(t~"'\-' +0 'r ~\,\ 'o~,-~" ~~~ ~<:,J.~~ ~~<!:- "'S.~0 \ k¡ '-~ ""-"- "'-~~ -\ò S<..:l~. Ã. \ \ o~ -\-~ "TC) ~tt ~-\-\--, S ~~ \:JQt"'1 f'.Q..~\ -\-~~ Sû~~. ~ 0 1;.ù ,-\- '"'<L \ C1. c...\ \ 0 ~ "<2:.ct.~{J.' 'i ß)!/rr? l"d- Á - Q -S · ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well TOC Volume Sacks Name PTD# Type ft 88LS Cement 3S-03 2030910 Prod 8 0.6 3.6 3S-07 2021870 Prod 8 1.5 9.1 3S-09 2022050 Inj 14 2.5 15.1 3S-1 0 2022320 Prod 12 1.5 9.1 3S-14 2022210 Inj 3 1.5 9.1 3S-15 2022540 Prod 8 0.8 4.8 3S-17 A 2030800 Prod 12 1.1 6.6 3S-18 2022060 Prod 10 1.1 6.6 3S-19 2030960 Prod 5 1.1 6.6 3S-21 2030310 Inj 5 0.5 3.0 3S-22 2030110 Inj 7 0.9 5.4 3S-23 2030450 Prod 2 0.3 1.8 ') ) WELL LOG TRANSMITTAL dO~ -,U\I\ {\~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West ih Avenue, Suite 100 Anchorage, Alaska June 03, 2003 RE: MWD Fonnation Evaluation Logs 3S-22, AK-MW -2280031 1 LDWG fonnatted Disc with verification listing. ~I#: 50-103-20446-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. AnchR~e@tVf!D JUL 24 2003 ÍÌ1 O\ttllka Œ1 & Gas Cón~. Commi5!ion Signed: N:5..eA ~ Anchorage () Note: This Data Replaces Any Previous Data For WeIl3S-22. ) ) aa3-0/1 IlloL/~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COlTIm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 18,2003 RE: MWD Formation Evaluation Logs 3S-22, AK-MW-2280031 1 LDWG formatted Disc with verification listing. API#: 50-103-20446-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~~~ RECEIVED APR 2 9 2003 Alaska or¡ & Gas Cons. Commission Anchmge r 03/25/03 Schlumberger NO. 2720 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ Well Job # Log Description Date BL Color CD 1C-15 ~5Ç?-~ 1C-190,:::>(D3-œ3 3S-22 õ:05-0J, 23101 23103 23102 SCMT USIT SCMT 03/11/03 03/09/03 03/06/03 1 1 1 ~ RF~""'VC·D·_·· : _"" _~ t": 1 .. ;1 SIGNE~ I~ lliy{J APR 1 4 2003 DATE: Alaatta Vfi & Gas Cons. Comm~n AnctJomge Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of well Classification of Service Well oilD GasD 2. Name of Operator ConocoPhillips Alaska, Inc. ':;'·,':':'''::;:\;:'~''''':'~;:~:'.f ;1 ~.', );[.;;1'~ K)N~~'I-' 3. Address,i ; Y~~~r~~ .~:, P. O. Box 100360, Anchorage, AK 99510-0360 ., :"~"~i 4. Locati~n of well at S,Urface i .\"ë j t;¡~~~.,'''· ,"'~~.i 2556 FNL, 1227 FEL, Sec. 18, T12N, R8E, UM ~ .1': ,t _ 2 i~ASP: 476033, 599386jl,:~,,..,!\":h·:':;1'"'':t " At Top Producing Interval ~_._~_tlJ~¡ 2038' FSL 1472' FEL Sec 13 T12N R7E UM ;,::,' '\:.l)iU:;!CI;cn (^;"p. 470979 5993192) , ,.", ~ ""F . , At Total Depth t::;~~'~~;"~"1I':1' 2002' FSL, 1685' FEL, Sec. 13, T12N, R7E, UM (ASP: 470766, 5993157 ) 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB 28 feet ADL 25544 ALK 2639 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J 15. Water Depth, if offshore ¡::ohr""'~ MtJI,.r-c,1I /0, February 12, 2003 February 21, 2003 ~ '-"T, 2003 -µ::o~ N/A feel MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 8423' MD 16081' TVD 8244' MD 15956' TVD YES 0 No 0 DS Nipple @ 497' Suspended o Abandoned D Service [2] MW AG injector 7. Permit Number 203-011 1 8. API Number 50-103-20446-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3S-22 11. Field and Pool Kuparuk River Oil Pool Kuparuk River Field 16. No. of Completions 21. Thickness of Permafrost 1666' MD 22. Type Electric or Other Logs Run GR/Res/Dens/Neut 23. CASING SIZE WT. PER Fr. 16" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3050' Surface 8412' HOLE SIZE CEMENTING RECORD AMOUNT PULLED 42" 59 bbls Arctic Crete 12.25" 8.5" 543 sx AS IIIL, 275 sx LiteCrete 250 sx Class G w/GasBlok 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 3.5" TUBING RECORD DEPTH SET (MD) 7792' PACKER SET (MD) 7761' 25. SIZE 8124' - 8154' MD 5874' - 5894' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production started injecting 3/11/03 Date of Test Hours Tested Flow Tubing Casing Pressure PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period> Calculated OIL-BBL GAS-MCF 24-Hour Rate> W A TER-BBL CHOKE SIZE GAS-OIL RATIO W A TER-BBL OIL GRAVITY - API (corr) pressure psi not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A F<ECEìVED .APR 0 2, 2003 Alaska œ & Gø Coos. Ccmrrnssion A¡};:~~'¿ve G ¡~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate RBDMS BfL ~ \ I I",..) t l~, APR ,4 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top C Sand Top A Sand 8123' 8153' 5873' 5893' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869 Signed~~ R. Thomas Title Kuparuk Drilling Team Leader Date ~i /è.. (6 ::s 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 ') .....;:. ..'.: . "; ".. .: ..... .:';" :;, ....:. .:.- . '.. ...:.-. ." . .. .. . . . ". . . '. .. . .. . : -:.;......... ..:.... .. .. '.' .... . .." ." :.... .... ...;.;.....:. ;..... . ...... : ..:: :". .. ". ....... :" .... :.": ,". ': . .:.. . ". . .." ",. "":" ....:...... .....:. :" ..:.... ,". "' . . '. . .... .... . '. :" .. ":' . ......... . :......... .: ".' :....:::..."' .: ..... ;.::.";" ". ", ".:: ".. .:' ;' .......... ":." ::......,.....:"" .":: "::: .. '". ".. .. . ,". . .". .... ".. .. . . . "' .... .... . .. . . ..,.. . .' ,.... '" . .,... .. .... .... . .... ... ......... ... .. ... ........ ... . ... ....... .... ..,........ .. '. .'.;::>L ::... .:.. .··......8()nøG()P.hnH~F~'~$kå.:...·...·;t< ....'.... ':, ..;.' ,,;QþØ~~é1tiq~~'§LltrI:~;;try i·~~R~r~ ACCEPTED RIG @ 09:30 Hrs 2/11/03 Hook Rig Up to High Line Power, Had to Dig Cable Out from Snow, Unloaded 1 Load of Spud Mud into Pits & Cont to Mixed Spud Mud in Pits NU 16" Divertor Line Changed Over Top Drive & Iron Roughneck Back to 5" Dp from 4" Dp Serviced Rig & Top Drive Cut & Slip 99' of Drlg Line RIH With 1 Jt HWDP & Function Tested Divertor & Closing Unit, Good Test, NOTE: Jeff Jones with AOGCC Waived Witnessing of Test PU & Stood Back 23 Jts 5" HWDP, Jars and 3-61/4" NM Flex Dc's Began Bringing BHA #1 to Rig Floor Fin Bringing BHA #1 Xo's & Stab's to Rig Floor RU HES Slickline to Run Gyro Repaired Hyd Hose on Drawworks & Adjusted Backstop on Skate Began PU BHA #1, Found Sperry Sun's MWD Hang-Off Sub Had Wrong Conn on Pin End, PU and Set MM to 1.5 Deg. Fill Stack & Checking for Leaks, Pressure Test Surface Lines to 3,500 Psi, Fin Pre-Spud Check Sheet Waited on XO Sub For Sperry Sun's Non-Mag Hang-Off Sub Fin MU BHA #1, Orient & Pulse Test Tool, Washed Down to 108' Spud Well and Drill 12 1/4" Hole from 108' to 180', (72') ART 3/4 Hr. Survey with MWD, No Survey, Blow Down Top Drive & Ran Gyro at 83' - .5 deg Drill 12 1/4" Hole from 180' to 270' (90') ART 1/2 Hr, AST 1/4 Hr, 396 Gpm's, 750 Psi, 50 Rpm's, 10-25 K WOB, Attempted Survey with MWD Tool & Tool Failed Monitored Well-Static, Blow Down & POOH for MWD Changed Out MWD, Surface Test Same & TIH Drill 12 1/4" Hole from 270' to 451', (181') AST 21/4 Hrs, ART 1/4 Hr, Slowed Gpm's to 315 Gpm, 880 Psi 25 K WOB, 60 Rpm's Gyro at 353' -.4 deg Drill from 451' to 575', (124') AST 1.5 Hrs, No Rot., 315 Gpm, 840 Psi Off Btm Press, 880 Psi On Btm, Off Btm Torque 1 K Ft#'s, On Btm 2.5K Ft#'s, 35K WOB, Rot Wt 45K, PU Wt 45K, S/O 45K Circ & Survey, Evaluated Survey's & Close Approach to 3S-26, Not Getting Required Build from BHA and Determined Would Cross Hard Une, Decision made to POOH & Change MM bend from 1.5 deg to 1.83 deg. Notified Pad Operator to Shut In Injection on Well 3S-26 Until Drilling Past Well, Well Shut Down @ 01:00 Hrs 2/13/03 TRIP SURFAC POOH to Mud Motor TRIP SURFAC Changed Bend in MM from 1.5 Deg to 1.83 Deg, Oriented Tool DRLG SURFAC TIH after POOH & Changing MM from 1.5 Deg to 1.83 Deg, TIH to 575' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-22 38-22 ROT - DRILLING Ftôm..TQ .··tHqýrs..·..··¢qâè: ·~d/~ . <>Rh¡i$e··· 2/11/2003 00:00 - 03:00 3.00 MOVE RURD DEMOB 03:00 - 06:30 3.50 MOVE MOVE MOVE 06:30 - 12:00 5.50 MOVE RURD RIGUP 12:00 - 14:00 2.00 MOVE RURD RIGUP 14:00 - 15:30 1.50 WELCTL NUND SURFAC 15:30 - 18:00 2.50 RIGMNT RURD SURFAC 18:00 - 19:00 1.00 RIGMNT RSRV SURFAC 19:00 - 20:30 1.50 RIGMNT RSRV SURFAC 20:30 - 21 :00 0.50 WELCTL OTHR SURFAC 21 :00 - 23:30 2.50 DRILL TRIP SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 2/12/2003 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 02:00 1.50 LOG RURD SURFAC 02:00 - 04:00 2.00 RIGMNT RGRP SURFAC 04:00 - 05:00 1.00 DRILL TRIP SURFAC 05:00 - 06:00 1.00 DRILL CIRC SURFAC 06:00 - 10:00 4.00 WAlTON EQIP SURFAC 10:00 - 11 :00 1.00 DRILL TRIP SURFAC 11 :00 - 12:00 1.00 DRILL DRLG SURFAC 12:00 - 13:00 1.00 DRILL SURV SURFAC 13:00 - 14:00 1.00 DRILL DRLG SURFAC 14:00 - 14:30 0.50 DRILL SURV SURFAC 14:30 - 15:30 1.00 DRILL TRIP SURFAC 15:30 - 16:30 1.00 DRILL TRIP SURFAC 16:30 - 20:00 3.50 DRILL DRLG SURFAC 20:00 - 20:30 0.50 DRILL SURV SURFAC 20:30 - 22:00 1.50 DRILL DRLG SURFAC 22:00 - 22:30 0.50 DRILL SURV SURFAC 2/13/2003 22:30 - 23:30 23:30 - 00:00 00:00 - 01 :00 1.00 DRILL 0.50 DRILL 1.00 DRILL 8tart: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 Group: Removed Berms and Moved Off Injection Equip., Ball Mill & Mud Pits from 3S-16, Dug Out Snow & Grade Pad Around 3S-22 , Unable to Reach Around Well Until Mud Pits Were Moved Lay Mats & Herculite Around 3S-22, Set in Tree & Gen V Wellhead & Spool, Rig Off 3S-16 @ 03:00 Hrs, Moved Rig 60' and Spotted Over 3S-22 @ 06:00 Hrs. Spot Mud Pits, Ball Mill & Injection Skid, Berm Around Same, Hook Up Service Lines to Pits, Began NU 21 1/4" Divertor, Took on Water into Pits @ 10:00 Hrs Printed: 3/10/2003 1 :38:28 PM ) ) . . .. ... ... .. .. .. . ..... ... .. ..... . ...... ""...... .".... . ..... . ....... . . . . . .. . . .." ....... , ,;. . ","." .". . ...... .... ". . ::' . . ........ ... ." .. .... .. . .... .. ..... , . ... '.' ... ." . ..... . . ... ." .. . ". .. .. ..... ...", ... ... ·""0 . "... "::' .": .. ... ...... ...... .... ..' .. ... .. .... . . . . ,·..·...·.·.··....~~P~CQ~~ill!~~1! ~~¡< t. < ºRe:råti~l·l~ ·..$LJn1rn¡trY¡Ff~pgrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-22 3S-22 ROT - DRILLING Start: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 G ro up: ':' : .....: :...... 'S:'b 'I-IQÛtsiQÓge .!bpclei ·Pné1s~ , .', ''',' '.'., . . .... . .. ... . . . . '. . '"' .. ... ..... . D. e$4riptïQhorÔPßr~tiQrîß..··"····· .... ".. . ..... .....", ....... .... ... . ...... 2/13/2003 01 :00 - 05:00 4.00 DRILL DRLG SURFAC Drill, Slide & Survey F/575 , to 787', (212') AST 3114 Hrs, No Rot, 40-45K WOB, 307 Gpm's 975 Psi, Rot Wt 68K, PU 68K, Dn WT 68K, Unable to Get Build Needed to Clear Close Approach to 3S-26 05:00 - 05:30 0.50 DRILL CIRC SURFAC Circ Btms Up, Monitored Well & Blow Down Top Drive 05:30 - 07:00 1.50 DRILL TRIP SURFAC POOH Wet, Pulled MWD & Broke Out Bit 07:00 - 08:30 1.50 RIGMNT RSRV SURFAC Serviced Top Drive & Cleaned Rig Floor 08:30 - 09:30 1.00 DRILL PULD SURFAC PU & MU XO Subs to Run Gyro on 5" DP 09:30 - 10:30 1.00 DRILL TRIP SURFAC TIH to 770', PU 10' Pup Jt And Set Bit @ 777' 10:30 - 11 :30 1.00 DRILL SURV SURFAC RIH with Sperry Sun's Gyro on HES Slickline, Ran Gyro @ 752', Angle 6.45 Deg AZ 261 Deg, POOH wlSlickline, PU on DP & Ran 2nd Gyro @ 712', Angle 4.6 Deg, AZ 257 Deg, POOH w/Gyro & Slickline 11 :30 - 13:00 1.50 RIGMNT RSRV SURFAC Circ Hole While Nabors Commissioned Auto Driller- Not Completed, Worked on Auto Driller While Working on New Directional Plan, To Fin Commisioning Once in Tangent Section of Well 13:00 - 14:30 1.50 DRILL TRIP SURFAC POOH W/5" DP, LD XO Subs & Bit 14:30 - 15:30 1.00 DRILL TRIP SURFAC MU BHA #5, RR 12 1/4" Bit W/MM Set at 1.83 Deg Bend, Oriented MWD & Surface Test Same 15:30 - 16:00 0.50 DRILL TRIP SURFAC TIH to 787', No Prblems or Fill 16:00 - DRILL DRLG SURFAC Drill, Slide & Survey Per Directional Plan Fn87' to 1 ,287'MD/1 ,275' TVD, (500') AST 5 Hrs, ART 3/4 Hr, 40K WOB, 55 Rpm's W/Rot, 375 Gpm 1,200 Psi On Btm, 1,000 Psi Off, Off Btm Torque 2K Ft#'s, On Btm 5K Ft#'s, Rot Wt 85K, PU Wt 85K, Dn Wt 83K, Ave BGG 20 Units 2/14/2003 00:00 - 08:30 8.50 DRILL DRLG SURFAC Drill, Slide & Survey F/1,287' to 1,701' MD/1,655' TVD, (414'), ART 1/2 Hr, AST 4 1/2 Hrs, 365 Gpm, Off Btm Press 950 Psi, On Btm 1,000 Psi, Off Btm Torque 2K Ft#'s, On Btm 5K Ft#'s, 30-40K WOB, 60 Rpm's, Rot Wt 85K, PU Wt 85K, Dn Wt 80K, Attempted to Survey with No Success 08:30 - 10:00 1.50 DRILL SURV SURFAC POOH & Took Survey's @ 1,701',1,668',1,487' & 1,287' with No Success, MWD Not Showing Good Survey's 10:00 - 12:00 2.00 DRILL TRIP SURFAC Monitored Well, Blow Down, POOH & LD MWD 12:00 - 14:30 2.50 DRILL PULD SURFAC Adjusted MM to Straight & Checked Bit, Bit Ck'd Ok, LD MM & PU New 8" MM with Longer Bit to Bend, MU RR Bit & Set MM to 1.83 Bend, MU New MWD Tool, Orient Tool & Surface Test MWD 14:30 - 16:00 1.50 DRILL TRIP SURFAC TIH, Took MWD Check Shots @ 1,573',1,671' & 1,701', Ck'd Ok, Sperry Sun Surface Tested MWD that was POOH & Tool Ck'd Ok on Surface, Sent Tool In 16:00 - 00:00 8.00 DRILL DRLG SURFAC Drill, Slide & Survey F/1 ,701' to 2,338' MDI 2,113' TVD (637'), ART 3 1/2 Hrs, AST 2 3/4 Hrs, 500 Gpm, Off Btm Press 1,650 Psi, On Btm 1,725 Psi, Off Btm Torque 4.5K Ft#'s, On Btm 6.5K Ft#'s, 30-35K WOB, 60 Rpm's, Rot Wt 90K, PU WT 93K, Dn Wt 83K, Ave BGG 15 Units 2/15/2003 00:00 - 08:00 8.00 DRILL DRLG SURFAC Drill, Slide & Survey F/2,338' to 3,060' MDI 2,573'; TVD, 9 5/8" Csg Pt, (722'), ART 5 1/4 Hrs, AST 1/2 Hr, 600 Gpm's, Off Btm Press 2,250 Psi, On Btm 2,450 Psi, 35K WOB, 80 Rpm's, Off Btm Torque 4K Ft#'s, On Btm 6K Ft#'s, Rot Wt 95K, PU Wt 105K, Dn WT 95K, Ave BGG 15 Units 08:00 - 10:00 2.00 DRILL CIRC SURFAC Pumped 35 bbl Hi Vis Sweep, Had 3X the Amount of Cuttings Back Over Shaker, Pumped 2nd Sweep & had very Little back, Circ Hole Clean, Circ Total of 4 Btms Up, Circ @ 600 Gpm @ 2,200 Psi at 90 Rpm's 10:00 - 13:30 3.50 DRILL TRIP SURFAC Monitored Well-Static, Started POOH, Pulled 15K Over @ 1,671', Pumped Out F/1 ,671' to 1,575', Went Back Thru Spot & Ck Ok, Cont to POOH to BHA, Monitored Well- Static Printed: 3/10/2003 1 :38:28 PM ) ) .. "". ... . ...... . ..:....... ...: . ,.. . .." ..... .... . . ... .., '." . ". . '. ... . ". . "... ...",..........." ...... '..... '.. .... ... "... . " . ....... ". .. ...... ..... . . '" ....... . .... . .. .. ...... ....... . ... ... .. . . .. _. . . .. . .. .' .... .. .. .".. .. . '." . .. .. . "..: : . .. . .. ... '"' . ..... . .. ..... ,. . . . '.. .... _. '. . . .. .. .. . . . . . .' . .' . ..... ........ .... .. .. ... .. ............. .. .......... i·~.i'¡'bøn~c~~~iII¡~~ml~$~~ .... ..... .... .,. ··G),p~r~tlØl'1s'$Lll11mªrYRèport 2.50 DRILL TRIP SURFAC POOH, Adjust MM & LD BHA, Cleared Rig Floor 1.50 CASE RURD SURFAC RU GBR Csg Equip & Franks Fill Up Tool, Held PJSM with Rig & Csg Crew 5.75 CASE RUNC SURFAC MU 95/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 73 Jts of 9 5/8" Csg, (Total of 75 Jts Ran 3,017.32') TIH, Tagged Up at 1,685', Washed Down F/1,685' to 1,715', Cont RIH with No Problems, Landed Csg in Head - Landed Csg wI FS @ 3,049', FC @ 2,961'. Ran 14 Bow Spring Centralizers Per Well Program Est Circ at 126 Gpm 425 Psi Thru Fill Up Tool, Circ Btms Up While Reciprocating Csg, Increased Rate to 193 Gpm 400 Psi, Prep to MU Cmt Head Up Wt 125K, On Wt11 OK RD Franks Fill Up Tool & MU Cement Head Cont to Circ & Cond Mud for Cmtg, Lower Vis from 144 to 55, YP from 60 to 19, Final Circ Rate 8 Bpm @ 440 Psi, Last 55 bbls pumped Nutplug Sweep for Marker, Reciprocated Pipe, Up Wt 130K, On wt 115K Held PJSM with Vac Truck Drivers, Dowell & Rig Crew 2.00 CEMENT PUMP SURFAC RU Dowell, Pumped 10 bbls CW 100 Chem Wash, Tested Lines to 3,000 Psi, Pumped 40 bbls CW 100 Chern Wash at 8.3 ppg @ 7 Bpm @ 250 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 7.0 bpm @ 280 Psi with Red Dye in Spacer, Mixed & Pumped 412 bbls, 543 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 250 Psi, , Observe Nut Plug at Shaker and Started seeing a trace of Red Dye Back. Switched to Tail Cmt, Pumped 275 sxs (104 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield, Pumped @ 7.0 Bpm @ 500 Psi, 0.50 CEMENT DISP SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 204.6 bbls of 9.4 ppg mud, Ave Disp Rate 7.5 bpm @ 760 Psi, Reciprocated Pipe Until CW 100 was Going Out of Shoe-Landed Pipe, Slowed to 3 bpm @ 460 Psi, Bumped Plug to 1,200 Psi, Displ Calc 95% Eft on Rig Pumps, Had 180 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 05:30 Hrs 2/16/03 RD Cement Head, LD Landing Jt, RD Csg Equipment, Flushed Out Divertor & Flowline, Cleaned Rig Floor NO 21 1/4" Divertor & Removed 16" Divertor Line Install FMC 11" 5M Gen V Casing Head and Tubing Spool, Tested M/M seal to 1 000 psi. NU 13 5/8" 5M BOP Stack, Changed Out Adapter to Flowline RU & Tested BOP Stack, Manifold & Valves, Tested to 250 Psi Low & 5,000 Psi High, Tested Annular to 250 & 3,500 Psi, Tested Variable Rams with 7" Test Jt, Good Test, NOTE: John Crisp with AOGCC Waived Witnessing of BOP Test, RD Test Equipment 2.00 WELCTL OTHR SURFAC Attempted to Pull Test Plug, Flushed Out Stack with Mud to Remove Debris, Still Would Not Come Loose, Inspected Hanger Thru 2" Outlet on Tbg Spool & Found Copper Wire Wedged in Hanger 0.50 WELCTL NUND SURFAC LD 7" test Jt & Began NO Stack Above Tbg Spool 2.00 WELCTL NUND SURFAC Flushed Out BOP Stack & NO Stack, Inspected Tbg Spool & Found Scarring in Seal Area Where Test Plug had Drug Debris While Attempting to POOH, Found Large Pieces of Aluminum from previous We1l3s-16 on Top of Test Plug 2.50 WELCTL NUND SURFAC Removed Tbg Spool & Test Plug, Inspected Csg Head and Found Scarring on The Seal area also, Recovered a Vis Cup of Large Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-22 3S-22 ROT - DRILLING : Hdur$ <¢bdê . îóU:e Phasø 2/15/2003 13:30 - 16:00 16:00 - 17:30 17:30 - 23:15 23: 15 - 00:00 0.75 CASE CIRC SURFAC 2/16/2003 00:00 - 00:45 0.75 CASE RURD SURFAC 00:45 - 03:00 2.25 CEMENTCIRC SURFAC 03:00 - 05:00 05:00 - 05:30 05:30 - 07:30 2.00 CEMENT RURD SURFAC 07:30 - 10:30 3.00 WELCTL NUND SURFAC 10:30 - 11 :00 0.50 WELCTL NUND SURFAC 11 :00 - 16:00 5.00 WELCTL NUND SURFAC 16:00 - 21 :30 5.50 WELCTL BOPE SURFAC 21 :30 - 23:30 2/17/2003 23:30 - 00:00 00:00 - 02:00 02:00 - 04:30 Start: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 Group: . . .. . . .. ... . ......... '" .. . . .... . . . . . . .. . . ..... ,..... .... .. .. . ..·..·p~~Gripti9h~tþþ~râtiC>ris Printed: 3/10/2003 1 :38:28 PM ) ) .. .. .... . ." .. "' ... . .. ... .. .. .. ....... .... . ... . . . .." . ... . . ... ,". . . ..... .... ""0. "n. .... . '" ".. .. . ... .. . . . ... .. . . . . . . . . . .. . . . . .. "' . .... . . .. '. "' ... . . . .. . .. . ". .... .... .... ":": .... ...... .. .. . .. . ...... ......:.... ." ..:.....";. :.... .... ,:., '". .. .. :,:":.: :.". :' ::. .... ....... ..... :.: .. ... . ... . . . ... . . ... . . .. . ... ." .." '" ... . .. . ..... ......... ... ... ..·¢~hbçQPrill'~~j~~f~f~'i ... i fi}pJer¡¡ti.o~s.SUtnma~y.Rèpprt: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-22 3S-22 ROT - DRILLING Start: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 Group: .. . . ... ....... ". "." ....".. S"b . PéltØ .j=rQm:~·"åH()4îrs¡··.·,¢öciè ..éOUdè..·· Pha~~..·· . .. . .... .. .... . . "' : "." ...... '.": . .> '.0. e.·.·s¢riptipn.öf¡þp~H~tiqd~:i ...... , '. .,...... ...... ..... ........... .... 2/17/2003 02:00 - 04:30 2.50 WELCTL NUND SURFAC Aluminum 04:30 - 06:30 2.00 WELCTL NUND SURFAC NU New 11" 5M Gen V Csg Head & Tbg Spool, Set Stack on Head & Tested M/M Seals to 1,000 psi, Tested Ok, Fin NU Bop Stack 06:30 - 08:00 1.50 WELCTL BOPE SURFAC RU & Tested Flanges Between Csg Head, Tbg Spool & BOP's to 250 Psi, Low & 5,000 Psi & Had Good Test, Pulled Test Plug, RD Test Equip & Installed Wear Bushing 08:00 - 09:00 1.00 RIGMNT RSRV SURFAC Serviced Rig & Top Drive 09:00 - 11 :00 2.00 DRILL PULD SURFAC PU 33 Jts of 5" DP from Pipe Shed & Stood Back 11 :00 - 15:00 4.00 DRILL PULD SURFAC PU & MU BHA #7, 8 1/2" Bit with Directional Assembly, Orient BHA, Uploaded MWD, Held PJSM with Sperry Sun & Loaded Radioactive Source 15:00 - 17:30 2.50 DRILL TRIP SURFAC TIH with BHA #7 PU 5" DP from Pipe Shed, Tagged Cement at 2,943' (Fit Collar @ 2,961') 17:30 -18:00 0.50 DRILL CIRC SURFAC Circ Btms Up for Csg Test, 9.0 ppg MW In & Out 18:00 - 19:00 1.00 CASE DEOT SURFAC RU & Tested 95/8" Csg to 2,500 Psi for 30 Min, Good Test 19:00 - 20:45 1.75 DRILL DRLG SURFAC Drilled Fit Collar @ 2,961', Shoe Trac, Soft-Med Cmt, Fit Shoe @ 3,049' and 20' of New Formation to 3,080' MD/ 2,584' TVD, 4-8K WOB, 40 Rpm's, 450 Gpm 1,300 Psi 20:45 - 21 :30 0.75 DRILL CIRC SURFAC Circ Btms Up & Displaced Hole with New 9.0 ppg LSND Mud 21 :30 - 22:30 1.00 DRILL LOT SURFAC RU & Performed LOT with 9.0 ppg Mud at 3,049' MD/2,564'TVD Leaked Off At 944 Psi for a 16.1 ppg EMW 22:30 - 23:00 0.50 DRILL CIRC SURFAC Circ Est Clean Hole Rate and SPR's, Clean Hole = 9.4 ppg 23:00 - 00:00 1.00 DRILL DRLG INTRM1 Drill 8 1/2" Hole F/3,080' to 3,207' MD/2,666' TVD, ART 3/4 Hr, 15K WOB, 50 Rpm's, 514 Gpm 2,250 Psi, Off Btm Torque 6K Ft#'s, On Btm 6.5K Ft#'s, Rot Wt 100K, PU 115K, On Wt 83K, ECD 10.04 ppg 2/18/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilling f/3207-4541. ART 6.75 hr, AST 0.5 hr. 4200-4541 ECD's ranging from 11.4 - 12.4 ppg. UP WT 145k, ON WT 100k, ROT WT 11 Ok, TO ON/OFF 7k/6k, jar hrs 39.5, SPR 40@140, 50@160. Pump hi vis weighted sweeps every three stands. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilling f/4541-5778. ART 8.5 hr, AST 0.25 hr. UP WT 160k, ON WT 98k, ROT 120k, TQ ON BTM 9000, TO OFF BTM 8500. SPR #1 pump 40 SPM/21 0 psi, 50 SPM/240 psi, SPR #2 pump 40 SPM/21 0 psi, 50 SPM/230 psi. 2100 gas units @ 5493' C-40. Pump hi vis weighted sweeps every three stands. 2/19/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilling f/5778' to 7050' ART 5.0 hr, AST 2.2 hr. UP WT 200k, ON WT 120k, ROT 130k, TO ON/OFF 11 k/1 Ok. SPR 200 psi @ 40 spm, 300 psi @ 50 spm. Jars 54.5 hrs. Increase wt from 10.0 ppg - 10.6 ppg. ECD's 11.8-13.1 ppg. Pump sweeps every 3 stands. Background gas 20-60 units. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill f/7050' to 8090' ART 7.3 hr, AST 0.68 hr. UP WT 220k, DN WT 115k, ROT 153k, TO ON/OFF 13k/12k. SPR 360 psi @ 40 spm, 440 psi @ 50 spm. Jars 54.5 hrs. Increase wt from 10.6 ppg - 11.3 ppg. ECD's 12.1-13.3 ppg. Pump sweeps every 3 stands. Background gas 60-350 units. Had 1150 units at 7202' with 10.8 ppg mud. 450 units at 7649' with 11.3 ppg mud. 2020 units at 7720' with 11.3 ppg, no mud cut., Connection gases 250 to 400 units 2/20/2003 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Drill f/8090' to 8110' ART 0.5. UP WT 225k, ON WT 130k, ROT 150k, TO ON/OFF 13k/12k. Jars 63 hrs. SPR 40/50 spm 260/360 psi. ECD's 12.1-13.3 ppg. 00:30 - 06:00 5.50 DRILL CIRC INTRM1 Pump sweep 4 BU, Monitor well CBU. Background gas 350 units, up to 2550 on BU. Increase MW 11.3-11.5ppg. Background gas dropped to 150 units. Printed: 3/10/2003 1 :38:28 PM ) ) . --.' .:...:". .'. .." "":'.'.. '. . .. . ," .'.. ....." ," ..... ..... ....... . . . .... ". .. ... ... . . ....,.. .' ... ... ...... .. .... .... .... . . . . ... . . .. ...... . . . '. . . . ... . . . , .. . 0"" .. ... . ... . . ...... . . .. ..... ",", :..:.,: 'on ...."...".:. ..". ....,: ,".. .... ... .. .' ", ... .. .. . .. . , .. . .. . '.. . ... .... . '" ... . . ..r.·...·. . ",. . .... ".,:, .:.."' ._ . ....:.. ,." ":.:: .... .. ." ",.:: :'. .... ........ ..... . .. >......... ..."..:.:. '.""... . ._.. . .... .", "' ... ... . . .... ..... . . . . . .... ..... ...!.··....······....·1Ar~~w?iÎlip~~I~~~~..,i.. . , .. ····ØP~fªti Ql1s'surn~ª~yR~p()rt· . . ... ..... ... ......", ",. ......... .... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-22 38-22 ROT - DRILLING Start: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 Group: ,.",':' :' ....'.'.".... .':.: . ..":, ." . ·Öatê· · i ·;FrQm-To ·t--!()Ut$,: ëj6âß. . ... .. . . ..... . 0"".. '. ,".. ..."........ ... ..... :.' .·.:.:þ~$cripti()rlqfdper~tipl1$>..:) ..... ... ... . .... .' ... ......... . ".. . 2/20/2003 06:00 - 08:00 2.00 DRILL WIPR INTRM1 08:00 - 08:30 0.50 DRILL WIPR INTRM1 08:30 - 10:30 2.00 DRILL CIRC INTRM1 10:30 - 14:30 4.00 DRILL WIPR INTRM1 14:30 - 15:30 1.00 RIGMNT RSRV INTRM1 15:30 - 16:30 1.00 RIGMNT RSRV INTRM1 16:30 - 19:30 3.00 DRILL WIPR INTRM1 19:30 - 23:00 3.50 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL DRLG INTRM1 00:00 - 00:30 0.50 DRILL DRLG PROD 00:30 - 01 :00 0.50 DRILL CIRC PROD 01 :00 - 07:30 6.50 DRILL DRLG PROD 2/21/2003 07:30 - 10:00 2.50 DRILL CIRC PROD 10:00 - 12:30 2.50 DRILL WIPR PROD 12:30 - 14:30 2.00 DRILL CIRC PROD 14:30 - 15:00 0.50 DRILL CIRC PROD 15:00 - 21 :30 6.50 DRILL TRIP PROD 21 :30 - 00:00 2.50 DRILL PULD PROD 2/22/2003 00:00 - 01 :30 1.50 DRILL PULD PROD 01 :30 - 02:00 0.50 CASE RURD PROD 02:00 - 03:30 1.50 CASE RURD PROD 03:30 - 11 :00 7.50 CASE RUNC PROD 11 :00 - 11 :30 0.50 CASE CIRC PROD 11 :30 - 13:30 2.00 CASE RUNC PROD 13:30 - 14:00 14:00 - 00:00 0.50 CASE RURD PROD 10.00 CASE RUNC PROD 2/23/2003 0.50 CASE CIRC PROD 2.50 CASE RUNC PROD 00:00 - 00:30 00:30 - 03:00 03:00 - 04:30 1.50 CASE CIRC PROD POH f/8110', pumped out f/7392' to 7297', cont POH to 7011' RIH to 8110' no problems, No fill CBU pump sweep, circ hole clean, background gas started @ 150, maxed out @ 5350 units mud cut 1.0 ppg, gas returned to 150 units POH to shoe, no problems. Service rig and top drive. Service and inspect crown sheaves (dust covers loose). TIH to 8110', no fill, no problems. CBU max gas 1380 units mud cut .4 ppg, pump sweep, lower MW fl 11.5 to 11.3 ppg. Drill f/811 0' to 8135' ART 1.0 hr. Drill f/8135' to 8155' ART .50 hrs, ECD's 12.1 ppg, BGG 851 100 units, 400 gpm @ 2070 psi, had trouble detecting wi MWD & had to increase gpm to 420 Circ. btm's up, Max gas 760 units, BBG 851 100 units Drill fl 8155' to 8423' ART 5.8 hrs, ECD's 12.1 ppg, BGG 85/100 units, 431 gpm @ 2100 psi, Connection gas 100 to 150 units, Mud wt. 11.3 ppg, ECD's 12.1 ppg, UP 245, DN 130, ROT 155, TQ 15/14 Circ btm's up, Pump hi-vis unweighted sweep, Circ hole clean wi total of 4 btm's up. Shakers look very clean, No mud loss. Wipe hole to 7011', Hole in very good shape, Good fill up. Circ btm's up, Pump hi-vis unweighted sweep, Circ hole clean wI total of 4 btm's up. Shakers look very clean, No mud loss, Trip gas 270 units Monitor well-OK, Spot 50 bbls Steel seal pill on btm. POOH 10 stands, Pump dry job, POOH to BHA, Had 1 pull @ 6700' of 50K over, wiped thru- OK, Monitor well at BHA, SLM -No correction Lay down Flex collars & Stab, PJSM- Remove A.A. Sourse, Down load MWD Finish laying down BHA, Clean rig floor Pull wear bushing Change out bails for running casing, Rig to run 7" casing. PJSM, Run 7", 26#, L-80, BTCM casing, Install centralizers 1 per jt. on 1 thru 6, 2 per jt on 7 thru 16, 1 per jt on 17 thru 28, Had to push first 40 joints casing in hole due to extra centralizers, Circ. 50 bbls mud @ 1239' due to inadequate displacement, Running speed 30/40 fVmin. Circ. btm's up @ 3013' 9-5/8" casing shoe, 4 bpm @ 335 psi -No mud loss while circulating. Run 7" casing, Break circ. wi 50 bbls every 10 jts., Circ. btm's up every 20 jts. due to inadequate casing displacement- 5 jts.calc. displace 1.9 bbls, actual 1.0 bbls, Circ. at rate of 4 bpm @ 350 psi - No mud loss while circulating, Running speed 20/30 fVmin. Work pipe & change out franks fill up tool rubber @ 3988'. Run 7" casing, Break circ. wI 50 bbls every 10 jts., Circ. btm's up every 20 jts. due to inadequate casing displacement- 5 jts.calc. displace 1.9 bbls, actual 1.0 bbls, Began getting proper displacement @ 5286', Circ. at rate of 4.5 bpm @ 575 psi - No mud loss while circulating, Running speed 20/30 fVmin. Circ. btm's up at rate of 4.5 bpm @ 620 psi, No mud lost Run 7" casing f/7717' to 8412', running speed of 20/30 fVmin., good displacement until last 5 jts.- got back .6 of 1.9 bbl. Pipe very free Up & Down. Shoe @ 8412', Float collar @ 8243' Work pipe & circulate btm's up at rate of 4.5 bpm @ 650 psi, Trip gas Printed: 3/10/2003 1 :38:28 PM ) ) . . . '. . . . ... ... . . ... .. ." . . . , ." ..". ..' ....." .. '. . .... . .. .. ..... .. ..",.. '" '" .... "' . .... .., ..' ..... . . . . '." .. .....".. . . .... ..... ." ...... . . ... . .... . . '. ....... .... .... . . . .... .... . .. ..,. . . "' .. . . .... . .. .. ... .. . . . ...... ............ .......... ." .. .... .. ." ..... 0"" . ." .... ."....... ... . . ..' ... .. ... .. .. ... ..... .. .. . .. . .... .. .... . . "' .. . . ... .. .. .. .... . ",. . .", . .......", . ...... ... . . ... . . .. ",. .."..... '" .. ,".... '.' . ..' . .'.. ...;··.\·.i;·.·.9Ø~?d()Phill¡p#)~I~Skfl····.·.J·...·..... . . ·>·,0.. ..... .þ..·~·r~ti()t1~,.··.SLlmmary,FtE)pqrt.· . .'. ..,. . . . . .... . ... .. . .... .......... .' ... .. . '. .. . . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-22 3S-22 ROT - DRILLING F . T H·..···.o····u·..·.r··s··· .iC··..',o·.·.d.',·.··...e·,·..· '-Sub Ph ·rqrh-ö .·'Cddè i¡ ...···àse . 2/23/2003 1.50 CASE CIRC PROD 03:00 - 04:30 04:30 - 05:00 05:00 - 08:30 0.50 CEMENT PULD PROD 3.50 CEMENTCIRC PROD 08:30 - 10:00 1.50 CEMENT PUMP PROD 10:00 - 12:00 2.00 CEMENT PULD PROD 12:00 - 13:30 1.50 CMPLTN NUND PROD 13:30 - 14:30 1.00 CMPL TN RUNT PROD 14:30 - 22:00 7.50 CMPL TN RUNT PROD 22:00 - 23:00 1.00 CEMENT FIT PROD 23:00 - 00:00 1.00 CMPL TN RUNT PROD 2/24/2003 00:00 - 01 :00 1.00 CMPL TN RUNT PROD 01 :00 - 01 :30 0.50 CMPL TN DEQT PROD 01 :30 - 03:30 2.00 CMPL TN PCKR PROD 03:30 - 04:00 0.50 CMPL TN SOHO PROD 04:00 - 05:30 1.50 CMPL TN DEQT PROD 05:30 - 06:00 06:00 - 09:00 09:00 - 10:30 10:30 - 13:00 0.50 CMPL TN PULD PROD 3.00 CMPL TN NUND PROD 1.50 CMPL TN NUND PROD 2.50 CMPL TN FRZP PROD Start: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 Group: ,". ... .... . . ... ..' . ........ .:.,""' .." .. ". ." . ". "" :.. '. ... . ....:..... ... ... ... ··.·.·.¡Pß$Þripti¿,ndf.öPßrå(icir1s .. . ... . "." ." ... ,... ".. ...... ...... '" ... ..... '" . . . .... . 140 units, Pipe became stuck at btm's up- drag increased from 220K up to 350K, Land pipe in hanger. No mud lost while eirc. Rig down fill up tool & rig up Dowell cmt. head. Circ & Cond mud for cmt. lower YP f/24 to 16, Balance mud wt. out at 11.3 ppg Rig Dowell, Batch mix 25 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 12.0 ppg, 250 sxs (52 bbls) cmt. mixed at 15.8 ppg GasBLOK wI Class G + .030%BWOC B155, .300%BWOC D65, 2.000 gallsk D600G, 2.00 gallsk D47, Pump 5 bbls CW100, Test lines to 3500 psi, Pump 20 bbls CW100, Drop plug #1, Reload head, Pump 50 bbls MudPUSH at rate of 6.0 bpm at 735 psi, Drop plug #2, Pump 52 bbls cmt at rate of 6.0 bpm at 800 to 550 psi, Shut down, Flush lines to rig floor wI seawater, Drop top plug, Dowell displaced first 296 bbls seawater at rate of 6.5 bpm at 930 to 1360 psi until 26 bbls cmt around shoe then slowed rate to 3.0 bpm @ 1130 to 1350 psi & bumped plug wI total of 319.0 bbls seawater, Bumped plug wI 2000 psi, Bled back 2.0 bbls for total of 317.0 bbls displaced, CIP @ 1000 hrs 2/23/03, Had good circ thru out job, Displaced entire job wI Dowell, Casing stuck prior to start of job. Rig down cmt. head & equip., Flush stack & lay down landing joint. Rig & run 7" GEN 5 Pack off, Test same to 250 low & 5000 psi high 10 min. -OK Rig up to run 3-1/2" completion string Pick up & run 3-1/2" 9.3#, L-80, EUE 8rd completion srting Perform injecttivity test on 7" x 9-5/8" annulus EMW of 17.2 ppg using 11.3 ppg mud, 780 psi @ 9-5/8" shoe 3049' MD 2564' TVD Pick up & run 3-1/2" 9.3#, L-80, EUE 8rd completion srting Run 3-1/2",9.3#, L-80, EUE 8rd Completion string to 7792' Rig & test 7" casing to 3500 psi fl 30 min. -OK Note; Flushed 7" x 9-5/8" annulus with 220 bbls fresh water at 2 bpm @ 800 psi, followed by 60 bbls diesel for freeze protection. Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 7760.53', Slowly pressure 3-1/2" tbg. to 2500 psi. Wait 5 min. Bleed pressure to zero. Slack off to 45K (20K on pkr) to comfirm packer set, then pressure tbg string to 3000 psi and hold 5 min. Bleed pressure to 1000 psi. PU to 125K (30K over) & shear PBR. Bleed pressure to zero. Slack off, tag locator wI 15K. Pressure tbg to 3700 psi to shear ball seat. Bleed off all pressure. Pull jt. #250 out of hole (pulling 12' out of PBR). M/U 3-1/2" FMC tubing hanger on jt. # 249, Use jt. #250 as landing jt., RIH & land tubing wI locator 2' above fully located in PBR, RILD8. Rig pumping lines Pressure 3-1/2" tubing to 3500 psi f/15 min. Bleed pressure to 1500 psi. Pressure 3-1/2" x 7" annulus to 3500 psi f/15 min (Pressure on tubing increase to 2000 psi). Bleed tbg pressure to zero. (RP sheared wI 1200 psi on tbg). Bleeding both sides to zero. All test were charted. Lay down landing joint, Install FMC BPV Blow down all surface lines, Nipple down BOP stack. Install & nipple up Gen 5 tree, Test same to 250/5000 psi. Rig up little red, Pump 120 bbls diesel down tbg. to GLM & for 2000' annular space in 3-1/2" x 7" annulus (350 psi on tbg.), Rig down little red. Install FMC lubricator & set BPV. Change out 16" riser to 20" for next well. Printed: 3/10/2003 1:38:28 PM ) ) ...... ......... ...... ". ':" ..:. : .". . ,:..... ":",. ,," ...". . .' .. ..... :". .. :'.... '.:" ..... . ....... . .. ... . . , .. . .... .. . . ... . . .. ..... ... .......,.... ...... o ...... . .. , . ..< .···<.8?~~C'()7hìlli~S~IßSk?, ....... ............ 9perati()l'1s,'~,umrn;~fY··,Fh~p()rt:. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-22 3S-22 ROT - DRILLING Start: 2/11/2003 Rig Release: Rig Number: Spud Date: 2/12/2003 End: 2/24/2003 Group: ..... .... . ... . Sub rtqrr1 "TQ'Hol] rš: CQdØ ..qdde I?håsø. . .. ..... ... . . .. .. ... ..'." ..... .:De§êt¡þ~idn()f(jpërªtlon$ . ..... ...... . ... .... ..... ........ ",.. . 2/24/2003 13:00 - 17:00 17:00 - 18:00 4.00 MOVE DMOB MOVE Lay down excess drill pipe from derrick for rig move using mouse hole. 1.00 MOVE DMOB MOVE Cut & slip drilling line. Release rig at 1800 hrs 2/ 24/03 Printed: 3/10/2003 1 :38:28 PM Date 02/27/03 02/28/03 03/06/03 03/10/03 03/25/03 ) ) 35-22 Event History Comment TAGGED @ 82091 RKB, EST. 55' RATHOLE BELOW EXPECTED BOTTOM PERF INTERVAL. DRIFTED W/ 22' X 2.625" DUMMY GUN TO 8209' RKB. ATTEMPT PULL DCR. IN PROGRESS. [TAG, PERF] CONFIRMED RP VALVE DROPPED FROM 7659' RKB. CHASED TO RATHOLE @ 8209' RKB. SET DV @ 7659' RKB. TESTED IA & TBG TO 3000 PSI, GOOD. RAN SCMT / SBHP. CEMENT IS GOOD FROM 8190' TO 77921 (TBG TAIL). BHP AT 81391= 2188 PSI WHEN WHP= 0 PSI, TAGGED TD AT 8200'. PERFORATED 8139-8143 THEN MEAS SBHP AT 8141'= 2787 PSIA AND STILL INCREASING AFTER 1HR 38MN, PERFORATED 8124-8139 AND 8143-8154, MEAS FINAL SBHP AT 8139'= 2897.5 PSIA, TEMP= 162.2 DEGF AND FINAL SBHP AT 7139'= 2837.5 PSIA, TEMP= 155.2 DEGF. MITIA (STATE WITNESSED) PASSED. [WH MAINTENANCE] Page 1 of 1 4/1/2003 ) ) é108,-o II 16-Apr-03 AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-22 Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0,00' MD 0.00' MD 8,423.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager , If'''" f,""<)~ r' i \ I t.~ \I ,. "'~, [:;) ¡'PI'"'' :'\ ¡""'" ~ I', ~ t ' . ~ ,6/ ~ .~ i.".-:<. \.,..}Ii ct,...."" 0 .. L:~";-~' Attachment(s) APC) I') '") n'nr-;l T\ (_ C ,;:...., t,;') i=\\a'5ha IOfi &. Gas ();:ms. C:'Q¡YIf:1~'1 M':ho"~~ Sperry-Sun Drilling Services Western North Slope ConocoPh illips 35-22 ---' Job No. AKZZ2280031, Surveyed: 21 February, 2003 Survey Report 1 April, 2003 Your Ref: API 501032044600 Surface Coordinates: 5993860.59 N, 476032.71 E (70023' 39.6794" N, 150011' 42.0163" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ,-". Kelly Bushing: 57. 10ft above Mean Sea Level =I-'Eai .. ·Y-~I .., Ei"RlLL.:Xî\n:;--· !Sire:: A·VTc:-e-s A Halliburton Company Survey Ref: svy1999 Sperry-Sun Drilling Services Survey Repol1 for 35-22 Your Ref: API 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPhillips Western Nol1h 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) CO/100ft) 0.00 0.000 0.000 -57.10 0.00 0.00 N 0.00 E 5993860.59 N 476032.71 E 0.00 Tolerable Gyro 83.00 0.500 30.000 25.90 83.00 0.31 N 0.18 E 5993860.90 N 476032.89 E 0.602 -0.22 AK-6 BP _IFR-AK 197.65 0.460 61.480 140.55 197.65 0.97N 0.84 E 5993861.55 N 476033.55 E 0.230 -0.95 288.85 0.650 30.450 231.74 288.84 1.59 N 1.42 E 5993862.17 N 476034.13 E 0.382 -1.61 .-...-' 380.97 0.320 74.650 323.86 380.96 2.11 N 1.93 E 5993862.69 N 476034.65 E 0.517 -2.19 471.25 0.060 22.180 414.14 471.24 2.22 N 2.19 E 5993862.80 N 476034.91 E 0.318 -2.46 503.32 0.170 28.310 446.21 503.31 2.27N 2.22 E 5993862.86 N 476034.94 E 0.345 -2.50 533.89 0.090 28.310 476.78 533.88 2.33 N 2.26 E 5993862.92 N 476034.97 E 0.262 -2.54 564.03 0.540 20.600 506.92 564.02 2.49 N 2.32 E 5993863.07 N 476035.03 E 1.496 -2.62 593.52 0.830 316.140 536.40 593.50 2.77N 2.22 E 5993863.36 N 476034.94 E 2.613 -2.56 623.94 1.530 261.520 566.82 623.92 2.87N 1.66 E 5993863.46 N 476034.38 E 4.105 -2.02 653.18 2.590 246.710 596.04 653.14 2.55 N 0.67 E 5993863.14 N 476033.39 E 4.027 -1.00 682.11 4.140 256.000 624.92 682.02 2.04N 0.94W 5993862.63 N 476031.77 E 5.662 0.67 712.35 5.060 256.900 655.06 712.16 1 .48 N 3.30W 5993862.08 N 476029.41 E 3.052 3.08 752.00 6.450 261.000 694.51 751.61 0.73 N 7.20W 5993861.34 N 476025.51 E 3.654 7.05 772.89 6.460 261.550 715.27 772.37 0.37 N 9.53W 5993861.00 N 476023.19 E 0.300 9.40 803.49 7.960 269.320 745.63 802.73 0.10 N 13.35 W 5993860.73 N 476019.36 E 5.836 13.22 833.38 8.600 274.730 775.21 832.31 0.26 N 17.64 W 5993860.90 N 476015.07 E 3.371 17.46 866.92 9.130 280.820 808.35 865.45 0.96 N 22.76 W 5993861.63 N 476009.96 E 3.211 22.44 898.96 8.900 275.680 839.99 897.09 1.69 N 27.72 W 5993862.36 N 476004.99 E 2.613 27.26 929.59 9.190 279.790 870.24 927.34 2.34N 32.49 W 5993863.03 N 476000.23 E 2.312 31.91 -- 962.08 9.530 280.830 902.30 959.40 3.28 N 37.69 W 5993863.99 N 475995.03 E 1.169 36.94 993.33 10.180 281.510 933.09 990.19 4.32 N 42.93 W 5993865.05 N 475989.79 E 2.113 42.00 1023.87 10.960 282.860 963.11 1020.21 5.50 N 48.41 W 5993866.25 N 475984.32 E 2.679 47.28 1056.32 11.800 282.230 994.92 1052.02 6.89 N 54.66 W 5993867.66 N 475978.07 E 2.617 53.29 1089.40 12.340 279.400 1027.27 1084.37 8.19 N 61 .45 W 5993868.97 N 475971.28 E 2.421 59.86 1120.59 12.460 277.390 1057.73 1114.83 9.16 N 68.08 W 5993869.97 N 475964.66 E 1.436 66.30 1153.62 13.510 276.530 1089.92 1147.02 10.06 N 75.44 W 5993870.89 N 475957.30 E 3.232 73.49 1186.06 14.420 276.710 1121 .40 1178.50 10.96 N 83.22 W 5993871.82 N 475949.52 E 2.808 81.08 1216.26 14.900 272.710 1150.61 1207.71 11.59 N 90.83 W 5993872.47 N 475941.91 E 3.709 88.54 1 April, 2003 - 13: 13 Page 2 of7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 3S-22 Your Ref: AP/501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 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) e/100ft) 1248.61 15.930 275.210 1181.80 1238.90 12.19 N 99.41 W 5993873.10 N 475933.34 E 3.788 96.97 1280.26 17.140 273.190 1212.14 1269.24 12.84 N 108.39 W 5993873.78 N 475924.36 E 4.232 105.79 1310.59 18.250 270.890 1241.04 1298.14 13.16 N 117.60 W 5993874.13 N 475915.15 E 4.324 114.88 1343.63 19.440 267.970 1272.30 1329.40 13.05 N 128.27 W 5993874.05 N 475904.48 E 4.595 125.47 .~ 1374.92 19.970 266.400 1301.76 1358.86 12.53 N 138.81 W 5993873.56 N 475893.94 E 2.394 135.99 1404.26 20.900 265.540 1329.26 1386.36 11.81 N 149.03 W 5993872.88 N 475883.72 E 3.331 146.21 1438.34 22.500 265.460 1360.92 1418.02 10.82 N 161.59 W 5993871 .93 N 475871.16 E 4.696 158.79 1470.48 22.620 264.840 1390.60 1447.70 9.78 N 173.87 W 5993870.92 N 475858.87 E 0.829 171.11 1501.68 23.320 260.950 1419.33 1476.43 8.26N 185.95 W 5993869.45 N 475846.79 E 5.357 183.28 1595.88 26.330 265.540 1504.82 1561.92 3.71 N 225.20 W 5993865.02 N 475807.52 E 3.792 222.79 1626.61 26.510 265.990 1532.34 1589.44 2.70N 238.84 W 5993864.05 N 475793.88 E 0.876 236.44 1660.33 26.320 265.670 1562.54 1619.64 1.61 N 253.80 W 5993863.01 N 475778.92 E 0.704 251.42 1690.30 27.11 0 267.540 1589.31 1646.41 0.81 N 267.25 W 5993862.26 N 475765.47 E 3.849 264.86 1723.76 28.490 269.430 1618.91 1676.01 0.40 N 282.85 W 5993861.90 N 475749.87 E 4.893 280.37 1756.22 30.700 269.340 1647.13 1704.23 0.23 N 298.87 W 5993861.78 N 475733.84 E 6.810 296.29 1787.59 32.740 269.710 1673.82 1730.92 0.10 N 315.37 W 5993861.70 N 475717.35 E 6.533 312.66 1821.21 35.560 267.960 1701.64 1758.74 0.308 334.23 W 5993861.36 N 475698.48 E 8.881 331.41 1852.58 38.630 267.800 1726.66 1783.76 1.008 353.14 W 5993860.72 N 475679.57 E 9.791 350.25 1883.67 41.690 268.780 1750.41 1807.51 1.598 373.18 W 5993860.20 N 475659.53 E 10.050 370.19 1916.04 43.410 268.030 1774.26 1831.36 2.208 395.06 W 5993859.65 N 475637.65 E 5.540 391.96 1947.50 43.630 268.430 1797.07 1854.17 2.878 416.71 W 5993859.05 N 475615.99 E 1.121 413.52 .----- 1978.18 44.120 268.720 1819.19 1876.29 3.40 8 437.97 W 5993858.59 N 475594.74 E 1.726 434.66 2011.21 45.160 269.680 1842.69 1899.79 3.728 461.17 W 5993858.35 N 475571.53 E 3.753 457.71 2042.75 46.290 268.380 1864.71 1921.81 4.11 8 483.75 W 5993858.03 N 475548.95 E 4.642 480.15 2073.71 47.200 267.920 1885.92 1943.02 4.848 506.29 W 5993857.38 N 475526.41 E 3.132 502.59 2106.45 47.640 267.180 1908.08 1965.18 5.878 530.37 W 5993856.42 N 475502.32 E 2.139 526.60 2137.65 48.330 265.870 1928.96 1986.06 7.278 553.51 W 5993855.09 N 475479.18 E 3.824 549.72 2169.40 48.380 263.910 1950.06 2007.16 9.398 577.14 W 5993853.05 N 475455.55 E 4.616 573.43 2201.69 49.210 262.140 1971.33 2028.43 12.348 601.25 W 5993850.18 N 475431.42 E 4.859 597.72 2233.16 50.090 261.440 1991.71 2048.81 15.768 624.99 W 5993846.83 N 475407.68 E 3.270 621.70 1 April, 2003 - 13:13 Page 3 of7 Dril/Quest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 35-22 Your Ref: API 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 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) CO/100ft) 2263.22 50.170 261.540 2010.98 2068.08 19.18 8 647.80 W 5993843.49 N 475384.85 E 0.369 644.76 2358.98 50.710 260.070 2071.97 2129.07 30.98 S 720.68 W 5993831.92 N 475311.94 E 1.311 718.55 2454.88 50.960 259.360 2132.53 2189.63 44.25 8 793.84 W 5993818.88 N 475238.74 E 0.630 792.82 2549.50 51.310 259.490 2191.91 2249.01 57.78 S 866.26 W 5993805.59 N 475166.27 E 0.385 866.39 >~ 2645.53 50.560 261.770 2252.43 2309.53 69.92 8 939.81 W 5993793.68 N 475092.68 E 2.002 940.90 2740.63 50.550 260.060 2312.85 2369.95 81.52 8 1012.33 W 5993782.32 N 475020.13 E 1.389 1014.31 2837.13 51.400 258.040 2373.62 2430.72 95.76 8 1085.92 W 5993768.31 N 474946.49 E 1.849 1089.13 2931.72 50.350 258.610 2433.30 2490.40 110.61 8 1157.78 W 5993753.69 N 474874.58 E 1.204 1162.31 2986.54 50.540 261.970 2468.22 2525.32 117.748 1199.43 W 5993746.70 N 474832.91 E 4.738 1204.54 3047.51 51 .000 262.280 2506.78 2563.88 124.21 8 1246.21 W 5993740.38 N 474786.10 E 0.851 1251.77 3143.09 49.940 262.560 2567.61 2624.71 133.94 8 1319.29 W 5993730.88 N 474713.00 E 1.132 1325.48 3237.65 49.410 262.370 2628.81 2685.91 143.39 8 1390.76 W 5993721.66 N 474641.50 E 0.581 1397.57 3333.96 48.360 261.870 2692.14 2749.24 153.338 1462.63 W 5993711.95 N 474569.60 E 1.158 1470.13 3429.00 47.810 261.440 2755.63 2812.73 163.60 8 1532.60 W 5993701.91 N 474499.59 E 0.670 1540.85 3524.12 47.060 260.780 2819.97 2877.07 174.42 S 1601.82 W 5993691.31 N 474430.34 E 0.940 1610.88 3619.28 48.470 262.400 2883.93 2941.03 184.71 8 1671.51 W 5993681.24 N 474360.61 E 1.945 1681.32 3715.43 48.250 262.800 2947.82 3004.92 193.97 8 1742.77 W 5993672.21 N 474289.33 E 0.386 1753.18 3810.05 50.830 263.920 3009.21 3066.31 202.28 8 1814.27 W 5993664.13 N 474217.80 E 2.872 1825.15 3905.42 50.460 264.580 3069.69 3126.79 209.67 8 1887.64 W 5993656.98 N 474144.40 E 0.661 1898.86 4001.85 49.750 264.080 3131.54 3188.64 216.98 8 1961.26 W 5993649.90 N 474070.76 E 0.837 1972.81 4095.82 51.160 263.680 3191.37 3248.47 224.70 8 2033.31 W 5993642.41 N 473998.69 E 1.536 2045.24 ---- 4190.97 50.610 263.700 3251.40 3308.50 232.82 8 2106.69 W 5993634.53 N 473925.29 E 0.578 2119.05 4286.68 50.490 263.140 3312.21 3369.31 241.29 8 2180.11 W 5993626.30 N 473851.84 E 0.469 2192.95 4381.73 50.160 263.450 3372.89 3429.99 249.838 2252.76 W 5993617.99 N 473779.16 E 0.428 2266.10 4475.82 49.660 262.700 3433.49 3490.59 258.50 8 2324.22 W 5993609.54 N 473707.67 E 0.809 2338.08 4572.24 49.430 262.960 3496.05 3553.15 267.66 8 2397.01 W 5993600.61 N 473634.85 E 0.315 2411.44 4667.37 49.200 262.170 3558.06 3615.16 277.00 S 2468.54 W 5993591.51 N 473563.29 E 0.675 2483.58 4763.99 50.630 261.450 3620.28 3677.38 287.53 8 2541.71 W 5993581.21 N 473490.09 E 1.586 2557.49 4859.65 50.130 262.470 3681.28 3738.38 297.848 2614.67 W 5993571.14 N 473417.10 E 0.974 2631.17 4954.37 49.730 261.600 3742.26 3799.36 307.88 8 2686.45 W 5993561.32 N 473345.28 E 0.820 2703.66 1 April, 2003 - 13:13 Page 40i7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 3S-22 Your Ref: API 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 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) e/100ft) 5049.66 49.580 262.030 3803.95 3861.05 318.22 S 2758.34 W 5993551.21 N 473273.37 E 0.378 2776.28 5145.28 49.480 261.880 3866.01 3923.11 328.40 S 2830.37 W 5993541.26 N 473201.31 E 0.159 2849.02 5238.34 49.320 261.230 3926.57 3983.67 338.78 S 2900.26 W 5993531.11 N 473131.38 E 0.558 2919.66 5333.49 48.920 261.230 3988.84 4045.94 349.75 S 2971.36 W 5993520.37 N 473060.25 E 0.420 2991.59 '-" 5427.31 49.080 260.970 4050.39 4107.49 360.70 S 3041.31 W 5993509.64 N 472990.26 E 0.270 3062.37 5524.83 49.650 260.620 4113.90 4171.00 372.54 S 3114.36 W 5993498.04 N 472917.17 E 0.645 3136.34 5619.34 49.910 260.810 4174.93 4232.03 384.18 S 3185.58 W 5993486.62 N 472845.91 E 0.315 3208.47 5714.10 49.730 260.610 4236.07 4293.17 395.87 S 3257.03 W 5993475.16 N 472774.43 E 0.249 3280.84 5809.25 49.740 260.230 4297.57 4354.67 407.95 S 3328.62 W 5993463.31 N 472702.80 E 0.305 3353.40 5903.78 49.160 260.560 4359.02 4416.12 419.94 S 3399.44 W 5993451.55 N 472631.94 E 0.668 3425.17 5999.05 49.730 261.930 4420.96 4478.06 430.95 S 3470.98 W 5993440.77 N 472560.36 E 1.246 3497.54 6094.49 49.080 262.540 4483.07 4540.17 440.75 S 3542.79 W 5993431.20 N 472488.53 E 0.836 3570.01 6189.85 48.360 261.630 4545.98 4603.08 450.61 S 3613.76 W 5993421.57 N 472417.52 E 1.041 3641.66 6284.40 47.830 261.900 4609.13 4666.23 460.69 S 3683.41 W 5993411.71 N 472347.84 E 0.599 3712.03 6379.38 47.760 262.910 4672.94 4730.04 469.99 S 3753.14 W 5993402.63 N 472278.08 E 0.791 3782.38 6474.57 49.910 262.800 4735.59 4792.69 478.90 S 3824.24 W 5993393.95 N 472206.95 E 2.260 3854.04 6569.11 49.590 262.430 4796.68 4853.78 488.18 S 3895.80 W 5993384.90 N 472135.36 E 0.451 3926.19 6663.34 49.010 263.320 4858.12 4915.22 497.04 S 3966.69 W 5993376.27 N 472064.45 E 0.944 3997.63 6755.62 50.560 261.190 4917.71 4974.81 506.55 S 4036.50 W 5993366.98 N 471994.61 E 2.435 4068.09 6852.22 49.780 260.030 4979.58 5036.68 518.65 S 4109.69 W 5993355.12 N 471921.38 E 1.226 4142.23 6947.69 49.070 260.700 5041.68 5098.78 530.79 S 4181.18W 5993343.21 N 471849.85 E 0.915 4214.69 -- 7043.17 50.710 260.750 5103.19 5160.29 542.56 S 4253.24 W 5993331.67 N 471777.75 E 1.718 4287.68 7134.84 50.320 261 .160 5161.48 5218.58 553.68 S 4323.11 W 5993320.77 N 471707.84 E 0.548 4358.40 7233.28 50.250 259.970 5224.38 5281.48 566.09 S 4397.81 W 5993308.60 N 471633.11 E 0.933 4434.08 7328.08 49.820 260.150 5285.27 5342.37 578.64 S 4469.38 W 5993296.29 N 471561.50 E 0.476 4506.67 7423.84 48.880 258.950 5347.66 5404.76 591.81 S 4540.82 W 5993283.34 N 471490.01 E 1.367 4579.22 7518.83 50.160 260.520 5409.32 5466.42 604.67 S 4611.92 W 5993270.71 N 471418.88 E 1.843 4651.39 7614.97 49.150 260.060 5471.56 5528.66 617.03 S 4684.14 W 5993258.58 N 471346.62 E 1.112 4724.61 7710.40 48.200 258.910 5534.58 5591.68 630.10 S 4754.60 W 5993245.74 N 471276.11 E 1.345 4796.17 7796.12 47.690 260.120 5592.00 5649.10 641.69 S 4817.18 W 5993234.35 N 471213.50 E 1.205 4859.73 1 April, 2003 - 13:13 Page 50i7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 35-22 Your Ref: API 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/10Oft) 7900.75 46.790 259.550 5663.03 5720.13 655.24 S 4892.80 W 5993221.04 N 471137.84 E 0.949 4936.46 7993.95 46.600 259.600 5726.96 5784.06 667.51 S 4959.50 W 5993208.98 N 471071.10 E 0.208 5004.20 8091.83 46.330 259.280 5794.38 5851 .48 680.52 S 5029.25 W 5993196.20 N 471001.30 E 0.364 5075.05 8186.15 46.760 260.620 5859.25 5916.35 692.46 S 5096.67 W 5993184.47 N 470933.85 E 1.128 5143.45 '~ 8281.91 45.940 260.170 5925.35 5982.45 704.02 S 5164.99 W 5993173.13 N 470865.49 E 0.921 5212.69 8356.38 45.360 260.690 5977.41 6034.51 712.88 S 5217.50 W 5993164.45 N 470812.95 E 0.925 5265.91 8423.00 45.360 260.690 6024.22 6081.32 720.54 S 5264.28 W 5993156.93 N 470766.15 E 0.000 5313.29 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 = 57.1' MSL. Northings and Eastings are relative to 2556' FNL, 1227' 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 2556' FNL, 1227' FEL and calculated along an Azimuth of 262.500° (True). Magnetic Declination at Surface is 25.188°(11-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8423.00ft., The Bottom Hole Displacement is 5313.36ft., in the Direction of 262.206° (True). ----- 1 April, 2003 - 13:13 Page6of7 Dril/Quest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 3S-22 Your Ref: API 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPhillips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment .-- 8423.00 6081 .32 720.54 S 5264.28 W Projected SUNey Survey tool program for 3~-?? From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 83.00 0.00 83.00 83.00 8423.00 83.00 Tolerable Gyro 6081.32 AK-6 BP _IFR-AK .~ 1 April, 2003 - 13:13 Page 70(7 DrillQuest 3.03.02.002 ) AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-22 MWD Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window I Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 8,423.00' MD (if applicable) ) ó?o 3-0 I( 16-Apr-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED APR 2 2 2003 Alaska Of¡ & Gas Cons. Commisaon Anchorage ............. ............ o l ~. o ~ Sperry-Sun Drilling Services ,-.- Western North Slope ConocoPhillips Kuparuk 3S Pad 35-22 MWD Job No. AKZZ2280031, Surveyed: 21 February, 2003 Survey Report 18 March, 2003 Your Ref: 501032044600 Surface Coordinates: 5993860.59 N, 476032.71 E (70023' 39.6794" N, 150011'42.0163" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 r~. Surface Coordinates relative to Project H Reference: 993860.59 N, 23967.29 W (Grid) Surface Coordinates relative to Structure: 16.24 N, 422.34 W (True) Kelly Bushing: 57. 10ft above Mean Sea Level Elevation relative to Project V Reference: 57. 10ft Elevation relative to Structure: 1.00ft spe""'''''y-suf! DRILLING seRVices A Halliburton Company Survey Ref: svy1998 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-22 MWD Your Ref: 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPhiflips Western North Slope .... Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. 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 -57.10 0.00 0.00 N O.OOE 5993860.59 N 476032.71 E 0.00 Tolerable Gyro 83.00 0.500 30.000 25.90 83.00 0.31 N 0.18 E 5993860.90 N 476032.89 E 0.602 -0.22 MWD Magnetic 197.65 0.460 61 .480 140.55 197.65 0.97 N 0.84 E 5993861.55 N 476033.55 E 0.230 -0.95 288.85 0.650 30.450 231.74 288.84 1.59 N 1 .42 E 5993862.17 N 476034.13 E 0.382 -1.61 380.97 0.320 74.650 323.86 380.96 2.11 N 1.93 E 5993862.69 N 476034.65 E 0.517 -2.19 ".,...-....-- 471.25 0.060 22.180 414.14 471.24 2.22 N 2.19 E 5993862.80 N 476034.91 E 0.318 -2.46 503.32 0.170 28.310 446.21 503.31 2.27 N 2.22 E 5993862.86 N 476034.94 E 0.345 -2.50 533.89 0.090 28.310 476.78 533.88 2.33 N 2.26E 5993862.92 N 476034.97 E 0.262 -2.54 564.03 0.540 20.600 506.92 564.02 2.49 N 2.32 E 5993863.07 N 476035.03 E 1 .496 -2.62 593.52 0.830 316.140 536.40 593.50 2.77 N 2.22 E 5993863.36 N 476034.94 E 2.613 -2.56 623.94 1.530 261.520 566.82 623.92 2.87 N 1.66 E 5993863.46 N 476034.38 E 4.105 -2.02 653.18 2.590 246.710 596.04 653.14 2.55 N 0.67E 5993863.14 N 476033.39 E 4.027 -1.00 682.11 4.140 256.000 624.92 682.02 2.04 N 0.94W 5993862.63 N 476031.77 E 5.662 0.67 712.35 5.060 256.900 655.06 712.16 1.48 N 3.30W 5993862.08 N 476029.41 E 3.052 3.08 744.21 6.070 259.080 686.77 743.87 0.84 N 6.32W 5993861.45 N 476026.39 E 3.238 6.16 772.89 6.460 261.550 715.28 772.38 0.31 N 9.41 W 5993860.93 N 476023.30 E 1.653 9.29 803.49 7.960 269.320 745.64 802.74 0.04 N 13.23 W 5993860.67 N 476019.48 E 5.836 13.11 833.38 8.600 274.730 775.22 832.32 0.20 N 17.53 W 5993860.84 N 476015.18 E 3.371 17.35 866.92 9.130 280.820 808.36 865.46 0.90 N 22.64 W 5993861.56 N 476010.07 E 3.211 22.33 898.96 8.900 275.680 840.00 897.1 0 1.62 N 27.60 W 5993862.30 N 476005.11 E 2.613 27.16 929.59 9.190 279.790 870.25 927.35 2.27 N 32.37 W 5993862.97 N 476000.35 E 2.312 31.80 962.08 9.530 280.830 902.31 959.41 3.22 N 37.57 W 5993863.93 N 475995.15 E 1.169 36.83 993.33 1 0.180 281.510 933.10 990.20 4.26 N 42.82 W 5993864.99 N 475989.91 E 2.113 41.90 1023.87 10.960 282.860 963.12 1020.22 5.44 N 48.29 W 5993866.19 N 475984.44 E 2.679 47.17 1056.32 11.800 282.230 994.93 1052.03 6.83 N 54.54 W 5993867.60 N 475978.19 E 2.617 53.18 ,.- 1089.40 12.340 279.400 1027.28 1084.38 8.13 N 61.34 W 5993868.91 N 475971.40 E 2.421 59.75 1120.59 12.460 277.390 1057.74 1114.84 9.10 N 67.96 W 5993869.91 N 475964.78 E 1 .436 66.19 1153.62 13.510 276.530 1089.93 1147.03 10.00 N 75.33 W 5993870.83 N 475957.41 E 3.232 73.38 1186.06 14.420 276.710 1121.41 1178.51 10.90 N 83.10 W 5993871.76 N 475949.64 E 2.808 80.97 1216.26 14.900 272.710 1150.62 1207.72 11.53 N 90.72 W 5993872.41 N 475942.03 E 3.709 88.44 1248.61 15.930 275.210 1181.81 1238.91 12.13 N 99.29 W 5993873.03 N 475933.46 E 3.788 96.86 1280.26 17 .140 273.190 1212.15 1269.25 12.78 N 108.28 W 5993873.72 N 475924.48 E 4.232 105.68 1310.59 18.250 270.890 1241.05 1298.15 13.10 N 117.49 W 5993874.07 N 475915.27 E 4.324 114.77 1343.63 19.440 267.970 1272.32 1329.42 12.99 N 128.15 W 5993873.99 N 475904.60 E 4.595 125.36 1374.92 19.970 266.400 1301.77 1358.87 12.47 N 138.69 W 5993873.50 N 475894.06 E 2.394 135.88 1404.26 20.900 265.540 1329.27 1386.37 11.75 N 148.91 W 5993872.81 N 475883.84 E 3.331 146.10 1438.34 22.500 265.460 1360.93 1418.03 10.76 N 161.47W 5993871.87 N 475871.27 E 4.696 158.69 1470.48 22.620 264.840 1390.61 1447.71 9.71 N 173.76 W 5993870.86 N 475858.98 E 0.829 171.00 1501.68 23.320 260.950 1419.34 1476.44 8.20 N 185.83 W 5993869.39 N 475846.90 E 5.357 183.17 1595.88 26.330 265.540 1504.83 1561.93 3.64 N 225.09 W 5993864.96 N 475807.64 E 3.792 222.68 . ---- - -- ----_._--- 1 B March, 2003 - 16:00 Page 2 of 5 DrillQllost 3.03.02.004 Sperry-Sun Drilling Services SUlvey Report for Kuparuk 3S Pad - 3S-22 MWD Your Ref: 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPhlllips Western North Slope '. Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 1626.61 26.510 265.990 1532.35 1589.45 2.64 N 238.72 W 5993863.99 N 475794.00 E 0.876 236.34 1660.33 26.320 265.670 1562.55 1619.65 1.54 N 253.68 W 5993862.95 N 475779.03 E 0.704 251.31 1690.30 27.110 267.540 1589.32 1646.42 0.75 N 267.13 W 5993862.20 N 475765.58 E 3.849 264.75 1723.76 28.490 269.430 1618.92 1676.02 0.34 N 282.73 W 5993861.84 N 475749.98 E 4.893 280.27 1756.22 30.700 269.340 1647.15 1704.25 0.17 N 298.76 W 5993861.72 N 475733.95 E 6.810 296.18 ^" --, 1787.59 32.740 269.710 1673.83 1730.93 0.04 N 315.25 W 5993861.64 N 475717.46 E 6.533 312.55 1821.21 35.560 267.960 1701.65 1758.75 0.36 S 334.11 W 5993861.30 N 475698.60 E 8.881 331.30 1852.58 38.630 267.800 1726.67 1783.77 1.06 S 353.02 W 5993860.66 N 475679.69 E 9.791 350.14 1883.67 41.690 268.780 1750.43 1807.53 1.65 S 373.06 W 5993860.13 N 475659.65 E 10.050 370.08 1916.04 43.410 268.030 1774.27 1831.37 2.26S 394.94 W 5993859.59 N 475637.77 E 5.540 391.86 1947.50 43.630 268.430 1797.08 1854.18 2.93 S 416.59 W 5993858.99 N 475616.11 E 1.121 413.41 1978.18 44.120 268.720 1819.20 1876.30 3.46 S 437.85 W 5993858.53 N 475594.85 E 1.726 434.56 2011.21 45.160 269.680 1842.70 1899.80 3.78 S 461.05 W 5993858.28 N 475571.65 E 3.753 457.60 2042.75 46.290 268.380 1864.72 1921.82 4.17 S 483.63 W 5993857.97 N 475549.07 E 4.642 480.04 2073.71 47.200 267.920 1885.93 1943.03 4.90 S 506.17 W 5993857.32 N 475526.53 E 3.132 502.48 2106.45 47.640 267.180 1908.09 1965.19 5.93 S 530.25 W 5993856.36 N 475502.44 E 2.139 526.49 2137.65 48.330 265.870 1928.97 1986.07 7.33 S 553.39 W 5993855.03 N 475479.30 E 3.824 549.61 2169.40 48.380 263.910 1950.07 2007.17 9.45 S 577.02 W 5993852.99 N 475455.66 E 4.616 573.32 2201.69 49.210 262.140 1971.34 2028.44 12.40 S 601.13 W 5993850.12 N 475431.54 E 4.859 597.61 2233.16 50.090 261.440 1991.72 2048.82 15.83 S 624.87 W 5993846.77 N 475407.79 E 3.270 621.59 2263.22 50.170 261.540 2010.99 2068.09 19.24 S 647.69 W 5993843.43 N 475384.97 E 0.369 644.66 2358.98 50.710 260.070 2071.98 2129.08 31.04 S 720.56 W 5993831.86 N 475312.05 E 1.311 718.45 2454.88 50.960 259.360 2132.54 2189.64 44.32 S 793.72 W 5993818.82 N 475238.85 E 0.630 792.71 2549.50 51.310 259.490 2191.92 2249.02 57.84 S 866.14 W 5993805.53 N 475166.39 E 0.385 866.28 2645.53 50.560 261.770 2252.44 2309.54 69.98 S 939.70 W 5993793.62 N 475092.79 E 2.002 940.79 /~ 2740.63 50.550 260.060 2312.86 2369.96 81.58 S 1012.21 W 5993782.26 N 475020.24 E 1.389 1014.20 2837.13 51 .400 258.040 2373.63 2430.73 95.82 S 1085.80 W 5993768.25 N 474946.60 E 1.849 1089.02 2931.72 50.350 258.610 2433.32 2490.42 110.68S 1157.66W 5993753.63 N 474874.70 E 1.204 1162.21 2986.54 50.540 261.970 2468.23 2525.33 117.80S 1199.31 W 5993746.64 N 474833.02 E 4.738 1204.43 3047.51 51.000 262.280 2506.79 2563.89 124.27 S 1246.10 W 5993740.31 N 474786.22 E 0.851 1251.66 3143.09 49.940 262.560 2567.63 2624.73 134.00 S 1319.17W 5993730.82 N 474713.12 E 1.132 1325.38 3237.65 49.410 262.370 2628.82 2685.92 143.45 S 1390.64 W 5993721.60 N 474641 .62 E 0.581 1397.47 3333.96 48.360 261.870 2692.15 2749.25 153.39 S 1462.51 W 5993711.89 N 474569.71 E 1.158 1470.02 3429.00 47.810 261.440 2755.64 2812.74 163.66 S 1532.49 W 5993701.85 N 474499.71 E 0.670 1540.74 3524.12 47.060 260.780 2819.98 2877.08 174.48 S 1601.70 W 5993691.24 N 474430.46 E 0.940 1610.77 3619.28 48.470 262.510 2883.94 2941.04 184.71 S 1671.40 W 5993681.24 N 474360.72 E 2.002 1681.21 3715.43 48.250 262.590 2947.83 3004.93 194.02 S 1742.65 W 5993672.15 N 474289.44 E 0.237 1753.07 3810.05 50.830 263.500 3009.23 3066.33 202.73 S 1814.11 W 5993663.68 N 474217.96 E 2.823 1825.05 3905.42 50.460 264.490 3069.70 3126.80 210.45 S 1887.45 W 5993656.20 N 474144.60 E 0.891 1898.77 4001.85 49.750 263.840 3131.55 3188.65 217.96 S 1961.05 W 5993648.91 N 474070.98 E 0.900 1972.72 ---~------- 18 March, 2003 - 16:00 Page 3 of 5 DrillQl/üst 3.03.02.004 DrlllQlIest 3.03.02.004 Page 4 of 5 18 March, 2003 - 16:00 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-22 MWD Your Ref: 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPhllllps Western North Slope Measured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth (ncl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4095.82 51.160 262.160 3191.38 3248.48 226.81 S 2032.96 W 5993640.30 N 473999.03 E 2.038 2045.17 4190.97 50.610 263.700 3251.41 3308.51 235.90 S 2106.22 W 5993631.45 N 473925.75 E 1.382 2118.99 4286.68 50.490 263.510 3312.23 3369.33 244.13 S 2179.66 W 5993623.45 N 473852.27 E 0.198 2192.88 4381.73 50.160 264.070 3372.91 3430.01 252.04 S 2252.39 W 5993615.77 N 473779.52 E 0.571 2266.02 4475.82 49.660 262.960 3433.50 3490.60 260.17 S 2323.91 W 5993607.87 N 473707.98 E 1.047 2337.99 -- 4572.24 49.430 263.240 3496.07 3553.17 268.98 S 2396.75 W 5993599.29 N 473635.11 E 0.325 2411.35 4667.36 49.200 262.520 3558.07 3615.17 277 .92 S 2468.32 W 5993590.58 N 473563.51 E 0.623 2483.48 4763.99 50.630 262.570 3620.30 3677 .40 287.51 S 2541.62 W 5993581.23 N 473490.18 E 1.480 2557.41 4859.65 50.1 30 262.920 3681.30 3738.40 296.82 S 2614.72 W 5993572.15 N 473417.05 E 0.594 2631.09 4954.37 49.730 261.710 3742.27 3799.37 306.51 S 2686.55 W 5993562.69 N 473345.19 E 1.065 2703.58 5049.66 49.580 262.290 3803.96 3861.06 316.62 S 2758.47 W 5993552.82 N 473273.24 E 0.490 2776.20 5145.28 49.480 262.260 3866.02 3923.12 326.40 S 2830.55 W 5993543.27 N 473201.12 E 0.107 2848.94 5238.34 49.320 261.430 3926.59 3983.69 336.42 S 2900.50 W 5993533.4 7 N 473131.15 E 0.699 2919.59 5333.49 48.920 261.730 3988.86 4045.96 346.95 S 2971.66 W 5993523.17 N 473059.95 E 0.483 2991.52 5427.31 49.080 261.660 4050.41 4107.51 357.18 S 3041.73 W 5993513.16 N 472989.86 E 0.180 3062.32 5524.83 49.650 260.780 4113.92 4171.02 368.48 S 3114.86 W 5993502.10 N 472916.68 E 0.900 3136.31 5619.34 49.910 260.980 4174.95 4232.05 379.92 S 3186.11 W 5993490.89 N 472845.39 E 0.319 3208.45 5714.10 49.730 260.700 4236.09 4293.19 391.44 S 3257.59 W 5993479.59 N 472773.88 E 0.295 3280.81 5809.25 49.740 260.290 4297.58 4354.68 403.43 S 3329.20 W 5993467.83 N 472702.24 E 0.329 3353.37 5903.78 49.160 260.730 4359.04 4416.14 415.28 S 3400.04 W 5993456.22 N 472631.35 E 0.708 3425.16 5999.05 49.730 261.660 4420.98 4478.08 426.35 S 3471.57 W 5993445.37 N 472559.79 E 0.953 3497.52 6094.49 49.080 260.670 4483.09 4540.19 437.48 S 3543.18 W 5993434.4 7 N 472488.15 E 1.041 3569.97 6189.85 48.360 261.180 4546.00 4603.10 448.79 S 3613.94 W 5993423.39 N 472417.35 E 0.855 3641.61 6284.40 47.830 261.330 4609.15 4666.25 459.48 S 3683.50 W 5993412.92 N 472347.76 E 0.573 3711.96 6379.38 47.760 262.630 4672.95 4730.05 469.30 S 3753.16 W 5993403.33 N 472278.06 E 1.017 3782.31 ,- 6474.57 49.910 261.370 4735.61 4792.71 479.29 S 3824.11 W 5993393.57 N 472207.08 E 2.469 3853.96 6569.11 49.590 262.060 4796.69 4853.79 489.68 S 3895.52 W 5993383.40 N 472135.64 E 0.652 3926.11 6663.34 49.010 263.690 4858.14 4915.24 498.55 S 3966.40 W 5993374.76 N 472064.73 E 1.449 3997.54 6755.62 50.560 261 .440 4917.73 4974.83 507.68 S 4036.26 W 5993365.85 N 471994.84 E 2.507 4068.00 6852.22 49.780 262.500 4979.60 5036.70 518.05 S 4109.71 W 5993355.72 N 471921.36 E 1.167 4142.17 6947.69 49.070 260.750 5041.70 5098.80 528.60 S 4181.45 W 5993345.40 N 471849.59 E 1.578 4214.68 7043.17 50.710 260.300 5103.21 5160.31 540.63 S 4253.48 W 5993333.60 N 471777.52 E 1.755 4287.65 7134.84 50.320 261.890 5161.51 5218.61 551.58 S 4323.37 W 5993322.87 N 471707.60 E 1 .405 4358.38 7233.28 50.250 260.340 5224.41 5281.51 563.28 S 4398.18 W 5993311.42 N 471632.75 E 1.213 4434.07 7328.08 49.820 260.730 5285.30 5342.40 575.22 S 4469.85 W 5993299.70 N 471561.04 E 0.552 4506.69 7423.84 48.880 259.420 5347.68 5404.78 587.74 S 4541.41 W 5993287.41 N 471489.44 E 1.429 4579.27 7518.83 50.160 261.140 5409.35 5466.45 599.93 S 4612.62 W 5993275.45 N 471418.19 E 1.927 4651.47 7614.97 49.150 260.580 5471.59 5528.69 611.56 S 4684.96 W 5993264.05 N 471345.81 E 1.140 4724.71 7710.40 48.200 259.330 5534.61 5591.71 624.06 S 4755.53 W 5993251.78 N 471275.20 E 1.399 4796.30 7796.12 47.690 261.240 5592.03 5649.13 634.80 S 4818.26 W 5993241.24 N 471212.44 E 1.758 4859.89 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 35-22 MWD Your Ref: 501032044600 Job No. AKZZ2280031, Surveyed: 21 February, 2003 ConocoPl1IlIíps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7900.75 46.790 260.190 5663.06 5720.16 647.19 S 4894.07 W 5993229.09 N 471136.59 E 1.133 4936.67 7993.95 46.600 259.970 5726.99 5784.09 658.87 S 4960.88 W 5993217.62 N 471069.75 E 0.267 5004.44 8091.83 46.330 261.270 5794.41 5851.51 670.44 S 5030.88 W 5993206.28 N 470999.70 E 1.002 5075.35 8186.15 46.760 260.750 5859.28 5916.38 681.14 S 5098.51 W 5993195.80 N 470932.04 E 0.607 5143.80 8281.91 45.940 259.910 5925.38 5982.48 692.78 S 5166.81 W 5993184.38 N 470863.70 E 1.066 5213.04 /-- 8356.38 45.360 260.750 5977 .44 6034.54 701.72 S 5219.31 W 5993175.61 N 470811.18 E 1.121 5266.25 8423.00 45.360 260.690 6024.25 6081.35 709.37 S 5266.09 W 5993168.11 N 470764.37 E 0.064 5313.63 Projected Survey All data is in Feet (US Survey) unless othelWÍse stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 57.1' MSL. Northings and Eastings are relative to 2556' FNL, 1227' 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 2556· FNL, 1227' FEL and calculated along an Azimuth of 262.500° (True). Magnetic Declination at Surface is 25.188°(11-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8423.00ft., The Bottom Hole Displacement is 5313.65ft., in the Direction of 262.328° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment r-~.. 8423.00 6081.35 709.37 S 5266.09 W Projected Survey Survey tool program for 35-22 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 83.00 0.00 83.00 83.00 8423.00 83.00 Tolerable Gyro 6081.35 MWD Magnetic ----- 18 March, 2003 - 16:00 Page 5 of 5 DrllIQuest 3.03.02.004 ) ) MEMORANDUM Jþ I J State of Alaska ().¥ ~/'2Jðj Ù J1aska Oil and Gas Conservation Commission TO: Randy Ruedrich t DATE: March 25, 2003 Chair ,/\\11\1)~ - <\J. ' ~ SUBJECT: Mechanical Integrity Tests THRU: Jim Regg ~1~\ ConocoPhillips P.I. Supervisor 38 16,22 FROM: John H. Spaulding Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 38-16 Type Inj. 8 TV.D. 5718 Tubing 2360 2360 2360 2360 Interval 4 P.TD. 2030070 Type test P= T est psi 1430 Casing 1060 1950 1920 1920 P/F f Notes: Well 38-22 Type Inj. 8 T.V.D. 5626 Tubing 2150 2150 2150 2150 Interval 4 P.TD. 2030110 Type test P= T est psi 1407 Casing 1075 1950 1950 1900 P/F f Notes: Well Type Inj. T.V.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details The wells were ready to begin testing upon my arrival (fluid packed) Although the ambient temp. was -42 the tests were completed without to much difficulty M.I.T.ls performed: 1 Attachments: none Number of Failures: .Q Total Time during tests: 4hrs. cc: none MIT report form 5/12/00 L. G. mit kru 3s 2-25-03 js.xls 5/12/2003 ~~~~,~ ~ } f ~~~~~-.~~~ ) \,.~-, FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU 3S-22 ConocoPhillips Alaska, Inc. Pennit No: 203-011 Surface Location: 2556' FNL, 1227' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 2020' FSL, 1778' FEL, Sec. 13, TI2N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced service well. This pennit to drill does not exen1pt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Comn1Íssion 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 Adn1Ïnistrative Code, or a Commission order, or the tenns 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, ~cr~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this;'7~day of January, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ". .... /' ') ConO.cõPhillips ') Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com January 17, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, injector 38-22 Dear Commissioner Taylor: / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, KRU 38-22, 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 8cott Lowry at 265-6869. Sincerely, ~~ Randy Thomas GKA Drilling T earn Leader RECEIVED JAN 1 7 2003 Alaska Oil & Gas Cons. Commission - Anchorage ;~) ~ \ ~ ~ '\ ~ :1 ~ '.\ l_, VJ6A- if¡ ì I D''S ) STATE OF ALASKA '} ALASKA OIL AND GAS CONSERVATION COMMISSION 1 a. Type of work: Drill ld Redrill U Re-entry DDeepen 0 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2556'FNL, 1227'FEL, Sec. 18,T12N,R8E,UM At top of productive interval 2049' FSL, 1528' FEL, Sec. 13, T12N, R7E, UM At total depth 2020' FSL, 1778' FEL, Sec. 13, T12N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 1528' @ target 3S-26A @ 25' @ 850' 16. To be completed for deviated wells Kickoff depth: 220 MD 18. Casing program size PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (DF or KB) RKB = 28' U o Development Oil U Multiple Zone 0 10. Field and Pool /" feet 6. Property Designation ADL 25544 ALK 2639 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number , Number 3S-22 / #59-52-180 9. Approximate spud date ...../ Amount January 31, 2003 $200,000 14. Number of acres in property 15. Proposed dJPth (MD and TVD) 2560 8405' MD 16118' TVD 17. Anticipated pressure (see ¡MC 25.035 (e)(2)) Maximum surface 2992 psig At total depth (TVD) 3649 psig Setting Depth Kuparuk River Field ,.,- Kuparuk River Oil Pool Maximum hole angle 47° Weld 80' 3143' 8377' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' 1 st stage: 28 sx ArcticCrete, 2nd stage: 41 bbls ArcticCrete 28' 28' 3171' 2568' 560 sx AS Lite & 250 sx LiteCrete /' 28' 28' 8405' 6118' 300 sx Class G / Hole Casing Weight 42" 30"x16" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling Length H-40 L-80 L-80 BTC BTCM 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface Production Length Size Cemented Measured depth True Vertical depth RECEI\/ED Perforation depth: measured JAN 1 7' 200~~ true vertical ~~aska Oil & Gas Cons. Commission 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling progr~~p&rag~; Drilling fluid program 0 Time vs depth plot Qefraction analysis 0 Seabed report 020 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 Signed \ ' R. ThO~ \~ Title: Kuparuk Drilling Team Leader Date t (, 7 10 S Prfm::m~rf hv Shamn Allf::/m-nrakp. Commission Use Only Permit Number I API number I Approval date \/ 1) 3 ~ee cover letter Z 0 ~ - 0 / / 50- /0 $.- .2. 0 7' ~ 6 (). 0 _ for other requirements Conditions of approval Samples required 0 Yes ~ No Mud log required Yes ~ No Hydrogen sulfide measures 0 Yes ~ No Directional survey required ~ Yes 0 No Require9 working pressure for BOPE. [J2,M; 0 3M; 0 5M; 0 10M; 0 D'''R-s+ .fr7 P ~ ~ $000 pf. t' . Other' V-t'.,- 'll..'" AAL lS. ~ I ~ L bJ ì ()~ It:£-,- &.tf U,.. H: ê"",~~\..(....^-e~,-- i- ,'S I;;..,~...¿ 1/ l J . . ¡Vl}:"C\ e..~¡¡,-\- ~L(,;I .J;~.\ i~~ ~ 'bLL{ .~ d. 4.1' I,);O"Øl.{ ~OIA..'~ì'-l~y ~e~ of'-'l h".·..- fw-..¢! ~~~ ~·1t1 r ~\?1Þ t(.v(;\ 4 Approved by ORIGINAL SI~NED BY ..., ,cfI\m,~s~I...I.O, ~eA the commission Oate ,/:;.. /f If)-:; M L. sin ( i ¡ {~. ~ n n J~ijj~h- Form 10-401 Rev. 12/1/85· Submit in triplicate ) APr.·· )on for Permit to Drill, Well 3S-22 Revision No.O Saved: 16-Jan-03 Permit It - Kuparuk Well 35-22 Application for Permit to Drill Document MoximizE We-II "101"-11; 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. Dri II 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. Casing and Cementi ng 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. Dri II i ng FI uid 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 1 o. Se ism i c An a I ys is........ .............................................................................................. 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 Bond i ng ........... ......... ............ ...... ................ .... ..... ........ ..... ....... ...... ...... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Dri II i ng Program ..... ..... .................... ..... ........ ...... ......... .... ..... ..... ... ...... .... 6 C n! {'~\'''. , A , I \:1 J " Y ... 38-22 PERMIT IT. DOC Page 1 of 7 Printed: 16-Jan-03 ) Ap~¡. ,lon for Permit to Drill, We1l3S-22 Revision No.O Saved: 16-Jan-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. Attachments .... .......................... ..... .... .............. ... ...... ............. ..... ........ ..... ........... ..... 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 unique name des¿qnated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple we/I brr..-:¡nche!;,~ eaä7 branch must similarly be Identified by a unique narne and API number by adding a suffix to the name deSlf7f7ated tor tl7e well by the operator and to the number assigned to the well by the commiss'ion. The well for which this application is submitted will be designated as 35-22. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fÓr a Permit to Dlilf must be accompanied by each of" the fallowing items¡ exæpt for an item already on tHe with the commission and Identified in the applIcatIon: (2) a plat Identif"yIÌ7{) the property and the propetty's owners and showing (A)the mordinates of the proposed locatIon of the well at the surface/ at the top of each oL?Jective f'ormatlon and at total depth, re{erenced to governmental section lInes. (8) the coordli7ates of tile proposed location of the well at the .fiudace, referenced tv the state pl.:me coordinate system {'Or th/~fi state as maintained by tfle National Geodetic Survey In tile National OceanIc and Atmospheríc AdmInistration,· (C) tile proposed depth of the well at the top of each objective formation and at total depth/ Location at Surface NGS Coordinates Northings: 5,993,861 12556' FNL, 1227' FEL, Sec 18, T12N, R8E, UM /" RKB Elevation Eastings: 476,033 Pad Elevation Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,993,204 2049' FSL, 1528' FEL, Sec 13, T12N, R7E, UM /' /' Eastings: 470,923 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: ,/ Location at Total Depth 12020' FSL, 1778' FEL, NGS Coordinates Northings: 5,993,176 Eastings: 470,674 Sec13,T12N, R7E,UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: and (0) other intormatlon reqUli'ed by 20 AAC 25.0S0(bJ/ 56.1' AMSL 28.0' AMSL 8064' 5886' 5830' 8405' 6118' 6062' Requirements of 20 AAC 25.050(b) If a well is to be Intentionally deviated, the application for a PermIt to Dnll (Fom] 10-401) must (1) ¡¡7e1ude a plat, drawn to a sUItable scale, showing the path of the proposed wellbore/ ineluding all adjacent wellbores within 200 feet of any portion of the proposed well," Please see Attachment 1: Directional Plan J "'"': ~ .~ g :~i I I I . l1' ¡ ~1 ¡ j V 1-: ... 38-22 PERMIT IT.DOC Page 2 of 7 Printed: 16-Jan-03 } APíJ.._~ìion for Permit to Drill, We1l3S-22 Revision No.O Saved: 16-Jan-03 and (2) for all well.') witt7in 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that th05"(3 names are known or di!:.T.ovemble 1i7 public record~ and show that each named operator has been fumifJ17ed a copy of the application by certilìed ma/~' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application lor a Permit 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 d/~1gram and descriptio/? of the blowout prevention equipment (BOPE) as required by 20 AAC 25,035, 20 AAC 25.036, 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 f'Or a PermIt to Drill must be accompanied by ead7 of the tollowing items; except t(7r an Item already on file with the c:vmmis..r:,ion and identitied in the application: (4) infbrrnation on dnlling /¡azards¡ including (A) the maximum downhole pressure that may be encoul7terett cntefia used to deten71i/7¿> it" and maximum potential slIIf;¡Cé' pressure based on a methane gradient; A pressure build-up test performed on Palm 1A (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MP5P) while drilling 35-22 is calculated using above maximum reservoir pressure, a gas gr.adie~.. .... f .11 psi/ft, and the Kuparuk C sand target at 5886' tvd: MP5P =(5886 ft)*(0.62 -.1 si/ft) = 2992 psi /' (8) data 0/7 potential gas zone!;,~' The well bore is not expected to penetrate any gas zones. and (C) dati] concerning potentkJI Ci]uses of hole problems such a8 abnormally geo·pre.%ìJred !:;tratal lost circulation ZO/7es¡ and zones tt7at have a 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) A/7 application for a Permit to Drill must be accompanied by each of the fbllowi/7g item~ except lor a/? item already 0/7 tìle wIth the commission and Identified i/7 the applicatio/7: (5) a descriptio/? ol the procedure for conducti/7g formatkJ/7 i/7tegrity test~ as required under 20 MC 25.030(f}; A procedure is on file with the commission for performing LOT's. For 35-22 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) Jr:~îf:f~!")~J fiiGiJVJ-tá. 3$-22 PERMIT IT. DOC Page 3 of 7 Printed: 16-Jan-03 ) ì APf-h_.,Àion for Permit to Drill, We1l3S-22 Revision No.O Saved: 16-Jan-03 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be acc;vmpanied by eaä7 of the following Item~ except for an item already on file with the commiS':,70n and identified in the appliCi~tion: (6) a f.:"'Omplete proposed casing and cementing program as required by 20 MC 25. 03Q, and a desaiption of any slotted linef"r pre~ perforated linef"r or screen to be ¡¡7stalled.: Casing and Cementing Program Hole Top Btm CsgfTbg Size Weight Length MDfTVD MDfTVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H¿O Welded 80 28 / 28 108 / 108 9 cy High Early Insulated ./ 9-5/8 12-1/4 40 L-80 BTC 3143' 28'/28' 3171'/2568' Lead: 560 sx 10.7 ppg AS Lite Tail: 250 sx 12.0 ppg 'LiteCRETE' . (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 8377' 28'/28' 8405'/6118' 300 sx 15.8 ppg 'G' w/ add. /~'-J Planned TOC= 1{J},1~/ M D ."..-- 3-1/2 9.3 L-80 EUE 8rd 7686' 28' / 28' 7714'/5649' SAB- 3 packer set at Mod 7714' 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 MC 25.412 (b) is requested. The distance between seals at the top of the 3 V2"liner and the top perforation will exceed 200' 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 applkätion tor a Pelil7lt to Drill must be accompanied by each ot the fallow¡17g Item~ except for an Item already on file with the commis::.7on and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25. 03~ unless thl5 requirement 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 Onll must be accompanied by each of the fol/owing 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 description of the dnlling fluid system, as required by 20 MC 25. 033/ Drilling will be done using mud systems having the following properties: ( 1/G'~'f I . 1 ~/JVf'¡'. 3$-22 PERMIT IT. DOC Page 4 of 7 Printed: 16-Jan-03 ) APIJ.,,,,)ion for Permit to Drill, Well 3S-22 Revision No.O Saved: 16-Jan-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* .:=.s9.4* 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 10-30 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 .,..,.... 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 15-1 9 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Onl/ must be accompanied by each of the fo/lowing items, except for an item already on file wIth the commission and identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as reqwÌ'ed by 20 AAC 25. 033(f}; N/A - Application is not for an exploratory or stratigraphic test well. Orìl~iiÚiL 3S-22 PERMIT IT.DOC Page 5 of 7 Printed: 16-Jan-03 ) APIJ..vJion for Permit to Drill, Well 3S-22 Revision No.O Saved: 16-Jan-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 the tollowing item5~ exæpt tor an item already on file with the cvmmission and identified in the applk;"r.1tion: (10) for an exploratory or stratigraphic test well a seismic retraction or reflection analysis as required by 20 AAC 25.061(a)/ NI 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 must be accompanied by eaä7 of t77e following item!:>~ except for an item already on file with the commission and identified in the application: (1.1) for a well drilled from an oft.c.,1Jore platform/mobile bottom-founded structureI' jac.*-up rigl' or float"]g drilling vef:J"5"e1, an analYf:Jis of seabed condItions as required by 20 MC25~061(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 aCLìJmpanied by each of the following item~ except for an it(·?m already 0/7 file wIth the commif:::iion and Identified Ii? the application: (12) ev¡(jencc s'fJowing tbat the requirements of 20 MC 25.025 (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 PelTfJlt to Dtill must be acr.."ompanied by each or the following item~ exæpt for an item already on me with the commission and Identified i/7 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 9-5/8" s\.lrface casing point according to directional plan. No LWD logging equipment required. / 4. Run and cement 9-5/8" 40#, L -80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surfa~. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. /'" 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill 8-1/2" hole to total depth according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron. Run 7" 26# L-80 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#, L-80 8rd EUE 8rd-Mod completion assembly wi SAB-3 permanent packer and PBR. Set packer 350' above top planned perforation, shear out of PBR, P/U tubing hanger, and --- land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi. ./. Burst shear valve for freeze protect. 8. 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-80 BTCM casing must be top-set above the Kuparuk C sand, 6 1/8" hole will be Š drilled to total depth according to the directional plan and a 3 V2" 9.3# L-80 SLHT liner will be ran and cemented across the productive interval. The cement bond log will be done after moving the rig off the well. I 1 V j . ~ .~~ ~ J L 3$-22 PERMIT IT. DOC Page 6 of 7 Printed: 16-Jan-03 ) APIJ.....)¡on for Permit to Drill, Well 3S-22 Revision No.O Saved: 16-Jan-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 Dnll mustc be accompanied by each of the fÒllowíng items, except fÒr an item already on file wIth the commíSSìÓn and Identified in the application: (14) a general description of how the operator p/'':;J!7S to dispose of dril/ir7g mud and cuttings and a statement of whether the operator Ji1tends to request authorization under 20 AAC 2.5~080 for an annular disposaloperatlÒI7 in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 35 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 35-22 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 =- G ^/- 3$-22 PERMIT IT. DOC Page 7 of 7 Printed: 16-Jan-03 --..- ~.-~ ~ ~ r- Sperry-Sun Drilling Services ConocoPhi//ips A/ask Western North Kupa _/ a :::0 ~"= !;'J oposal Report 12 January, 2003 Surface Coordinates: 599386û.51 N, 476032.63 E (YiP 23'39.6786" Nj 150" 11' 42.0186" W) Grid Coordinate System: NAü27 Alaska State Planes, Zone 4 Kelly Bushing: 56. 10ft above Mean Sea Level .-' ;'~~:~~~j Ai<b¡¡-~~Ç~~~' Proposal Ref: pro 10008 Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-22 Plan - 3S-22 (wp03) ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings ment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -56.10 0.00 0.00 N 0.00 E 5993860.51 N 0.00 SHL (2556' FNL & 1227' FEL, 8EC 18- T12N - R8E) 100.00 0.000 0.000 43.90 100.00 O.OON 0.00 E 5993860.51 N 0.00 200.00 0.000 0.000 143.90 200.00 0.00 N 0.00 E 5993860.51 N 0.00 220.00 0.000 0.000 163.90 220.00 0.00 N 0.00 E 5993860.51 N 0.00 Begin Dir @ 2.0°/1 o Oft (in 12-1/4" Hole): 220.00tt MD, 220.00tt TVD 300.00 1.600 225.000 243.89 299.99 0.79 S N 2.000 0.89 400.00 3.600 225.000 343.78 399.88 .3N 476028.62 E 2.000 4.48 -' 500.00 5.600 225.000 443.45 499.55 50.87 N 476022.93 E 2.000 10.85 C) 600.00 7.600 225.000 542.79 598.89 993842.77 N 476014.78 E 2.000 19.97 700.00 9.600 225.000 641.66 697.76 5993832.23 N 476004.17 E 2.000 31.83 ~. 225.000 661.37 717.47 5993829.83 N 476001.76 E 2.000 34.53 Increase in Dir Rate @ 4.00/100ft: ~-;~... _TJ··~ 720.00 10.000 ~''- 720.00tt MD, 717.47ft TVD ~ ~.~ 800.00 12.453 235.634 739.84 795.94 ;~O~i...~~;~~'- 42.81 W 5993820.09 N 475989.69 E .......--4.000 47.74 ~ 900.00 15.892 244.044 836.79 892.89~: 64.03 W 5993808.07 N 475968.43 E 4.000 70.35 "-'--.-..-..-,-..-....-......i 1 000.00 19.542 249.453 932.04 988.14c' 92.01 W 5993796.30 N 475940.41 E 4.000 99.64 :t.c,;:::, 1100.00 23.303 253.195 1025.12 ,!.Q81.22 126.62 W 5993784.81 N 475905.77 E 4.000 135.47 r-- 1200.00 27.129 255.939 1115~57 11(-1<"~7 167.69 W 5993773.68 N 475864.66 E 4.000 177.66 ·-i-~-:- 1300.00 30.997 258.046 .. ·1202..~7 - - 1259.07 98.24 8 215.02 W 5993762.96 N 475817.30 E 4.000 226.00 1400.00 34.891 259.726 1286.87 1342.97 108.68 S 268.37 W 5993752.69 N 475763.91 E 4.000 280.26 1500.00 38.805 261..1 06 1366.88 1422.98 118.638 327.49 W 5993742.93 N 475704.76 E 4.000 340.18 1600.00 42.732.· 262.269 1442.60 1498.70 i 28.04 S 392.10 \V 5993733.72 N 475640.12 E 4.000 405.46 1665.93 45.327 262.946 1490.00 1546.10 133.93 S 437.54 W 5993727.98 N 475594:67 E 4.000 451.27 B. Parrnatrost 1700.00 46.670 2()3.272 1513.67 1569.77 136.87 8 461.87 W 5993725.12 N 475570.33 E 4.000 475.78 1715.84- 47 ;294 263.418 1524.47 1580.57 138.21 8 473.37 W 5993723.81 N 475558.82 E 4.000 487.36 End Dir, 8tart Sail @ 47.3° : 1715.84ft MD, 1580.58ft TVD 1800.00 47.294 263.418 1581.56 1637.66 145.30 S 534.81 W 5993716.92 N 475497.36 E 0.000 549.20 ~ 1900.00 47.294 263.418 1649.38 1705.48 153.72 S 607.81 W 5993708.73 N 475424.33 E 0.000 622.67 2000.00 47.294 263.418 1717.20 1773.30 162.158 680.81 W 5993700.55 N 475351.31 E 0.000 696.15 2100.00 47.294 263.418 1785.03 1 841 .13 170.57 8 753.81 W 5993692.36 N 475278.28 E 0.000 769.62 2200.00 47.294 263.418 1852.85 1908.95 178.998 826.81 W 5993684.17 N 475205.25 E 0.000 843.10 2300.00 47.294 263.418 1920.67 1976.77 187.42 8 899.81 W 5993675.98 N 475132.23 E 0.000 916.57 2350.61 47.294 263.418 1955.00 2011.10 191.688 936.75 W 5993671.84 N 475095.27 E 0.000 953.76 1. West 8ak 2400.00 47.294 263.418 1988.50 2044.60 195.84 8 972.81 W 5993667.79 N 475059.20 E 0.000 990.05 12 January, 2003 - 18:09 Page 2 of7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-22 Plan - 3S-22 (wp03) ConocoPhilUps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings ment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 2500.00 47.294 263.4 18 2056.32 2112.42 204.26 S 1045.81 W 5993659.60 N 1063.52 2600.00 47.294 263.418 2124.15 2180.25 212.68 S 1118.81 W 5993651.42 N ~ 1137.00 2700.00 47.294 263.418 2191.97 2248.07 221.11 S 1191.81 W 5993643.23 N 1210.47 2800.00 47.294 263.418 2259.79 2315.89 229.53 S 1264.81 W 5993635.04 N 1283.95 2900.00 47.294 263.418 2327.62 2383.72 237.95 S 1337.81 W 5993626.85 N 1357.42 3000.00 47.294 263.418 2395.44 2451.54 246.37 S 21.04 E 0.000 1430.90 3006.72 47.294 263.418 2400.00 2456.10 246.94 S 474616.13 E 0.000 1435.84 B. West Sak 3100.00 47.294 263.418 2463.26 2519.36 254.80 S 474548.01 E 0.000 1504.37 _/ 3171.00 47.294 263.418 2511.42 2567.52 260.78 S 474496.17 E 0.000 1556.54 9-5/8" Csg pt ... Drill out 8-1/2" Hole C) 3171.00ft MD, 2567.52ft TVD 9 5/8" Casing =a 3200.00 47.294 263.418 2531.09 2587.19 5993602.28 N 474474.99 E 0.000 1577.85 --- ~:) 3272.1 2 47.294 263.418 2580.00 2636.10 1609.45 W 5993596.38 N 474422.32 E 0.000 1630.83 C-80 (K-10) 3300.00 47.294 263.418 2598.91 2655.01: 1629.81 W 5993594.10 N 474401.96 E 0.000 1651.32 -- 3400.00 47.294 263.418 2666.73 27?,~:8 1702.81 W 5993585.91 N 474328.93 E 0.000 1724.79 -~..~ ~ 3500.00 47.294 263.418 2734.56 . 279Æfl6 1775.81 W 5993577.72 N 474255.91 E 0.000 1798.27 :t:> 3600.00 47.294 263.418 2802.38 ~~\~28SªÆ~8 1848.81 W 5993569.53 N 474182.88 E 0.000 1871.74 r-- r ~ 3700.00 47.294 263.418 c?8""O£?1 ,. o 292~:31 305.33 S 1921.81 W 5993561.34 N 474109.85 E 0.000 1945.22 3800.00 47.294 263.418 293a~ø$ i/,/é; 2994.13 313.75 S 1994.81 W 5993553.15 N 474036.83 E 0.000 2018.69 3900.00 47.294 263.4 Ht .3005.85 . 3061.95 322.18 S 2067.81 W 5993544.96 N 473963.80 E 0.000 2092.17 4000.00 47.294 263:4-18'" 3073.68 3129.78 330.60 S 2140.81 W 5993536.78 N 473890.77 E 0.000 2165.64 4100.00 47.294 263.4.18 3141.50 3197.60 339.02 S 2213.81 W 5993528.59 t~ 473817.75 E 0.000 2239.12 4200.00 47.294 263.418: 3209.32 3265.42 347.44 S 2286.81 'vV 5993520.40 N 473744.72 E 0.000 2312.59 4300.00 47.294: 263.418 3277.15 3333.25 355.87 S 2359.81 W 5993512.21 N 473671.69 E 0.000 2386.07 4400.00 47.294 263.418 3344.97 3401.07 364.29 S 2432.81 W 5993504.02 N 473598.67 E 0.000 2459.54 4500.00 47.294 263.418 3412.79 3468.89 372.71 S 2505.81 W 5993495.83 N 473525.64 E 0.000 2533.02 4600.00 47.294 263.418 3480.62 3536.72 381.13 S 2578.81 W 5993487.65 N 473452.61 E 0.000 2606.49 "-'./ 4700.00 47.294 263.418 3548.44 3604.54 389.56 S 2651.81 W 5993479.46 N 473379.59 E 0.000 2679.97 4800.00 47.294 263.418 3616.27 3672.37 397.98 S 2724.81 W 5993471.27 N 473306.56 E 0.000 2753.44 4900.00 47.294 263.418 3684.09 3740.19 406.40 S 2797.81 W 5993463.08 N 473233.53 E 0.000 2826.92 5000.00 47.294 263.418 3751.91 3808.01 414.82 S 2870.81 W 5993454.89 N 473160.51 E 0.000 2900.39 5100.00 47.294 263.418 3819.74 3875.84 423.25 S 2943.81 W 5993446.70 N 473087.48 E 0.000 2973.87 5200.00 47.294 263.418 3887.56 3943.66 431.67 S 3016.81 W 5993438.51 N 473014.45 E 0.000 3047.34 5300.00 47.294 263.418 3955.38 4011.48 440.09 S 3089.81 W 5993430.33 N 472941.43 E 0.000 3120.82 5400.00 47.294 263.418 4023.21 4079.31 448.52 S 3162.81 W 5993422.14 N 472868.40 E 0.000 3194.29 5408.54 47.294 263.418 4029.00 4085.10 449.23 S 3169.04 W 5993421.44 N 472862.16 E 0.000 3200.57 C-40 (K-3) 5500.00 47.294 263.418 4091.03 4147.13 456.94 S 3235.81 W 5993413.95 N 472795.37 E 0.000 3267.77 12 January, 2003 - 18:09 Page 3 of7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-22 Plan - 35-22 (wp03) Western North 510pe Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) eft) (ft) (ft) 5600.00 47.294 263.418 4158.85 4214.95 465.36 S 3308.81 W 5993405.76 N 5700.00 47.294 263.418 4226.68 4282.78 473.78 S 3381.81 W 5993397.57 N. 5800.00 47.294 263.418 4294.50 4350.60 482.21 S 3454.81 W 5993389.38 N 5900.00 47.294 263.418 4362.33 4418.43 490.63 S 3527.81 W 5993381.20 N 6000.00 47.294 263.418 4430.15 4486.25 499.05 S 3600.81 W 5993373.01 N 6100.00 47.294 263.418 4497.97 4554.07 507.47 S 3673.81 W 57.21 E 6200.00 47.294 263.418 4565.80 4621.90 515.90 S 374 1 472284.19 E 6300.00 47.294 263.418 4633.62 4689.72 524.32 S 38 1 472211.16 E 6400.00 47.294 263.418 4701.44 4757.54 532.74 S c;<;"~1J)9 ~"..'~iC, ....< 3 40.25 N 472138.13 E a 6500.00 47.294 263.418 4769.27 4825.37 541. 16 S·>~':: ~5.8rW~~"'c:S993332.06 N 472065.11 E ~--- --...." 6600.00 4 7 .294 263.418 4837.09 4893.19 .C· 4038.81 W 5993323.88 N 471992.08 E -J.:. j 6700.00 47.294 263.418 4904.91 4961.01 111.81 W 5993315.69 N 471919.05 E ~.' {; 6800.00 47.294 263.418 4972.74 5028.84 4184.81 W 5993307.50 N 471846.03 E ,.) 6900.00 47.294 263.418 5040.56 5096.66" 4257.81 W 5993299.31 N 471773.00 E -'. 7000.00 47.294 263.418 5108.39 5164.4 4330.81 W 5993291.12 N 471699.97 E áCr:;:_. ...... 7061.36 47.294 263.418 5150.00 ';:~gÇJÇf~1 0 588.44 S 4375.60 W 5993286.10 N 471655.17 E '41< ~_-_.J;..A 7100.00 47.294 263.418 517ô:2-' '3} 5~~~1 591.70 S 4403.81 W 5993282.93 N 471626.95 E r-- 7200.00 47.294 263.418 .~244,b3 ;'.' 530tJ. i 3 600.12 S 4476.81 W 5993274.74 N 471553.92 E 7300.00 47.294 263.418 . '531 t~ªß .~ 5367.96 608.54 S 4549.81 W 5993266.56 N 471480.89 E 7400.00 47.294 263.418 . ·5379.68 5435.78 616.97 S 4622.81 W 5993258.37 N 471407.87 E 7500.00 47.294, 263.4.18 5447.50 5503.60 625.39 S 4695.81 W 5993250.18 r-..J 471334.84 E 7533.17 47.294 ,263.418· 5470.00 5526.10 628.18 S 4720.02 W 5993247.46 N 471310.62 E 7600.00' 47.294 263.418 5515.33 5571.43 633.8i S 4768_81 VJ 5993241.99 N 471261.81 E 77oo.do '. 47.29A: 263.418 5583.15 5639.25 642.23 S 4841.81 W 5993233.80 N 471188.79 E 7798.56 47:294 263.418 5650.00 5706.10 650.54 S 4913.76 W 5993225.73 N 471116.81 E 7800.00 47.294 263.418 5650.98 5707.08 650.66 S 4914.81 W 5993225.61 N 471115.76 E 7900.00 47.294 263.418 5718.80 5774.90 659.08 S 4987.81 W 5993217.43 N 471042.73 E 7960.75 47.294 263.418 5760.00 5816.10 664.20 S 5032.16 W 5993212.45 N 470998.37 E 8000.00 47.294 263.418 5786.62 5842.72 667.50 S 5060.81 W 5993209.24 N 470969.71 E 8063.96 47.294 263.418 5830.00 5886.10 672.89 S 5107.50 W 5993204.00 N 470923.00 E ConocoPhillips ment 3341 .24 3414.72 3488.19 3561.67 3635.14 0.000 3708.62 0.000 3782.09 0.000 3855.57 -..-' 0.000 3929.04 0.000 4002.52 0.000 4075.99 0.000 4149.47 0.000 4222.94 0.000 4296.42 0.000 4369.89 0.000 4414.97 Top Morraine 0.000 4443.37 0.000 4516.84 0.000 4590.32 0.000 4663.79 0.000 4737.27 0.000 4761.64 Top HRZ 0.000 4810.74 0.000 4884.22 0.000 4956.63 Base HRZ 0.000 4957.69 -' 0.000 5031.17 0.000 5075.80 K-1 0.000 5104.64 0.000 5151.63 TARGET: 8063.96ft MD, 5886.1 Oft TVD (2049' F8L & 1528' FEL, See T12N-R7E) Kuparuk 38-22 (Geo- Target), 150.00 Radius Current Target 12 January, 2003 - 18:09 Page 4 of7 DrillQuest 3.03.02.002 C ::0 --- ~ ---- ~ ~ ..... co I"';'~ r--- Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-22 Plan - 35-22 (wp03) Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 8100.00 47.294 263.418 5854.45 5910.55 675.92 S 5133.81 W 5993201.05 N 8105.24 47.294 263.418 5858.00 5914.10 676.37 S 5137.64 W 5993200.62 N 8200.00 47.294 263.418 5922.27 5978.37 684.35 S 5206.81 W 5993192.86 N 8300.00 47.294 263.418 5990.09 6046.19 692.77 S 5279.81 W 5993184.67 N 8400.00 47.294 263.418 6057.92 6114.02 701.19 S 5352.81 W 5993176.48 N 8405.48 47.294 263.418 6061.63 6117.73 701.65 S N All data is in Feet (US) unless otherwise stated. Directions and coordinates ar Vertical depths are relative to RKB = 56.1' MSL. Northíngs and Eastings ar Global Northings and Eastings are relative to NAD27 Alaska State Planes," The Dogleg Severity is in Degrees per 100 feet (US). y'.'''' . Vertical Section is from 2556' FNL, 1221' FEL and calculated al®g a Based upon Minimum CUNature tvt:·,:. (;¡I,:ijI3Iion ~ ;¡t <1 Meé:lsurecJ Oepth Of 8405.48ft., The Bottom Hole Displacement is 540¿.5ìrl., In Ine Direction of 26:2.538 (True). Comments Meaaured Depth (ft) s ta,t ion Coo r din ate s Northings Eastings (ft) (ft) Comment -TVD (ft) ConocoPhilDps ment 5178.12 5181.97 Miluveach 5251.59 5325.07 5398.54 0.000 5402.57 Total Depth: 8405.48ft MD, 6117.73ftTVD(2020'FSL& iT FEL, SEC. 13-T12N-R7E) ~__ 7" Casing 0.00 220.00 720.00 1715.84 3171.00 SHL (2556' FNL & 1227' FEL, SEC. 18- T12N - R8E) Begin Dir @ 2.00/100ft (in 12-1/4" Hole): 220.0Oft MD, 220.0Oft TVD Increase in Dir Rate @ 4.00/100ft : 720.00ft MD, 717.47ft TVD End Dir, Start Sail @ 47.3° : 1715.84ft MD, 1580.58ft TVD 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 3171.00ft MD, 2567.52ft TVD 0.00 0.00 N 0.00 E 220.00 0.00 N 0.00 E 717.47 30.78 S 30.78 W 1580.58 138.21 S 473.37 W 2567.52 260.78 S 1535.64 W 5886.10 672.89 S 5107.50 W 6117.73 701.65 S 5356.81 W ~ 8063.96 8405.48 TARGET: 8063.961t MD, 5886.1 Oft TVD (2049' FSL & 1528' FEL, See 13-T12N-R7E) Total Depth: 8405.48ft MD, 6117.73ft TVD (2020' FSL & 1778' FEL, SEC. 13-T12N-R7E) 12 January, 2003 - 18:09 Page 5 of7 DrillQuest 3.03.02.002 C) :.t:J ~""- ~ ""'"-... ~..: '-"II. L~~ r-- Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-22 Plan - 3S-22 (wp03) Western North Slope Formation TODS Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (ft) 1665.93 1546.10 1490.00 133.93 S 2350.61 2011.10 1955.00 191.68 S 3006.72 2456.10 2400.00 246.94 S 3272.12 2636.10 2580.00 269.29 S 5408.54 4085.10 4029.00 449.23 S 7061.36 5206.10 5150.00 588.44 S 7533.17 5526.10 5470.00 628.18 S 7798.56 5706.10 5650.00 650.54 S 7960.75 5816.10 5760.00 664.20 S 8063.96 5886.10 5830.00 672.89 S 8105.24 5914.10 5858.00 CasinCl details Fro m Measured ,Vertical·'· Depth . Depth ' (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surtace::> <Surface> 3171.00 2567.52 <Surface> <Surface> <Run-TO> <Run-TO> 12 January, 2003 - 18:09 Eastings (ft) 437.54 W 936.75 W 1415.71 W 1609.45 W 3169.04 W - - - -.- .~ c-'5137.64-\¡Ij Casing Detail 9 5/8" Casing 7" Casing ConocoPhilUps Dip Up-Dip Formation Nam Angle Dirn. 0.000 0.000 0.000 0.000 0.000-- ~'q~R09~-c: o :Q{)O o. 0.0 0.000 0.000 ;~~:~~ ~ ~: ~~~~~t 359. 816;-._,ª. W~t Sak,;:~è ~99.81f}£cð~Ç~0 C(!<21 0) 359--,-8nJx~~Q (K-;:3) 359':8;16 359.816 359.816 359.816 359.816 359.816 Page 6 of 7 C~:.Top Morraine Top HRZ Base HRZ K-1 Kuparuk Miluveach .----- - --' DrillQuest 3.03.02.002 C) ::J:1 ~-:.~::;;-.... ~ :.\w:~. } ~~;':..q ~~ :i~~ r--- Western North Slope Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 35-22 Plan - 35-22 (wp03) Tarøets associated with this well"ath Target Name 38-22 (Geo- Target) 12 January, 2003 - 18:09 Target TVD (ft) Mean Sea Level/Global Coordinates: Geographical Coordinates: _ Target Page 70f7 5107.50 W 470923.00 E 150014' 11.6065" W ConocoPhillips Target Target Shape Type Circle Current Target -.-' ~ DrillQuest 3.03.02.002 I 2000~':-'~1,"'- - I ~l:-J*10"- - - - ~JiT":':' i~'~'!·:_- - - - -- ". . ',- . 9-5/8" Csg PI. MD: 3171.0011 TVD: 2567.5211 3000 - I I I RKB Elevation : I North Reference: Units: 4000- """_,,+,~, _ _ _ _ _ _ _ _ _ _ _ __<'" _ _ _ __ _ __ I ~ ø/ I ~~o:- I I i,.!,\:.",,;;-:. I\ït'_""¡,·¡;---· - - - - - - - TAR~ET: 8063~6ftMD. ~886.10ft;V~- ---,- ."..~ _ _ _ _ _ _ _ _ _ (2049~FSL & 1~8' FEL. ~ec~1~N-R7E) _ _ -::J!$' _ _ _ _ _ _ _ _ _ _ ~~I~'~____________________ ~,y'T><f" II ;,.,!, Iii!! !\ªf' .ê' ii, !i'I' 15 r~l "1"','1_;;-.,;'1. [ ;-;~!JF -. J~-;'-'-;-;~;-;-;-;-;--- .!: 6000 _ ,..' . , -. -" ... ~í¡IU".Lt. TVD,5<;1".](Ij-' I C) ::::J (/) :1.:] ~ T""" -...,. , <Ó Ç) L{) II CO --. .. ~ --~::t fE, ,.ê:-_ .!:: ~ õ.. Q) r-- 0 ëU ü t Q) > o~--- SHL (2556' FNL & 1227' FEL, SEC. 18- T12N - R8E) / ________ Begin Oir @ 2.00/100ft (in 12-1/4" Hole): 220.00ft MO, 220.00ft TVO 1000 - f§f'c;!- ':--- I I I -:~r-:; +":¡li" End Oir, Start Sail @ 47.3° : 1715.84ft MO, 1580.58ft TVO Increase in Oir Rate @ 4.00/100ft: 720.00ft MD, 717.47ft TVO cØ' >J»..~-------------- 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 3171.00ft MO, 2567.52ft TVD 5000 - ,t:: o o o a; ëñ <.) (/) Total Depth: 8405.48ft MD, 6117.73ft TVD (2020' FSL & 1778' FEL, SEC. 13-T12N-R7E) o I 1000 I 3000 I 4000 I 5000 I 2000 Scale: 1 inch = 1000fl DrillQuest 3.03.02.002 __ììli. ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 35-22 (wp03) ~ Reference is True North Current Well Properties Well: 3S-22 HorizontaJ Coordinates: Ref. Global Coordinates: Ref. Structu re : Ref. Geographical Coordinates: 5993860.51 N, 476032.63 E 16.16 N. 422.42 W 70° 23' 39.6786" N, 150011' 42.0186" W 2556' FNL & 1227' FEL, SEC. 18- T12N - R8E I 56.1 Oft above Mean Sea Level True North Feet (US) ; ~'aij s~ .¡u.y...SLJr1 ~~Jt;""I~~'_..~~J!-~.",tr;~ .,JiI,. A -H!iíftil:1í.i<rt~CQ(~âlft!l ---- --= > :==:=: - ~~' - -;:G;g Pt. ~ - _2 - . - . ,,,'- MD: 8405.48ft 3S-2 (Ceo-Target) TVD: 6117.7311 Circle, Radius: 150.0Qft 5886.10 TVD, 672.89 S, 5107.50 W I 6000 I 7000 (¡j «i (,) (f) õ o I'-- II .s:::. - -1400 .~ - -700 -- -700 --...-' Eastin9S o I -700 I -2800 I -3500 Total Depth: 8405.48ft MD, 6117.73ft TVD (2020' FSL & 1778' FEL, SEC. 13-T12N-R7E) I -4900 I -1400 I -2100 o I I -700 I -1400 I -2800 I -3500 I SHL (2556' FNL & 1227' FEL, SEC. 18- T12N - RaE) , \ Begin Dir@2.00/100ft(in12-114"HOle):220.00ftMD'220.000TVD\I, Increase In o;r Rate @ 4.001100ft , 720.00' M0,717.47ft T~ ~ \ I End D;r, Start Sail @ 47.3" , 1715.84" MO, 1580.58nTVO ~ ~ ~ 0-- - - - - - - - - - - - - -=- ;0-:-:::- ,: ~. ~ -:::- '-1.=. :?:::;:-::= ~!;:- - - - ~--~~-~ - - --;;~ - - ~ 0 I' ') (. / OJ-,.;1.... v;:,g.-, '-"I"vm8-·" Ho·", "1.1 -.1\.11'..'''-' '::vO¡ '-'''-I' "'" ------ {----- I 1~L_ ( 1tO.. tlrt..[d) . ~ U' . --. . - . ~. 1 . ~ ......... 'J..;, (lI(h,Radlll\./'O,lilijl ~.... t \.0. 700 .'SS(,./Ii/I'/),672.S9S,_'/1/7.5(J\\ ~,- 'Iz><; 7'b0'b.? lbq . \.oQ- <:1<-'bo . ~'b.?' I , 3&-22 (wp03) , 7>.z¡. 3700 ·lbq I . ~ 'Ir<:1a ·~o'b.? 9-5/8" Csg PI. Q \ 'C.-~_ 1Q0'b.? ~ MD:3171.00ft . t \'. ~ ~;>0o ~Olbq TVD: 2567.52ft I , 'Iz> S700 "tI1 lir>--- . s. .0,» I 'C.s ·"'0'b.? 00, -~ . '~ ~ I TARGET" 8063.96ft MD. 5886.1 Oft TVD (2049' FSL & 1528' FEL. See 13-T12N-R7E) I I -2100 I APPROVED Plan 56.1 Oft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: 5993860.51 N, 476032.63 E 16.16 N. 422.42 W 700 23' 39.6786" N, 1500 11' 42.0186" W 2556' FNL& 1227' FEL, SEC. 18- T12N - R8E Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates: Current Well Properties 38-22 Well: Reference is True North &11...¡I~Y-~-J1 gJ!I~I:d!j,~_____~_~~YJoc;~J! A. ~U~rlQft Cq.mØ~H1!t DrillQuest 3.03.02.002 Scale: 1 inch", 700ft I -4200 I -5600 -700 - 7" Csg PI. MD: 8405.4811 TVD: 6117.7311 700 - -4200 I -4900 I Scale: 1 inch = 700ft -5600 I ConocóPhillips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 35-22 (wp03) (¡j «i (,) (f) .:= o o ..... II .s:::. (,) .£ -1400- (/) g1 :£ o z <::) ::J:J --- ~~ ---.... ~....~3 ""~ ~ r-- ConocoPhillips Alaska, Inc. 35-22 (wp03) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft) ---' 0.00 0.00 0.00 -56.10 0.00 0.00 N 0.00 E 5993860.51 N 476032.63 E 0.00 0.00 SHL 220.00 0.00 0.00 163.90 220.00 0.00 N 0.00 E 5993860.51 N 476032.63 E 0.00 0.00 Begin Dir @ 2.00/100ft (in 12-1/4" Hole) 720.00 10.00 225.00 661.37 717.47 30.78 S 30.78 W 5993829.83 N 476001.76 E 2.00 34.53 Increase in Dir Rate @ 4.00/100ft C~ 1665.93 45.33 262.95 1490.00 1546.10 133.93 S 437.54 W 5993727.98 N 475594.67 E 4.00 451.27 B. Permafrost 1715.84 47.29 263.42 1524.4 7 1580.57 138.21 S 473.37 W 5993723.82 N 475558.82 E 4.00 487.36 End Dir; Start Sail 2350.61 47.29 263.42 1955.00 2011.10 191 .68 S 936.75 W 5993671.84 N 475095.27 E 0.00 953.76 T. West Sak -'c 3006.72 47.29 263.42 2400.00 2456.10 246.94 S 1415.72 W 5993618.11 N 474616.13 E 0.00 1435.84 B. West Sak {' 3171.00 47.29 263.42 2511.42 2567.52 260.78 S 1535.64 W 5993604.66 N 474496.17 E 0.00 1556.54 9-5/8" Csg Pt ... Drill out 8-1/2" Hole 3272.12 47.29 263.42 2580.00 2636.10 269.29 S 1609.45 W 5993596.38 N 474422.32 E 0.00 1630.83 C-80 (K-10) ~. 5408.54 47.29 263.42 4029.00 4085.10 449.23 S 3169.04 W 5993421.44 N 472862.16 E 0.00 3200.57 C-40 (K-3) ...., 7061.36 47.29 263.42 5150.00 5206.10 588.44 S 4375.60 W 5993286.10 N 471655.17 E 0.00 4414.97 Top Morraine r::J r---. 7533.17 47.29 263.42 5470.00 5526.10 628.18 S 4720.02 W 5993247.46 N 471310.62 E 0.00 4761.64 Top HRZ 7798.56 47.29 263.42 5650.00 5706.10 650.54 S 4913.76 W 5993225.73 N 471116.81 E 0.00 4956.64 Base HRZ 7960.75 47.29 263.42 5760.00 5816.10 664.20 S 5032.16 W 5993212.45 N 470998.37 E 0.00 5075.80 K-1 8063.96 47.29 263.42 5830.00 5886.10 672.89 S 5107.50 W 5993204.00 N 470923.00 E 0.00 5151.63 TARGET 8105.24 47.29 263.42 5858.00 5914.10 676.37 S 5137.64 W 5993200.62 N 470892.85 E 0.00 5181.97 Miluveach 8405.48 47.29 263.42 6061.63 6117.73 701.65 S 5356.81 W 5993176.03 N 470673.60 E 0.00 5402.57 Total Depth; 7" Casi ng Pt. .----- Company: , Field: , ,R,éfer~nce, Site,: , Rèference Weill Réferë,nce WeUpath: F;'hillips AI~$kå.lnc. Kuparuk River Unit Kuparuk 3SPad Plan: 35722, 'Plan:3S-22 ) SPERRY_SUN DES ) Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.10 to 8405.48 ft Maximum Radius: 1037.74 ft Survey Program for Definitive Wellpath Date: 5/15/2002 Validated: No Planned From To Survey ft ft 28.10 900.00 900.00 8405.48 Casing Points MD fir,' 3171.00 8405.48 '<TVD",' , ft' 2567.41 6117.25 Planned: 3S-22 (wp03) V8 Planned: 3S-22 (wp03) V8 Uhuoeter . in.' 9.625 7. 000 Date: i/12A2003 Time: '1.4:59:22 , C07ordinate(NE}Retereu(:e::" VertiCal (1'yD) áefeteTme: Well:Plan:3S-22,TrljeNorth AKa";55~~'MSL55.8· ' Db: Principal Plan & PLANNED PROG RAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Referm)(:I~: Error 1:1¡i[(JIdlel: Scan JVDøthod: Error SUI"æace: Version: 4 Toolcode T~lol Name CB-GYRO-SS MWD Camera based gyro single shot MW D - Standard 12.250 8.500 95/8" 7" Hole $ize in Summary ~~~~~,~7+-~· ..,u~~.~. ~ .'. ()ttset'vv~lIpritll ,'~~ ~7~:,··~~~·h·-~~~~~~~, " '$i~è, """ , "',Well' ,',' ,", "', '" 'Well~åth' Exploration 2001 Kuparu k 3S Pad Kuparu k 3S Pad Kuparu k 3S Pad Kuparu k 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 35 Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 35 Pad Kuparuk 3S Pad Palm 1 3S-14 3S-18 3S-26 3S-26 Plan: 35-15 Plan: 3S-16 Plan: 35-17 Plan: 3S-17 Plan: 3S-19 Plan: 3S-19 Plan: 35-20 Plan: 35-21 Plan: 3S-21 Plan: 35-23 Plan: 3S-24 Palm 1 WP01 V1 Plan: P 3S-14 V2 3S-18 V4 3S-26 V2 3S-26A V3 Plan: 35-15 V1 Plan: 3 Plan: 3S-16 V2 Plan: 3 Plan: 35-17 VO Plan: 3 Plan: 35-17F V1 Plan: Plan 3S-19F V2 Plan: 3 Plan: 3S-19 V1 Plan: 3 Plan: 35-20 V1 Plan: 3 Plan: 3S-21 V1 Plan: 3 Plan: 35-21F V2 Plan: Plan: 35-23 V1 Plan: 3 Plan: 3S-24 V1 Plan: 3 ;Reference ()ffs¢t, (::tlt'.Ctr'No~(;o ^.l~~~le~ ,'" i'I'," ,'".,.,', ",,',:' ,:,:: '::"',,:" ':':: ',.':',',,:1 ·MO" ,'. MD "'" ][:IIi~¡ll.anceArea. Deylat.on' . W~rÎ1ing I · I Jt iff ' ff' ,,' "1ft . 'ft" 903.10 900.00 3"1.86 No Offset Errors /' 248.51 250.00 1.59.94 4.47 155.47 Pass: Major Risk 492.63 500.00 76.82 7.63 69.38 Pass: Major Risk 850.35 850.00 :24.69 13.13 11.61 Pass: Major Risk 850.35 850.00 24.69 13.13 11.61 Pass: Major Risk 296.77 300.00 '140.18 6.04 134.13 Pass: Major Risk 296.94 300.00 '120.82 6.08 114.74 Pass: Major Risk 442.82 450.00 '100.48 7.91 92.59 Pass: Major Risk 442.82 450.00 100.48 7.91 92.59 Pass: Major Risk 494.52 500.00 58.83 8.60 50.27 Pass: Major Risk 494.52 500.00 58.83 8.60 50.27 Pass: Major Risk 889.66 900.00 38.28 16.24 22.72 Pass: Major Risk 349.17 350.00 20.93 6.39 14.55 Pass: Major Risk 349.17 350.00 :2:0.93 6.39 14.55 Pass: Major Risk 450.96 450.00 20.07 7.90 12.18 Pass: Major Risk 351.51 350.00 41.43 6.35 35.08 Pass: Major Risk C ~ . (~ .~ f" , n L . ~i j Li i j '~) j.~ . WEILP ATH DErAILS PhIL 3S·22 N7ES RKB ~ 55.S' MSL 55.8Oit ~ -t~~ ~~m"fvD 0.00 0.00 0.00 Ri<!: Ref. o.tuJÌÍ: V.Section Ang1< 262.6' COMP A"<Y DErAILS P~oInc. KúpMU!t Cakubtion Me-Ihod: MiniIrwn CU!\~illre &ror Svslèm: ISCWSA SC~Iùí<1hod: Trav Cylinder North &ror Surîaœ: Ðliptic~ -t Casing Wt1111.ÛJgMerl1od: R~B¡:;sed ANTI-COLLISION SETTING: Interval: 50.00 To: 8405.48 Reference: Plan: 35-22 (wp03) Interpolation MethodMD Depth Range From: 28.10 Maximum Range: 1037.74 Slot KIA IongJIUd< 150'11'~2.016W Latil:UI 70'H39.679~ WElL DErAILS ~onhm.g &sting 5993860.59 476032.71 +fl·W ·~22.39 +SJ- 26 ~am: PM 3S. From Colour To MD 0-300 300 - 500 500 - 700 700 - 900 900 1100 1100 - 1300 1300 1500 1500 2000 2000 - 2500 2500 - 3000 3000 - 3500 3500 - 4000 4000 - 4500 4500 - 5000 5000 - 5500 5500 - 6500 6500 - 7500 7500 8500 From Colour To MD 0-300 300 - 500 500 - 700 700 - 900 900 1100 1100 - 1300 1300 1500 1500 2000 2000 - 2500 2500 - 3000 Pi 3000 - 3500 ftT/: 3S-19 3500 - 4000 ~ ,(PJftT/:~l~ 4000 - 4500 ......' ~t--.... 'n3--:~) 4500 - 5000 .~t\ ....""';i1l!~ [S;Z8 5000 - 5500 0& 5500 - 6500 'Z<f; 6500 ~ 7500 7500 8500 Tool CB-GYRO-SS MWD 4 Version SURVEY PROGRAM Validated No SurveylPlan Planned: 3S-22 (wpm) V8 Planned: 3S-22 (wp03) V8 5115/2002 Date Depth Fm Depth To 28.10 900.00 900.00 8405.48 (P~ .~ o 22, ~ -22.0 Plan: 3S-bJ -JPäg: 3S-23 -0 --5.0 -20.0 -15.0 -1U.1) -15.0 -20.0 --5.0 75 100 lsd°.5 o .,~ ---- -105 -100 -75 -100 -105 --50 -75 j --50 ( 38-22 (wp03) --- Approved Plan --- """"'12.0 Target VSee 0.00 0.00 34.44 487.20 5152.20 5403.00 TFaee 0.00 0.00 225.00 45.47 0.00 0.00 DLeg 0.00 0.00 2.00 4.00 0.00 0.00 +E/- W 0.00 0.00 -30.78 -473.47 -5108.09 -5357.25 SECTION DETAilS +N/-S 0.00 0.00 -30.78 -138.24 -673.04 -701.79 lVD 28.10 220.00 717.47 1580.66 5885.80 6117.25 Az 0.00 0.00 225.00 263.42 263.42 263.42 lne 0.00 0.00 10.00 47.30 47.30 47.30 MD 28.10 220.00 720.0U 1715.97 8064.19 8405.48 See 1 2 3 4 5 6 Centre to Centre Separation [10ft/in] [deg] vs Travelling Cylinder Azimuth (TFO+AZI) 3S (22) [deg] vs Centre to Centre Separation [50ft/in] Travelling Cylinder Azimuth (TFO+AZI ¡::: o .- ........ ro I-< ro p.. <U r./) ([) d :1_~ -..., .cQ ç-~ -,._'~ -~..~ ~ ~ r-- Plan: 3S- 22/Plan: 3S- 22 ~ ~ '---' 0.0 "Iii"" ""11111 100 150 200 Measured Depth [ft] Palm 1 (Palm 1 WPO 1) 3S-26 (3S-26A) Plan: 3S-17 (Plan: 3S-17F) Plan: 3S-21 (Plan: 3S-21) 3S-18 (3S-18) Plan: 3S-16 (Plan: 3S-16) Plan: 3S-19 (Plan: 3S-19) Plan: 3S-23 (Plan: 3S-23) 3S- 26 (3S- 26) Plan: 3S-17 (plan: 3S-17) Plan: 3S-20 (Plan: 3S-20) Plan: 3S-24 (plan: 3S-24) 3S-14 (3S-14) Plan: 3S-15 (Plan: 3S-15) Plan: 3S-19 (Plan 3S-19F) Plan: 3S-21 (Plan: 3S-21F) ) ) 35-22 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" CasinQ Interval Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation Risk Level Low M iti~ation Strateqy Monitor cellar continuously during interval. Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Moderate ( Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Moderate /' Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Low Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. 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 /' Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM I Mitiqation Strateqy 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. 35-22 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 OR" ~ 6 ". , ~:" t , ~,~ I 'I 1\;41JVf{;... Page 1 of 1 ) KRU - 35-22 Injector Proposed Completion Schematic Single Completion 16"x30" insulated I I ~ conductor @ ~ ~ ~ +/- 108' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ TAM9-5/8"Po~ Z ~ S~ Collar Stnd ~ ~ Grade BTC ~ ~ Threads (+/- ~ ~ '" ~ 1000'MDITVD) I ~ ~ ~ ~ ~ Surface csg. I ~ 9-5/8"40# L-BO I ~ BTC (3171' MD /.....,. ~ ~ 2568' TVD) ~ Casing point ~ 100'abovethe ~ C80 sand ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..J .:...~ .-:.) J C Sand Peñs (to be done after rig moves off) Production csg. 7" 26# L-8Q BTCM (+/- 8405' MD) J ï-¡ ._-,~ ~ ~ ~ ~ ~ ~ ~ ~. ~: ~: ~ .... - -== Gëmëti~ l J' ~ ~:3 ~ ~ Z ~ ~ ~ ~ ~ ~ ~ ~ ~ i... ~~ ~~ ~~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ I ~ b....... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ F- ie-- - K-- r-- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ )~ ConocoPhi lips 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RO Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Camco OS 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/ OCR 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 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. / Baker 7" x 3-1/2" 'SA B-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 3-1/2" WL Re-entry Guide w/ shear out sub. Tubing tail 320' above top planned perforation. TD @ 8,405' MD /6,118' TVD (300' MO below Miluveach) O~· ¡;,:" r ,'1 L .., .. ~ '.' ",j rï'Udì\Ji~~ Scott L Lowry 01/16/03 } ) 1·~;~:O=---/1~ ¡-:? ' ANCHORAGE AK 99501 . DATE ~Jt.{ Vl vt( V'\.. L.l/V~~ 62-14/311 t.~¡.! :;~~~~~~E. 9. 1/f-,6 or/; lL.,~5K:ff I t4~7C I $ ¡CO. DO ~t -- OJA-i: jUi.-¿·t~~f C-ë!ú¿ ;'S ~<~!!ot:') - uOLLARS tð j ~~ ~... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars ~ . .., ".~."""",,.,-,,"""" c¡¿. I //7) J \ MEMO -LJA:!-~:'=.41L~~é!:~_!!! ; I: 0 ~ . . 0 0 . '-t '-t I: 2 . aDO 0 0 '-t 2 7 2 5 7111 . 0 2 0 t .\.·W~',j¡!",:\~··"."",~."",~.\".,,,:~:,¡,,,/-,,~~ "!"I~~"',"""'W" ,"'I"",'r'~~'"'~"',;'·:'I'":I"'~'"'''''''.\''':i\\:I'''''''''~11i'';·:?~~''' '~~!'r"'I''''nrT,'1I·'''¡:':''''.'·'~~1h·,~: ,"'·'m,",'.", ·!:'~'~"~·":"·r.!r :,,~,. ~(":'c,,,,::·.' ',,,,,,, ?'''~\'7''.'~''. "'~" :.",''''II1\'~:'lm.f'~:', :"'~:" "'1"'''''1'' ":.~,.,:,,, ...;;;';/:;;.;:;"."'.:~' ~ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) "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(f), 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). paOT (PH) 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 that 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 . CÖMPANYGv......_,~~}.( WELL NAME *4 .~S"-7 2.. PROGRAM:Exp _ Dev --:- Redrll ~ Re-Enter _ ServX- Wellbore seg_ FIELD & POOL . 4'9 (""j / r),-) INn' CLASS /- µ ..If'( 1" ~ if '\ GEOL AREA ð'1 ñ UNIT# //1 ó /) ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . tý \N 2. Lease number appropriate. . . ~ . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . , . Y N 4. Well located in a defined pool.. . . . . . . . . . . . .. . . . Y N 5. Well located proper distance from drilling unit boundary. .... . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . ... . . . . ... . . . Y N 9. Operator only affected party.. . . . . . ... . . . . . . . . . . Y N 10. Operator has appropriate bond in force.. . . . . . . . . . . . Y IN 11. Permit can be issued without conservation order. . . . . . . . Y N ) 12. Permit can be issued without administrative approval.. ... . . Y N " ., (Service Well Only) 13. Well located w(in area & strata authorized by injection order #~ Y N (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . ... ~y N ENGINEERING 15. Conductor string provided. . .. . . . . . . . . .. . . . . . Y. N 16. Surface casing protects all known USDWs. . . . . . . .. . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . þ1. 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y (NI A- D (l CJÇ..<:-t' b Ie. 19. CMT will cover all known productive horizons. . . . . . . .. . 6J N 20. Casing designs adequate for C, T, B& permafrost. . . . . . . &. N h· 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . CV N Ai~. OV~ TEÇ- 22. If a re-drill, has a 10-403 for abandonment been approved. . . '¥-N NIIt- . 23. Adequate wellbore separation proposed.. .... . . . . . .. . . N 24. If diverter required, does "it meet regulations. .. . . . . .. . N dlA 1. / 25. Drilling fluid program schematic & equip list adequate. . . . . '.N Mev¡¿ yrtlA..-l ,t. S PfJ1 . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N AÚI ) C~ ") . . 27. BOPE press rating appropriate; test to 5000 psig. N {v, > I ~ ¡'-'I (....- P $ ¿ . f' 28'. Choke manifold complies w/API RP-53 (May 84). . . . . . . . WGA- i t 1 () 5 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . APPR DATE 1iZ-0.?k APPR DATE ) . (Service Well Only) GEOLOGY APPR DATE hr'. ~11ä5 I' (É~Plorafu~ Only) 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented o"n potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (ifoff-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... /L/ ¿:.">I"V -c....- GE~Y: PETROLEUM ENGINEERING: UIC ENGINEER COMMISSIONER: Commentsllnstructions: RP. ./ TEM JDH JBR ~: ç t,{ D'2J WGA ./ MJW MLB ~ '/;.. 7/Þ3 SFD Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane 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 Drilling Services LIS Scan Utility d-D3-b\r ~ \ ~4 tf $Revision: 3 $ LisLib $Revision: 4 $ Sat May 24 09:25:36 2003 Reel HeadeJ:· Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/0.5/24 O.cigin. . . . . . . . . . . . . . . . . . . STS Reel Namc................UNKNOWN Continuat.lon Number...... 01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technic<ll Services Tape Header Service name.............LISTPE Date.. . . . .. . . . . .. . . . . . . . . 0:3 /05/24 Origin. . . . . . . . . . . . . . .. . . . S'1'S Tape Name................ UNKNOWN Continuation Nurnber......01 Previous Tape Nam.e....... UNKNOWN Comment.s................ .STS LIS Writing Library. Sci.entitic Technical Services Physicill EOF Comment Record TAPE l-IE:þJ)E:R Kuparuk MWD/MAD LOGS II WELL NAME: API NUMB£R: OPE.RATOR: LOGGING COMPANY: TAPE CREATION DATE: Jf ,JOB DATA 3S-22 501032044600 Canaca Phillips Alaska, Inc. Sperry Sun 15-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AKMW2280031 P. SMITH M. THORNTON it SURFACE LOCATION SECTION: 'l'OWNSH.1 P: RANGE: fNL: FSL: F£L: FWL: F,J,f,VATJ ON (F'1' FROM MSI. 0) KELLY BUSHING: DERRICK FLOOR: GROUN [) LEVF.T,: HI l?N 8E 2556 1227 .00 57.10 1.7.70 ~ WELL CASING RECORD 1ST STRING 2ND STRING 3ED STErNG PRODUCTION STRING OPF:N HOLE CASrNG nRTLLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.~00 9.62~ 3049.0 ~ RSMl\RKS : 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. - . ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. !'-1:'!D RUI'! 100 - 500 :^!SRE DIRSCTION!\l.. ONLY }\ND l\RE t'!OT ) ) PRESENTED. 4. HV\ID RUN 600 HAS DIRECTIONAL Ii-11TH DUAL G_~IHA RAY (DGR) , U' 'Jl.,I 7, J NG GEI(-ŒR-JvlUL,LEk 'I'U8F:m:'l'F:C'T'OkS ELECTROHAGNETIC HAVE RESISTIVITY PHASE-4 (EWR4), COHPENSATED THERMAL NEUTRON POROSITY(CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. MWIJ DATA IS CONSIDE.RED PDC PER GKPll, GEOSCIENCES. 6. MítiJDRUNS 100 - 600 REPRESENT WELL 3S-22 II'JITH API 50-103-20446-00. THIS WELL REACHED A TOT.AL DEPTH (TD) OF 8423' MD, 6081' TVD. SROP ~ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAM.MA RAY COHBINED. SEXP SMOOTHED PHASE SHIFT DERIVED RESISTIVTTY (EXTRA SHALLOW SPACING) . SESP = StvIOO'T'HEI) PHASE SHI. F"I' [JE:RrVE:I) RES IS'I'IVJ'I'\' (SHAI..,I.,(ÆI SPACING) . SEMP = SMOOTHED PHASE S!-IIFT DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT DEHIVED RESISTIVITY (DEEP SPACIN(1) . SFXF. ,= SMOOTHED FORM1\TION EXPOSURE TI.MF,. SPSF == SMOOTHED NEUTRON POROSITY SANDSTONE HATRIX FIXED HOLE SIZE. SBD2 SMOOTHED BULK DENSITY COMPENSATED(LOW-COUNT BIN). SC02 SMOOTHED STANDOFF CORRECTION (LOW·-COUNT BIN). SNP2 SMOOTHED NEAR DETECTOR ONLY PHO'I'OELEC'I'RIC ABSORPTION bACTOR (LOW-COUNT BIN). ACAL = SMOOTHED ACOUSTIC CALIPER ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: BOREHOLE SIZE: MJ".'l'RI:'<'DF',NSI'I'Y: HATRIX LITHOLOGY: FORHATION HATER SALINITY: MUD WEIGHT: MUD SALINITY: VARIABLE - FROM ACAL 2.65 glee SANDSTONE 25,000 pprn CL- 11. J ppg 175 - 250 ppm CL- $ Fi.lp Hp.=tdpr Service name.............STSLIB.OOl Service Sub Level Name... Version Numher.......... .1.0.0 Date of Generation.... ...03/05/24 Maximum Physical Record..65535 F 1. 1 e Type................ LO Previous File Name.......STSLIB.OOO Cc,mment Record FILE HE},\OER FILE NUMBER: 1 EDITED MERGED MWD Depth shitted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 i! FILE SUMMARY FEU TOOL CODE GR NPHI ì'-lCNT ST_",-RT DEPTH 30:~9.0 3039.5 3039.5 STO DEFTH O~ 0..5 83 9. ¡:; tl_) .:1.. 5 ') ) FET RPX RPM PEF RPS ROP RPD FCNT DRHO RIIOB $ 3039.5 3039.5 3039.5 3039.5 3039..5 3039.5 3039.5 3039.5 3050.0 3050.0 8384.0 8384.0 8384.0 8348.0 8384.0 8423.0 8384.0 8335.0 8348.0 8348.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ H MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO HERGE TOP 6 3029.0 JVIERGE BASE 8123.0 REJVIARKS: MERGED JVIAIN PASS. $ # Data Format Specification Record Data Reeo.Ld Type.................. 0 Data Specification Block Type.....O Logging Di.r-ectìon................. Dm,¡n Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999.25 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 " ¿ C:¡R MWD API 4 1. 68 8 3 RI?X MWD OHMM 4 1 68 12 4 RPS JVIWD OHMM 4 1 68 16 5 RPJVI JVIWD OHMJVI 1 1 68 20 6 RPD MWD OHMM 4 1 68 24 -¡ FET MWD HR 4 1 68 28 8 PEF MWO BARN 4 1 68 32 9 NPHI MWD pu-s 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 NCNT MWD CNTS -1 1 68 4.<1 12 RHOS MWD G/CM 4 1 68 48 13 DRHO MWD G/CM 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3029 8423 5726 10789 3029 8423 ROP Mli'm FT/H 2.98 <182.65 178.812 10768 3039.5 8<123 GR MWD API 4/.3~ 4:)1.91 123.428 10/24 3029 8390.~ RPZ H'V\J'D OHHIv¡ 1.1 2000 4.5804 10690 3039.5 8384 RPS Mv-JD OHMM 1.1 2000 <1. 9 ,17 3 10690 3039.5 838,1 RPM MWD OHMM 0.3~ 2000 6./342/ 10690 jOj9.~ 8384 f"\t"u l"lWD OHt-1M 1. 03 2000 8.6067 10690 3039.5 8384 FET MND IIR 0.1325 63.0949 0.86395: 10690 3039.5 8384 PEF MWD BARN 1. 89 12.88 3.27623 10618 3039.5 8348 NPHI HWD PU-S 7.44 52.85 31.9936 10581 3039.5 8329.5 fCNT MI^JD CNTS 589.4 1075.2 1013.27 10592 3039.5 8335 NC!'IT MIAJD CNTS 112031 207740 137821 10591 3039.':-' :3334.5 RHOB ¡'fwD t...-;/CI"[ 1. 979 3.18 2.33368 10597 3()5CI 834 f: DRHO t11'm G / C~1 -0.104 0.431 0.0566459 1059: 3050 83~ f: First Re:::dii'.g For Entire File.. ........3029 ) Last Reading For Entire File...........8423 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/24 Maximum Physical Record..G5535 E'il e Type................ LO Next File Name.... ...... .8T8LIB.002 Physical EOr File Header Service name.............STSLIB.002 Service Sub Level Name... Version Nurnbe.c.......... .1.0.0 Date of Generation. ......03/05/24 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.001 Co.mrnent Recor:d FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE (3R RPD NCNT FCNT NPHI PEF FET RPM ROP RPS RPX RI-IOB DRHO 2 ') header data for each bit run in separate files. 6 .5000 ò y START DEPTH 3029.0 3039.5 3039.5 3039.5 3039.5 3039.5 3039.5 3039.5 3039.5 3039.5 3039.5 3050.0 3050.0 µ LOG HEADER DATA DATE LOGGED: SOFTìtiJARE SURFACE SOFTWARE VERSION: DOí'\JNHOLE SOFT~'\JARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (E'T): BOTTOM LOG INTERVAL (E'T): BIT ROTATING SPEED (RPM): HOLe INCLIW\TION (DeG MINIMUM .A.NGLE: fl/lAXIfI/¡UM ANGLE: iJ. IT TOOL STRING (TOP TO BOTTOM) veNDOR TOOL CODE TOOL TYPE DGR Et^JR'l oSLO CTN " STOP DEPTH 8390. ~) 83(H . 0 fB3/ .5 8335.0 8329.5 8348.0 8384.0 8384.0 8423.0 8384.0 8384.0 8348.0 8348.0 DUAL GAHÌ"IA RAY ELECTRO~A.G. RESIS. STABILIZED LITHO DEN COMP THERMT\L NEUTRON BOREHOLE .A.tW C.A.SING D,A.TÞ. OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 21-FEB-03 Insite 6.02 Memory 8423.0 ,15. -1 ~1. :2 TOOL NUMBER 164580 103792 120993 1 7 ? () 51 8.!:>Uu 3049.0 ) ') BOREHOLE CONDITIONS ¡VIUD 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 CIRCULATINC:; TET\MPERATUEE: MUD FILTEATE AT MT: HUD CAKE /\1' MT: LSND 11. 30 45.0 9.3 250 2.0 1.7.50 1.005 1. 600 2.000 78.0 140.8 78.0 78.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): jf TOOL STANDOFF (IN): EWE FREQUENCY (HZ): Ii REMARKS: $ # Data Format Specification Record Data .Record TYpCè.................. 0 Data Specification Block: Type. ....0 Logging Dlrection.................Down Optical log depth units...........Fcct Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999.25 Depth Uni t3. . . . . . . . . . . . . . . . . . . . . . . Datum Specificati.on Block: sub-type... 0 Name Service Orde.c Units Size Nsam Rep Code Offset Channel DEPT FT 4 1. 6B U 1. ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API <1 1. 68 8 3 RPX MWD060 OHMM 4 1 68 1.2 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 o II M.~1 4 1. 68 20 6 RPD MWD060 o I-IMM. 4 1. 68 24 7 FET ¡VIWD060 HR 4 1 68 28 8 I?E F MWD060 BARN <1 1 68 32 9 NPHI MWD060 PI)-S 4 1. 68 36 10 E'CNT MWD060 CNTS 4 1 68 40 11 NCNT MWD060 CNTS 4 1 68 44 12 RHOB MWD060 G/CM 4 1. 68 48 13 DRIIO MíeJD060 G/CM 4 1 68 52 14 first Name Service Unit Min Max Mean Nsam Readj.ng DC!?T fT 3029 8423 5726 10789 3029 ROP MWD060 FT / H 2.98 482.65 178.812 10768 3039. !') GR HHD060 API 47.35 451.91 123.428 10724 3029 RPX 1'1WDOGC or ItJ\M 1.1 2000 4.5304 10G90 3039.5 RPS M[^lD060 OH[VIY! 1.1 2000 4.9473 10690 3039.5 R PJV¡ HHD060 o HfvUV! 0.35 2000 6.73427 10690 3039.5 RPD M¡'W060 0111'1..'\1 1. 03 2000 8.6067 10690 3039.5 fET Mt^!DO 6 0 HR 0.1325 63.0919 0.863957 10690 3039.5 PE F MWDU6U BARN 1. 89 12.88 3.21623 1061tJ 3039.~ N PIII I'fi-;'D060 PU-S 7.44 52..85 31.9936 10531 3039.5 FCNT MWD060 CNTS 589.4 4075.2 1013.27 10592 3039.5 NCNT M1^m060 CNTS 112031 2077 ,1 0 137821 10591 3039.5 RHOB MWDU6U G/CM 1.9/9 3.18 2.33368 lU~9/ jU~U DRHO Hv-'¡DO G 0 G/CH -0.104 O.·Ul 0.0566459 10597 30::,0 Fi rct RC.:Jdir1g For Entire filc..........3029 Last Reading For Entire File...........8423 Last Read ng 423 423 83 0.5 384 384 384 ~o .1 381 348 83 9.5 335 83 ,1.. 5 3..1 ;-j J~ ) ) file Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date ot Generation. .... ..Oj/05/24 Mdximum Physical Recürd..65535 Fi 1 c Type................ LO Next File Name...........STSLIB.003 Physical EO£' Tape Trailer: Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 031 05/ 2 4 Or i gin. . . . . . . . . . . . . . . . . . . ST S Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wr.i ting Library. Sc.ientific Technical Services Reel Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 0.5/ 24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............ ....UNKNOWN Continuation Number.... ..01 Next Reel Name...........UNKNOWN Comments................ .STS LIS Wr:i.U.ng Library. Sci.entific Technical Services Physical EOF Physical EO£' bad Of LIS File
