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Home My WebLink About202-206202-206 T39767 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.13 07:52:07 -09'00' 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" H-40 108' 9-5/8" L-80 2547' 7" L-80 6106' 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 6577' MD3-1/2" CASING TUBING RECORD 223 sx Class G w/GasBlok8-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/31/2024 202-206/323-408 P.O. Box 100360, Anchorage, AK 99510-0360 476110 5993879 Surface/ Surface 6900' MD/ 6118' TVD ADL0380107 ALK 4624 50-103-20433-00-00 KRU 3S-18 November 23, 2002 November 30, 2002 9. Ref Elevations: KB: 28 ft Kuparuk River Field/ None-Abandoned 26# AMOUNT PULLED 473377 473345 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 1625' MD/ 1545' TVD N/A CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 6545' MD/ 5767' TVD PACKER SET (MD/TVD) 42" 12-1/4" 86 sx Arctic Crete 30'637 sx AS IIIL, 250 sx LiteCrete 30' 2841'30' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface-3655' 3655-4736' PLUGGED AND ABANDONED Perforations: 6642-6678' MD and 5863-5898' TVD (cemented) Gas-Oil Ratio:Choke Size: 40 bbls 15.8 Class G cement Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. HOLE SIZE Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 158 bbls Class G cement OA Cement Surface- Shoe @2841' 104 bbls 15.8 ppg PermaFrost cement w/ LCM in lead 50 bbls Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 4411-4737' 67.8 bbls 15.8 cement 4561-4711' 4 Perf Wash Cement passes 6887' SIZE DEPTH SET (MD) 2538' FNL, 1149' FEL, Sec. 18, T12N, R8E, UM 1628' FNL, 3882' FEL, Sec. 18, T12N, R8E, UM 1617' FNL, 3914' FEL, Sec. 18, T12N, R8E, UM 27' 62.5# 40# 108' 27' WT. PER FT.GRADE CEMENTING RECORD 5994798 SETTING DEPTH TVD 5994808 TOP Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 10:28 am, Apr 08, 2024 Abandoned 3/31/2024 JSB RBDMS JSB 041524 xGDSR-4/23/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1625' 1545' Top of Productive Interval N/A 31. List of Attachments: Schematic, Summary of Operations, Site 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: 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: 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 Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2024.04.08 08:59:47 -08'00' DTTMSTART JOBTYP SUMMARYOPS 4/21/2023 ACQUIRE DATA DRIFT FREELY W/ 2.77" CEMENT RETAINER DRIFT (NO ANOMALIES). JOB COMPLETE 4/21/2023 ACQUIRE DATA INJECTIVITY TEST ON TUBING PUMPED 40 BBLS DSL TO LOAD TUBING THEN 20 BBLS STEP RATE INJECTIVITY TEST. TBG: FINAL STEP RATE 3 BPM 375/750/200 OA: FINAL STEP RATE: 1.75 BPM 60/825/1250 READY FOR COIL P&A. 5/1/2023 ACQUIRE DATA TAGGED D-NIPPLE @ 6569' RKB W/ CEMENT RETAINER, PICKED UP 5' TO 6564' RKB, AND ATTEMPT TO SET RETAINER (LAUNCHED 2 BALLS W/ NO INDICATION OF RETAINER GETTING SET). POOH, RECOVER BOTH BALLS AND IDENTIFY ISSUES WITH SETTING TOOL ASSEMBLY. RBIH WITH CEMENT RETAINER, TAG D NIPPLE AND PICK UP 3'. SET RETAINER AT 6566' RKB. PERFORM INJECTIVITY TEST THROUGH RETAINER. PUMP 21 BBL OF 15.8 CEMENT. INJECT 19 BBL THROUGH RETAINER AND LAY IN 2 BBL ON TOP OF RETAINER TO 6,336'. PUMP GEL PILL, CLEAN DOWN TO TARGET TOC AT 6,336' AND CHASE RETURNS TO SURFACE. READY FOR SW TAG AND TEST IN 24 HRS. 5/3/2023 ACQUIRE DATA PRE_STATE WITNESSED TAG HARD CEMENT @ 6292' SLM/6316' RKB , LRS MIT-T TO 1500 PSI (PASS) *COMPLETE* 5/5/2023 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. 5/12/2023 ACQUIRE DATA STATE WITINESS (CAM ST.JOHN) TAG TOC @ 6300' SLM. PERFORM PASSING MIT-T TO 1500 PSI. PULL DGLV FROM ST# 4 @ 6002' RKB, POCKET OPEN. IN PROGRESS. 5/13/2023 ACQUIRE DATA PULLED GLV @ ST #1 2882' RKB, TOOL STRING WAS BLOW UP HOLE, POOH TO 266' WHERE WIRE PARTED. TS LEFT IN WELL, (35' OAL) RIG DOWN DUE TO INSUFFICIENT CRANE SIZE TO FISH TOOLS. 5/14/2023 ACQUIRE DATA FOUND TOOL STRING FISH @ 2732' SLM. CHASE DOWN TO 6242' SLM, LATCHED & SHEARED TOOL. JOB IN PROGRESS 5/15/2023 ACQUIRE DATA RECOVERED TOOL STRING FISH @ 6242' SLM. RECOVERED 1.5' WIRE USING WIRE GRAB AND BRUSH. CONFIRMED EMPTY POCKET IN ST #1 W/ LIB, SET DMY GLV IN ST# 1 @ 2882' RKB, READY FOR CIRC OUT FOR CMIT & TBG CUT. 5/20/2023 ACQUIRE DATA HOIST WELLTEC CUTTER TO CUT TUBING AT 6283 FT. CCL OFFSET = 18.0 FT, CCL STOP = 6265.0 FT. WELLTEC REPORTS GOOD INDICATION OF CUT AT SURFACE. ELINE COMPLETE. JOB IS READY FOR CIRC-OUT & DHD 5/22/2023 ACQUIRE DATA CIRC OUT DWN TBG UP IA TO 3S-620 FL W/ 190 BBLS SSSW & 77 BBLS DSL, U-TUBE FOR FREEZE PROTECT, CMIT TXIA TO 1500 - DDT 5/30/2023 ACQUIRE DATA (P&A) T X IA DDT (IN PROGRESS) 5/31/2023 ACQUIRE DATA (P&A) T X IA DDT (IN PROGRESS) 6/1/2023 ACQUIRE DATA (P&A) T X IA DDT (IN PROGRESS) 6/24/2023 PUMPING TRACKING ONLY PUMPED 2 BBLS DSL FOR FREEZE PROTECT DWN FL 7/14/2023 ACQUIRE DATA (P & A) DDT T X IA TO 0 PSI (PASSED), BLEED OA FOR BUR (COMPLETE). 8/2/2023 RECOMPLETION Complete test of tree break on 3S-14, rig down and pull pits away from rig, rig down rig and pull off 3S-14 and back over 3S-18, spot rig and pits, take on 9.6# water kill well, OWFF , no flow, set BPV and test dart, test 1000 psi for 10 min, nipple down tree, nipple up stack, start BWM 8/3/2023 RECOMPLETION Completed BWM, Test BOP's 250/2500, spear and pull hanger to floor 110K PUW, lay down 104 jts tubing rack 29 stands in derrick, pick up RBP BHA, trip in hole on stand to 2700', set RBP, Pressure test 1000 psi 10 min good pressure test, 30 min flow check no flow 3S-18 Plug and Abandon Summary of Operations 8/4/2023 RECOMPLETION 9/4/2023 CHANGE WELL TYPE EQUALIZE & PULL 7" WR BRIDGE PLUG @ 2680' RKB, READY FOR E-LINE. 9/5/2023 ACQUIRE DATA SPOT EQUIPMENT AND PREPARE JUNK BASKET WITH 5.92" GAUGE RING RIH WITH 5.92" GAUGE RING, TAGGED AT 6280' AND POOH 9/6/2023 ACQUIRE DATA RIH WITH 5.92" GAUGE RING, TAGGED AT 6280' AND POOH RIG UP AND RIH WITH USIT-CBL FOR PRE-PERF CEMENT EVALUATION LOG LOG MAIN PASSES FROM 6270' - 3500' AT 5DEG 6IN, 5DEG 3IN, 5DEG 1.5IN RESOLUTIONS, LOG REPEAT PASS AT 5DEG 3IN FROM 5900' - 5500' LOGGING COMPLETE 9/10/2023 ACQUIRE DATA MIRU ELINE AND STANDBY FOR APPROVALS FROM AOGCC. 9/11/2023 ACQUIRE DATA SET CIBP AT 4737' GUN 1 PERFORATED INTERVAL = 4691'-4711' GUN 2 PERFORATED INTERVAL = 4671'-4791' GUN 3 PERFORATED INTERVAL = 4649'-4669' GUN 4 PERFORATED INTERVAL = 4629'-4649' GUN 5 PERFORATED INTERVAL = 4607'-4627' ***CONTINUED INTO NEXT DAY*** 9/12/2023 ACQUIRE DATA GUN 6 PERFORATED INTERVAL = 4587'-4607' GUN 7 PERFORATED INTERVAL = 4565'-4585' GUN 8 PERFORATED INTERVAL = 4561'-4565' JUNK BASKET GAUGE RING RUN TAGGED PLUG AT 4737' - GOT BACK SOME METAL SHARDS IN BASKET JOB COMPLETE, READY FOR COIL PWC 9/13/2023 ACQUIRE DATA RIH WITH PERF WASH TOOL, TAG CIBP AT 4,737'. PAINT FLAG AT 4,731'. PERFORM 4 PERF WASH PASSES FROM 4,725' TO 4,550'. PUMP GEL SWEEP AND CHASE OOH OPEN UP CEMENT TOOL AND START CEMENT JOB 9/14/2023 ACQUIRE DATA START PUMPING CEMENT JOB LAY IN 67.8 BBLS 15.8 CEMENT F/4737 T/4411' POOH FLUSH OUT WELL W/ CLEAN S/W W/SWEEPS T/SURF AND F/P WELL F/2500'T/SURF. READY FOR SW TAG AND TEST IN 48 HRS. 9/19/2023 ACQUIRE DATA TAG TOC @ 4377' SLM, MIT IA TO 1500 (FAILED) 6 TIMES WITH A CONSISTENT 100 PSI LOSS IN 15 MIN'S. COMPLETE. 9/20/2023 CHANGE WELL TYPE OA INJECTIVITY TEST PUMPEP 5 BBLS DSL DOWN OA FOR INJECTIVITY TEST, SEE LOG FOR DETAILS JOB COMPLETE 9/21/2023 CHANGE WELL TYPE PUMPED OA CEMENT DOWN SQUEEZE f/ SURFACE TO SHOE w/ 104 BBLS OF 15.8 PPG PERMA FROST CEMENT w/ LCM IN LEAD 50 BBLS. PERFORMED 15 MIN SHUT DN HESITATION & PUMP THE LAST OF THE TAIL CEMENT. READY FOR THE NEXT STEP OF P&A. 9/24/2023 ACQUIRE DATA (P&A) OA DDT TO 0 PSI (COMPLETE), OBTAIN OA TOC (COMPLETE) @ SF 12/19/2023 ACQUIRE DATA STANDBY ON AES RIG UP, UNABLE TO MAKE IT THROUGH THE TREE WITH 6.25" MILL, RUN IN WITH 6.125" MILL, DRY TAG TOC AT 4382' MILLED TO 4572' CONTINUE MILLING 12/20/2023 ACQUIRE DATA MILL DOWN TO 4574' CTMD @ 60 FPH, POOH TO INSPECT MILL, RBIH TO MILL FROM 4574' TO 4580' CTMD, POOH TO REPLACE MOTOR, TAG AT 4580' CTMD GET GOOD MOTOR WORK AT 4582' CTMD BUT NOT MAKING ANY HOLE, FIND THAT WE HAD A BLOWN BURST DISC, TAG CEMENT AT 4580' CTMD AND MILL DOWN TO CIBP @ 4731' CTMD, UNDERREAM FROM 4360' TO 4722' 12/21/2023 ACQUIRE DATA MADE SECOND UNDERREAM PASS DOWN TO 4731' PUMP A 5/8" BALL OPEN CIRC SUB PUMPED 40 BBLS OF GEL AND CHASE TO SURFACE FREEZE PROTECT FROM 2500' RDMO 12/25/2023 ACQUIRE DATA PERFORM JUNK BASKET RUN, TAGGED TOC AT 4740', THEN LOG CEMENT EVALUATION LOG (IBC-CBL) POST CEMENTING AT 5 DEG 6", 5 DEG 3", AND 5 DEG 1.5" RESOLUTIONS. LOGGED FROM 4740' TO 4300', LOGGING COMPLETE, BEGIN TO RD. 12/26/2023 ACQUIRE DATA COMPLETE RD FROM IBC-CBL LOG. JOB IS READY FOR ENGINEER TO SUBMIT RESULTS TO AOGCC FOR NEXT STEPS. 1/25/2024 ACQUIRE DATA JOB DELAYED DUE TO DOYON 142 RIG ACTIVITIES. RIG UP CTU 4 & HES CEMENTERS. RUN IN HOLE W/ 2" DJN TO CIBP @ 4731'. 1/26/2024 ACQUIRE DATA TAG CIBP @ 4736' CTMD; PULL UP TO 4720' & LAY IN 40 BBLS OF 15.8 CLASS G CEMENT FROM 4,736' CTMD TO 3,686' CTMD. FREEZE PROTECT TUBING. READY FOR STATE WITNESSED TAG AND TEST IN 48 HRS. 2/4/2024 ACQUIRE DATA AOGCC WITNESSED (ADAM EARL) TAG TOP OF CEMENT @ 3655' SLM, TEST ON IA TO 1710 PSI (PASS). 2/8/2024 ACQUIRE DATA TRAVEL TO 3S PAD. MIRU. 2/9/2024 ACQUIRE DATA RIH TO TAG DEPTH AT 3,678' CTMD. LAY IN 158 BBL OF CLASS G CEMENT FROM 3,678' TO SURFACE. CLOSE MASTER AND WASH ACROSS TREE AND BOPS. JOB COMPLETE. 2/23/2024 ACQUIRE DATA (P&A) TxIA DDT (PASS), TOC @ TUBING HANGER. 3/1/2024 ACQUIRE DATA (P&A) STAGED EQUIPMENT & PREPPED FOR TREE VALVE REMOVAL, VERIFIED 0 PSI ON TUBING & IA, SIMOPS WITH FRAC & DETERMINED FRAC UNIT IS TOO CLOSE TO WELL #18 FOR TREE VALVE REMOVAL. 3/21/2024 CHANGE WELL TYPE (P&A) REMOVE DOUBLE SWAB VALVES (COMPLETE) OA DDT (IN PROGRESS) 3/22/2024 CHANGE WELL TYPE (P&A) REMOVE IA VALVES (COMPLETE) OA DDT (IN PROGRESS) 3/25/2024 CHANGE WELL TYPE (P&A) T X I DDT (COMPLETE) OA DDT (COMPLETE) CUT AND REMOVE THE WELLHEAD (COMPLETE) CUT AND REMOVE THE CELLAR (COMPLETE) EXCAVATION (IN PROGRESS) 3/26/2024 CHANGE WELL TYPE (P&A) EXCAVATION (IN PROGRESS ~11') 3/27/2024 CHANGE WELL TYPE (P&A) EXCAVATION TO 14' (COMPLETE) 3/28/2024 CHANGE WELL TYPE (P&A) INSTALLED SHORE CAN . CUT AND REMOVED ADDITIONAL 102" OF WELL STUB. TOP OF CEMENT = 136" (11' 3")' BELOW ORIGINAL TUNDRA. 3/29/2024 CHANGE WELL TYPE (P&A) AOGCC (KAM STJOHN) VERIFIED MARKER PLATE, TOC @ 11' BELOW ORIGINAL GROUND, BACKFILLED SHORING CAN & COMPACTED EVERY 2' 3/30/2024 CHANGE WELL TYPE (P&A) REMOVE SHORING CAN, FINAL BACKFILL & DEMOB EQUIPMENT 3/31/2024 CHANGE WELL TYPE (P&A) AOGCC KAM STJOHN SITE CLEARANCE POST 3S-18 P&A (COMPLETE) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,796.0 3S-18 10/6/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&A AOGCC Kam STJOHN TOC and marker plate 11' below OG 3S-18 3/30/2024 mouser Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 2,840.6 2,547.4 40.00 L-80 BTC PRODUCTION 7 6.28 41.0 6,887.1 6,105.7 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 6,283.0 Set Depth … 6,577.0 Set Depth … 5,798.4 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,428.9 5,652.4 11.71 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,480.9 5,703.5 9.86 SLEEVE 4.520 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE BAKER CMU 2.812 6,530.5 5,752.4 8.87 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.990 6,544.1 5,765.9 8.60 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,545.1 5,766.8 8.58 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 2.992 6,550.0 5,771.7 8.48 MILL 3.500 80-40 MILLOUT EXTENSION 80-40 2.992 6,555.5 5,777.1 8.37 COLLAR 3.500 2.992 6,569.1 5,790.6 8.22 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,576.1 5,797.5 8.20 WLEG 4.490 WLEG w/ SHEAR OUT SUB 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 40.5 40.5 0.13 MARKER PLATE AOGCC (KAM STJOHN) VERIFIED MARKER PLATE, TOC @ 11' BELOW ORIGINAL GROUND, BACKFILLED SHORING CAN & COMPACTED EVERY 2 3/29/2024 0.000 4,736.4 4,145.2 34.35 CIBP 5.61" CIBP MID-ELEMENT @ 4737' RKB, OAL = 1.6' LEGACY HPBP 00056 10- 002 9/10/2023 0.000 6,283.0 5,511.4 18.07 CUT WELLTEC MECHANICAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/20/2023 2.992 6,335.5 5,561.7 15.70 FISH 1" GLV FELL TO CEMENT TOP. 5/13/2023 0.000 6,566.0 5,787.5 8.23 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/2/2023 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,561.0 4,585.0 4,000.5 4,020.3 9/12/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 4,587.0 4,627.0 4,021.9 4,054.9 9/12/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 4,629.0 4,669.0 4,056.5 4,089.6 9/12/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 4,671.0 4,711.0 4,091.2 4,124.2 9/12/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 6,642.0 6,678.0 5,862.8 5,898.4 C-4, 3S-18 12/8/2002 6.0 IPERF 2.5" 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 4,561.0 4,711.0 4,000.5 4,124.2 Cement Squeeze PerfWash Cement 9/13/2023 6,300.0 6,576.1 5,527.6 5,797.5 Cement Plug 5/2/2023 6,576.1 6,887.0 5,797.5 6,105.6 Cement Plug 5/2/2023 4,411.0 4,737.0 3,874.1 4,145.7 Plug – Plug Back / Abandonment Plug 15.8 PPG CLASS G CEMENT. 9/13/2023 3,655.0 4,736.0 3,234.5 4,144.9 Plug – Plug Back / Abandonment Plug 40 BBL OF CLASS G CEMENT 1/26/2024 41.0 3,655.0 41.0 3,234.5 Plug – Plug Back / Abandonment Plug 15.8 PPG CLASS G 2/9/2024 3S-18, 4/5/2024 2:02:47 PM Vertical schematic (actual) PRODUCTION; 41.0-6,887.1 IPERF; 6,642.0-6,678.0 Cement Plug; 6,576.1 ftKB CEMENT RETAINER; 6,566.0 PACKER; 6,545.0 GAS LIFT; 6,428.9 FISH; 6,335.5 Cement Plug; 6,300.0 ftKB CUT; 6,283.0 CIBP; 4,736.4 APERF; 4,671.0-4,711.0 APERF; 4,629.0-4,669.0 Cement Squeeze; 4,561.0 ftKB APERF; 4,587.0-4,627.0 APERF; 4,561.0-4,585.0 Plug – Plug Back / Abandonment Plug; 4,411.0 ftKB Plug – Plug Back / Abandonment Plug; 3,655.0 ftKB SURFACE; 41.0-2,840.6 Cement Squeeze; 41.0 ftKB Cement Casing; 41.0 ftKB CONDUCTOR; 41.0-108.0 Plug – Plug Back / Abandonment Plug; 41.0 ftKB MARKER PLATE; 40.5 Casing 1; 0.0 KUP PROD KB-Grd (ft) 33.27 RR Date 12/3/2002 Other Elev… 3S-18 ... TD Act Btm (ftKB) 6,900.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043300 Wellbore Status PROD Max Angle & MD Incl (°) 35.67 MD (ftKB) 2,255.15 WELLNAME WELLBORE3S-18 Annotation Last WO: End DateH2S (ppm) 20 Date 2/16/2023 Comment SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-18 Plug and Abandonment April 3, 2024 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-18, commencing operations on September 6, 2023 and completing the Plug and Abandonment on March 31, 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 4,737ft KB, the production casing was perforated from 4,561 to 4,711ft 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. 2024-0331_Location_KRU_3S-18_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 03/31/2024 P. I. Supervisor FROM: Kam StJohn SUBJECT: Location Clearance Petroleum Inspector KRU 3S-18 ConocoPhillips Alaska Inc. PTD 2022060; Sundry 323-408 03/31/2024: Traveled to KRU 3 S pad to do a location on KRU 3S-18 with CPAI representative Roger Mouser after the surface abandonment was completed. Area was clear of debris and had a good mound over the P&A’d well. No follow up needed. Attachments: Photo     2024-0331_Location_KRU_3S-18_ksj Page 2 of 2 Location Inspection – KRU 3S-18 (PTD 2022060) Photo by AOGCC Inspector K. StJohn 3/31/2024 2024-0329_Surface_Abandon_KRU_3S-18_ksj Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 03/29/2024 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-18 ConocoPhillips Alaska Inc. PTD 2022060; Sundry 323-408 03/29/2024: I traveled to KRU 3S-pad verify the surface abandonment. Met with CPAI representative Roger Mouser at KRU 3S-18 after the surface cement job was completed. I verified the marker plate had the correct PTD and API # numbers, operator name, and well name. The plate thickness is ¼-inch steel. The casing cutoff was clean and flush and the cement was hard in all sections of the tubing and casing – this was verified by hitting with a hammer. The cutoff depth was 11 feet below tundra. Welding went well and marker plate was fit as per regulations. No follow up needed. Attachments: Photos (4)     2024-0329_Surface_Abandon_KRU_3S-18_ksj Page 2 of 3 Surface Abandonment – KRU 3S-18 (PTD 2022060) Photos by AOGCC Inspector K. StJohn 3/29/2024 2024-0329_Surface_Abandon_KRU_3S-18_ksj Page 3 of 3 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 202-206/ 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:Rig Elevation:Total Depth:6900 ft MD Lease No.:ADL0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ na Feet Surface:9 5/8"O.D. Shoe@ 2841 Feet Csg Cut@ na Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6887 Feet Csg Cut@ na Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 6577 Feet Tbg Cut@ 6283 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 4736 ft 3625 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1710 1610 1565 IA OA 21 21 21 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled out to KRU 3S-18 to witness a cement tag and pressure test for P&A operations. Brent Rogers was the CPAI rep. on the job. They tagged top of cement @ 3,655 ft SLM (3625 ft MD with 30 ft RKB correction). The tool string (250lbs hanging weight) was made up with 11 ft of 2 1/8" weight bar, oil jars, spanges, and a 5-ft ball check style sample bailer. Sample description top to bottom - cement-well fluid interface, unset cement then set-up cement near the ball. Pressure test passed. February 4, 2024 Adam Earl Well Bore Plug & Abandonment KRU 3S-18 CPAI PTD 2022060; Sundry 323-408 none Test Data: P Casing Removal: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0204_Plug_Verification_KRU_3S-18_ae            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: 1628' FNL, 3882' FEL S18 T12N R8E 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" H-40 108'86 sx ArcticCrete 9.625" L-80 2547' 7" L-80 6106' 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 6566-6778' 19 bbl of 15.8ppg Class G 6300-6566' 2 bbls of 15.8 Class G 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 223 sx Class G w/GasBlok8-1/2" 6577'3.5" 6545'MD/5767'TVD BOTTOM 12-1/4" 637 sx AS IIIL, 250 sx LiteCrete CASING 50-103-20433-00-00 KRU 3S-18 11/23/2002 6900'MD/6118'TVD 6300'MD/5528'TVD 28' P.O.Box 100360, Anchorage, AK 99510-0360 476110 2538' FNL, 1149' FEL S18 T12N R8E 1617' FNL, 3914' FEL S18 T12N R8E 11/30/2002 1625'MD/1545'TVD SETTING DEPTH TVD 5994808 TOP HOLE SIZE AMOUNT PULLEDTOP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 202-206/323-218Aband.: 8/04/2023 PACKER SET (MD/TVD) 42" 5993879 Kaparuk River Field/Suspended ADL0380107 ALK4624 30' 30' 2841' 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 473377 473345 CEMENTING RECORD 5994798 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 6642-6678' MD and 5863-5898' 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 30' 30' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 27' 62.5# 40# 108' 27' 6887' SIZE DEPTH SET (MD) 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 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 9:47 am, Aug 25, 2023 Suspended 8/4/2023 JSB RBDMS JSB 083123 xGDSR-10/25/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1625' 1545' N/A Suspended N/A Suspended N/A Suspended N/A Suspended 31. List of Attachments: Directional Survey, Well Schematic, Cement Operations, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Dusty Ward Digital Signature with Date: Contact Phone:907-265-6531 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and 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 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval: 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. 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. 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: dusty.ward@conocophillips.com Authorized Title: Wells Engineer 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,796.0 3S-18 10/6/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Welltec cut at 6283' RKB 3S-18 5/20/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: PULL BROKEN LATCH @ 5329' 8/30/2012 hipshkf NOTE: TREE CAP CONNECTION: TOP 5 3/4"" ACME W/3.5"" EUE 8RD THREAD 12/2/2002 triplwj 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 29.6 2,840.6 2,547.4 40.00 L-80 BTC PRODUCTION 7 6.28 27.0 6,887.1 6,105.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 6,283.0 Set Depth … 6,577.0 Set Depth … 5,798.4 String Ma… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,428.9 5,652.4 11.71 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,480.9 5,703.5 9.86 SLEEVE 4.520 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE BAKER CMU 2.812 6,530.5 5,752.4 8.87 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.990 6,544.1 5,765.9 8.60 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,545.1 5,766.8 8.58 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 2.992 6,550.0 5,771.7 8.48 MILL 3.500 80-40 MILLOUT EXTENSION 80-40 2.992 6,555.5 5,777.1 8.37 COLLAR 3.500 2.992 6,569.1 5,790.6 8.22 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,576.1 5,797.5 8.20 WLEG 4.490 WLEG w/ SHEAR OUT SUB 2.990 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) 2,680.0 2,415.1 34.32 RBP RBP from Yellowjacket for well barrier 8/3/2023 0.000 6,283.0 5,511.4 18.07 CUT WELLTEC MECHANICAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/20/2023 2.992 6,335.5 5,561.7 15.70 FISH 1" GLV FELL TO CEMENT TOP. 5/13/2023 0.000 6,566.0 5,787.5 8.23 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/2/2023 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,642.0 6,678.0 5,862.8 5,898.4 C-4, 3S-18 12/8/2002 6.0 IPERF 2.5" 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,300.0 6,576.1 5,527.6 5,797.5 Cement Plug 5/2/2023 6,576.1 6,887.0 5,797.5 6,105.6 Cement Plug 5/2/2023 3S-18, 8/22/2023 12:18:01 PM Vertical schematic (actual) PRODUCTION; 27.0-6,887.1 IPERF; 6,642.0-6,678.0 Cement Plug; 6,576.1 ftKB CEMENT RETAINER; 6,566.0 PACKER; 6,545.0 GAS LIFT; 6,428.9 FISH; 6,335.5 Cement Plug; 6,300.0 ftKB CUT; 6,283.0 SURFACE; 29.6-2,840.6 RBP; 2,680.0 CONDUCTOR; 30.0-108.0 KUP PROD KB-Grd (ft) 33.27 RR Date 12/3/2002 Other Elev… 3S-18 ... TD Act Btm (ftKB) 6,900.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043300 Wellbore Status PROD Max Angle & MD Incl (°) 35.67 MD (ftKB) 2,255.15 WELLNAME WELLBORE3S-18 Annotation Last WO: End DateH2S (ppm) 60 Date 11/10/2013 Comment SSSV: NIPPLE Page 1/2 3S-18 Report Printed: 8/22/2023 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) 8/2/2023 00:00 8/2/2023 01:30 1.50 MIRU, MOVE NUND P Nipple up production tree on 3S-14 0.0 0.0 8/2/2023 01:30 8/2/2023 03:30 2.00 MIRU, MOVE MOB P Jack up pits and pull away from rig for rig move ops 0.0 0.0 8/2/2023 03:30 8/2/2023 04:30 1.00 MIRU, MOVE PRTS P PT 3S-14 1500 psi 30 min for tree text 0.0 0.0 8/2/2023 04:30 8/2/2023 12:00 7.50 MIRU, MOVE MOB P Move rig sub from 3S-14 to 3S-18 staying on rig mats. Had to rig down scaffolding on 3S-17 to place rig mats around 3S-18. Place tree in cellar. Lay herculite, attach pits to rig sub and spot mud lab. Rig Accept at 12:00 HRS 8/2/2023. 0.0 0.0 8/2/2023 12:00 8/2/2023 15:00 3.00 MIRU, WELCTL RURD P RU circ lines in cellar to tiger tank. Bring on 9.6 ppg NaCl to pits. Build 40 bbl deep clean pill. 0.0 0.0 8/2/2023 15:00 8/2/2023 16:00 1.00 MIRU, WELCTL SEQP P PJSM and pressure test tiger tank line and squeeze manifold. 0.0 0.0 8/2/2023 16:00 8/2/2023 17:30 1.50 MIRU, WELCTL DISP P Displace well to 9.6 ppg brine @ 4bpm. 0.0 0.0 8/2/2023 17:30 8/2/2023 18:30 1.00 MIRU, WELCTL OWFF P OWFF no flow observed 0.0 0.0 8/2/2023 18:30 8/2/2023 20:00 1.50 MIRU, WELCTL MPSP P Set BPV w/ test dart // Test dart 1000 psi 10 min good test 0.0 0.0 8/2/2023 20:00 8/2/2023 23:00 3.00 MIRU, WELCTL NUND P Nipple down production tree, Nipple up BOPs 0.0 0.0 8/2/2023 23:00 8/3/2023 00:00 1.00 MIRU, WELCTL OTHR P Perform BWM on BOPs 0.0 0.0 8/3/2023 00:00 8/3/2023 03:00 3.00 MIRU, WELCTL OTHR P Perform Between wells maintenance 0.0 0.0 8/3/2023 03:00 8/3/2023 04:00 1.00 MIRU, WELCTL RURD P Rig up test BOPs 0.0 0.0 8/3/2023 04:00 8/3/2023 09:00 5.00 MIRU, WHDBOP BOPE P 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 and LVBR 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 = 1650 PSI, 200 PSI attained = 15 sec, full recovery attained = 104 sec. UVBR = 6 sec, Annular = 25 sec, Simulated blinds = 6 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 1950 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Bob Noble witness waived 0.0 0.0 8/3/2023 09:00 8/3/2023 09:30 0.50 COMPZN, RPCOMP RURD P Pull test joint RD test equipment and suck out the stack. 0.0 0.0 8/3/2023 09:30 8/3/2023 10:00 0.50 COMPZN, RPCOMP MPSP P Pull BPV. 0.0 0.0 8/3/2023 10:00 8/3/2023 10:30 0.50 COMPZN, RPCOMP SVRG P Rig service 0.0 0.0 8/3/2023 10:30 8/3/2023 11:30 1.00 COMPZN, RPCOMP THGR P Back out lock down screws. MU spear and pull tubing hanger to floor at 110K. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/4/2023 Page 2/2 3S-18 Report Printed: 8/22/2023 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) 8/3/2023 11:30 8/3/2023 12:00 0.50 COMPZN, RPCOMP OWFF P Check well for flow. No flow. 0.0 0.0 8/3/2023 12:00 8/3/2023 17:00 5.00 COMPZN, RPCOMP PULL P Pull ~3583' of 3-1/2" tubing. LD singles and send off for disposal. 0.0 0.0 8/3/2023 17:00 8/3/2023 18:00 1.00 COMPZN, RPCOMP PULL P Pull and rack back 30 stands ~2700' to use as a work shtring. 0.0 0.0 8/3/2023 18:00 8/3/2023 19:00 1.00 COMPZN, RPCOMP BHAH P Pick up RBP BHA 0.0 25.0 8/3/2023 19:00 8/3/2023 22:00 3.00 COMPZN, RPCOMP TRIP P TIH w/ RBP to setting depth @ 2682' COE // Trip in hole 60'/min // Up wt 50K // Ball on seat for setting RBP 25.0 2,682.0 8/3/2023 22:00 8/3/2023 23:00 1.00 COMPZN, RPCOMP MPSP P Set RBP // Pump 1 bpm // work pressure up 500 psi inc to allow element to seal // 3500 psi shear Good set 2,682.0 2,682.0 8/3/2023 23:00 8/4/2023 00:00 1.00 COMPZN, RPCOMP PRTS P Test RBP 1000 psi 10 min good test // Rig down test equipment 2,682.0 2,682.0 8/4/2023 00:00 8/4/2023 03:00 3.00 COMPZN, RPCOMP PULL P Pull and lay down 3.5" completion tubing 2,682.0 25.0 8/4/2023 03:00 8/4/2023 03:15 0.25 COMPZN, WHDBOP BHAH P Lay down RBP setting tool 25.0 0.0 8/4/2023 03:15 8/4/2023 04:00 0.75 COMPZN, WHDBOP PULD P Lay down 3 stands 3.5" completion tubing out of derrick 0.0 0.0 8/4/2023 04:00 8/4/2023 04:30 0.50 COMPZN, WHDBOP FRZP P Freeze protect well with 10 bbls Diesel. 0.0 0.0 8/4/2023 04:30 8/4/2023 09:00 4.50 COMPZN, WHDBOP NUND P Nipple down BOP's nipple up production tree, Rig release 9 AM. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/4/2023 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): 6900'6335' 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-18 6118' 6336' 5562' 1440 psi 6336' 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): 6545' MD and 5767' TVD 498' MD and 498' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 202-206 P.O. Box 100360, Anchorage, AK 99510 50-103-20433-00-00 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 6577' MD 108' 2547' 108' 2841' 6106'6887' 16" 9-5/8" 78' 2811' 6642-6678' (cemented) 6860' 5863-5898' (cemented) 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-80 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 10:18 am, Jul 19, 2023 323-408 8/1 Jill Simek Digitally signed by Jill Simek Date: 2023.07.18 16:19:40 -08'00' VTL 7/24/2023 MDG 7/24/2023 DSR-7/19/22 X AOGCC inspection is required after cutoff and before any remedial cementing. X 10-407 X GCW 07/24/2023JLC 7/24/2023 07/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.07.25 09:33:05 -08'00' RBDMS JSB 072523 3S-18 Plug and Abandon Procedure PTD #202-206 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 6,283ft KB. Well Type: Producer Scope of Work: Perform Plug and Abandonment of 3S-18: 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 4,737ft 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 ~4,411ft 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-18 Plug and Abandon Procedure PTD #202-206 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 169 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 2,841ft KB. Job is planned for 100 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-18 PTD #: 202-206 API #: 50-103-20433-00 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-18 P&A PTD #: 202-206 16” 62.5# H-40 Conductor @ 108' KB JS 7-17-2023 7" 26# L-80 Production Casing @ 6,887' KB 3-½” 9.3# L-80 Tubing @ 6,576' KB 9 5/8" 40# L-80 Surface Casing @ 2,841' KB Perfs: 6,642' – 6,678' KB Calculated Top of Cement (7" x Open Hole) = 5,848' KB Kuparuk HRZ/Kalubik Shales Moraine 5,930' – 6,109' KB Coyote 4,661 – 5,337' KB Packer depth = 6,545' KB Tubing cut at 6,283ft KB TOC (tubing) at 6,336ft KB Cement retainer set at 6,566' KB Cement Plug (Production Casing) Approx. 4,737' KB to Surface Cement Plug (Production Casing x Surface Casing Annulus) 2,841' KB to Surface Cement Plug (Production Casing x Open Hole Annulus) Approx. 4,561' – 4,711' KB CIBP @ ~4,737' KB Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Welltec cut at 6283' RKB 3S-18 5/20/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: PULL BROKEN LATCH @ 5329' 8/30/2012 hipshkf NOTE: TREE CAP CONNECTION: TOP 5 3/4"" ACME W/3.5"" EUE 8RD THREAD 12/2/2002 triplwj 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 29.6 2,840.6 2,547.4 40.00 L-80 BTC PRODUCTION 7 6.28 27.0 6,887.1 6,105.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.0 Set Depth … 6,577.0 Set Depth … 5,798.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.0 25.0 0.08 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 498.2 497.7 5.62 SAFETY VLV 4.540 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 2,882.6 2,581.8 34.77 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 4,311.5 3,789.7 32.21 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 5,329.7 4,645.3 29.45 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 6,002.6 5,249.7 22.46 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 6,428.8 5,652.3 11.71 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,480.9 5,703.5 9.86 SLEEVE 4.520 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE BAKER CMU 2.812 6,530.4 5,752.3 8.87 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.990 6,544.1 5,765.9 8.60 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,545.0 5,766.8 8.58 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 2.992 6,549.9 5,771.6 8.48 MILL 3.500 80-40 MILLOUT EXTENSION 80-40 2.992 6,555.4 5,777.1 8.37 COLLAR 3.500 2.992 6,569.0 5,790.5 8.22 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,576.1 5,797.5 8.20 WLEG 4.490 WLEG w/ SHEAR OUT SUB 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,283.0 5,511.4 18.07 CUT WELLTEC MECHANICAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/20/2023 2.992 6,335.5 5,561.7 15.70 FISH 1" GLV FELL TO CEMENT TOP. 5/13/2023 0.000 6,566.0 5,787.5 8.23 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/2/2023 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) 2,882.6 2,581.8 34.77 1 GAS LIFT DMY BK 1 0.0 5/15/2023 0.000 4,311.5 3,789.7 32.21 2 GAS LIFT DMY BK5 1 0.0 12/2/2002 0.000 5,329.7 4,645.3 29.45 3 GAS LIFT DMY BROK EN 1 0.0 5/7/2012 Latch Broke Off 0.000 6,002.6 5,249.7 22.46 4 GAS LIFT OPEN 1 5/13/2023 6,428.8 5,652.3 11.71 5 GAS LIFT OV RK 1 1/2 0.0 11/6/2019 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,642.0 6,678.0 5,862.8 5,898.4 C-4, 3S-18 12/8/2002 6.0 IPERF 2.5" 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,576.1 5,562.1 5,797.5 Cement Plug 5/2/2023 6,576.1 6,887.0 5,797.5 6,105.6 Cement Plug 5/2/2023 IPERF; 6,642.0-6,678.0 Cement Plug; 6,576.1 ftKB CEMENT RETAINER; 6,566.0 PACKER; 6,545.0 GAS LIFT; 6,428.8 Cement Plug; 6,336.0 ftKB FISH; 6,335.5 CUT; 6,283.0 GAS LIFT; 6,002.6 GAS LIFT; 5,329.7 GAS LIFT; 4,311.5 GAS LIFT; 2,882.6 SURFACE; 29.6-2,840.6 SAFETY VLV; 498.2 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" H-40 108' 9-5/8" L-80 2547' 7" L-80 6106' 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 6887' SIZE DEPTH SET (MD) 2538' FNL, 1149' FEL, Sec. 18, T12N, R8E, UM 1628' FNL, 3882' FEL, Sec. 18, T12N, R8E, UM 1617' FNL, 3914' FEL, Sec. 18, T12N, R8E, UM 27' 62.5# 40# 108' 27' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 2 bbl 15.8 ppg Cement on top of cement retainer 19 bbl 15.8 ppg Cement inj thru cement retainer Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 6300-6566' SUSPENDED Perforations: 6642-6678' MD and 5863-5898' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 6545' MD/ 5767' TVD PACKER SET (MD/TVD) 42" 12-1/4" 86 sx Arctic Crete 30'637 sx AS IIIL, 250 sx LiteCrete 30' 2841'30' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE CEMENTING RECORD 5994798 SETTING DEPTH TVD 5994808 TOP HOLE SIZE AMOUNT PULLED 473377 473345 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 1625' MD/ 1545' TVD N/A P.O. Box 100360, Anchorage, AK 99510-0360 476110 5993879 6300' MD/ 5528' TVD 6900' MD/ 6118' TVD ADL0380107 ALK 4624 50-103-20433-00-00 KRU 3S-18 November 23, 2002 November 30, 2002 9. Ref Elevations: KB: 28 ft Kuparuk River Field/ None-Suspended STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 5/12/2023 202-206/323-193 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 223 sx Class G w/GasBlok8-1/2" 6577' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 6566-6778' By Grace Christianson at 8:52 am, May 24, 2023 Suspended 5/12/2023 JSB RBDMS JSB 052523 xGDSR-6/12/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1625' 1545' 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 16:01:38 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,796.0 3S-18 10/6/2019 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Welltec cut at 6283' RKB 3S-18 5/20/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: PULL BROKEN LATCH @ 5329' 8/30/2012 hipshkf NOTE: TREE CAP CONNECTION: TOP 5 3/4"" ACME W/3.5"" EUE 8RD THREAD 12/2/2002 triplwj 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 29.6 2,840.6 2,547.4 40.00 L-80 BTC PRODUCTION 7 6.28 27.0 6,887.1 6,105.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.0 Set Depth … 6,577.0 Set Depth … 5,798.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.0 25.0 0.08 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 498.2 497.7 5.62 SAFETY VLV 4.540 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 2,882.6 2,581.8 34.77 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 4,311.5 3,789.7 32.21 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 5,329.7 4,645.3 29.45 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 6,002.6 5,249.7 22.46 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 6,428.8 5,652.3 11.71 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 6,480.9 5,703.5 9.86 SLEEVE 4.520 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE BAKER CMU 2.812 6,530.4 5,752.3 8.87 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.990 6,544.1 5,765.9 8.60 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,545.0 5,766.8 8.58 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 2.992 6,549.9 5,771.6 8.48 MILL 3.500 80-40 MILLOUT EXTENSION 80-40 2.992 6,555.4 5,777.1 8.37 COLLAR 3.500 2.992 6,569.0 5,790.5 8.22 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,576.1 5,797.5 8.20 WLEG 4.490 WLEG w/ SHEAR OUT SUB 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,283.0 5,511.4 18.07 CUT WELLTEC MECHANICAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/20/2023 2.992 6,335.5 5,561.7 15.70 FISH 1" GLV FELL TO CEMENT TOP. 5/13/2023 0.000 6,566.0 5,787.5 8.23 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/2/2023 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) 2,882.6 2,581.8 34.77 1 GAS LIFT DMY BK 1 0.0 5/15/2023 0.000 4,311.5 3,789.7 32.21 2 GAS LIFT DMY BK5 1 0.0 12/2/2002 0.000 5,329.7 4,645.3 29.45 3 GAS LIFT DMY BROK EN 1 0.0 5/7/2012 Latch Broke Off 0.000 6,002.6 5,249.7 22.46 4 GAS LIFT OPEN 1 5/13/2023 6,428.8 5,652.3 11.71 5 GAS LIFT OV RK 1 1/2 0.0 11/6/2019 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,642.0 6,678.0 5,862.8 5,898.4 C-4, 3S-18 12/8/2002 6.0 IPERF 2.5" 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,336.0 6,576.1 5,562.1 5,797.5 Cement Plug 5/2/2023 6,576.1 6,887.0 5,797.5 6,105.6 Cement Plug 5/2/2023 3S-18, 5/22/2023 11:46:04 AM Vertical schematic (actual) PRODUCTION; 27.0-6,887.1 IPERF; 6,642.0-6,678.0 Cement Plug; 6,576.1 ftKB CEMENT RETAINER; 6,566.0 PACKER; 6,545.0 GAS LIFT; 6,428.8 Cement Plug; 6,336.0 ftKB FISH; 6,335.5 CUT; 6,283.0 GAS LIFT; 6,002.6 GAS LIFT; 5,329.7 GAS LIFT; 4,311.5 GAS LIFT; 2,882.6 SURFACE; 29.6-2,840.6 SAFETY VLV; 498.2 CONDUCTOR; 30.0-108.0 KUP PROD KB-Grd (ft) 33.27 RR Date 12/3/2002 Other Elev… 3S-18 ... TD Act Btm (ftKB) 6,900.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043300 Wellbore Status PROD Max Angle & MD Incl (°) 35.67 MD (ftKB) 2,255.15 WELLNAME WELLBORE3S-18 Annotation Last WO: End DateH2S (ppm) 60 Date 11/10/2013 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 4/21/2023 ACQUIRE DATA DRIFT FREELY W/ 2.77" CEMENT RETAINER DRIFT (NO ANOMALIES). JOB COMPLETE 4/21/2023 ACQUIRE DATA INJECTIVITY TEST ON TUBING PUMPED 40 BBLS DSL TO LOAD TUBING THEN 20 BBLS STEP RATE INJECTIVITY TEST. TBG: FINAL STEP RATE 3 BPM 375/750/200 OA: FINAL STEP RATE: 1.75 BPM 60/825/1250 READY FOR COIL P&A. 5/1/2023 ACQUIRE DATA TAGGED D-NIPPLE @ 6569' RKB W/ CEMENT RETAINER, PICKED UP 5' TO 6564' RKB, AND ATTEMPT TO SET RETAINER (LAUNCHED 2 BALLS W/ NO INDICATION OF RETAINER GETTING SET). POOH, RECOVER BOTH BALLS AND IDENTIFY ISSUES WITH SETTING TOOL ASSEMBLY. RBIH WITH CEMENT RETAINER, TAG D NIPPLE AND PICK UP 3'. SET RETAINER AT 6566' RKB. PERFORM INJECTIVITY TEST THROUGH RETAINER. PUMP 21 BBL OF 15.8 CEMENT. INJECT 19 BBL THROUGH RETAINER AND LAY IN 2 BBL ON TOP OF RETAINER TO 6,336'. PUMP GEL PILL, CLEAN DOWN TO TARGET TOC AT 6,336' AND CHASE RETURNS TO SURFACE. READY FOR SW TAG AND TEST IN 24 HRS. 5/3/2023 ACQUIRE DATA PRE_STATE WITNESSED TAG HARD CEMENT @ 6292' SLM/6316' RKB , LRS MIT-T TO 1500 PSI (PASS) *COMPLETE* 5/5/2023 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. 5/12/2023 ACQUIRE DATA STATE WITINESS (CAM ST.JOHN) TAG TOC @ 6300' SLM. PERFORM PASSING MIT-T TO 1500 PSI. PULL DGLV FROM ST# 4 @ 6002' RKB, POCKET OPEN. IN PROGRESS. 3S-18 Suspend Cement 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:6900 ft MD Lease No.:ADL0380107 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 2841 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6887 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 6477 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 6564 ft 6300 ft 7.2 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1770 1665 1640 IA 1150 1150 1150 OA 500 500 500 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Had a good solid tag with a good cement sample in the bailer. Top of cement was supposed to be about 6334 ft MD; they tagged at 6300 ft MD. MIT-T passed (0.3 bbls in, 0.3 bbls back). May 12, 2023 Kam StJohn Well Bore Plug & Abandonment KRU 3S-18 Conoco Phillips Alaska Inc. PTD 2022060; Sundry 323-193 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0512_Plug_Verification_KRU_3S-18_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): 6900'None 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: 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 6642-6678' MD 6859' 5863-5898' TVD 3-1/2" 7" 16" 9-5/8" 78' 2810' Perforation Depth MD (ft): MD 108' 2547' 108' 2841' 6106'6887' Length Size Proposed Pools: TVD Burst 6119' 6796' 6015' 1440 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 202-206 P.O. Box 100360, Anchorage, AK 99510 50-103-20433-00-00 ConocoPhillips Alaska, Inc. KRU 3S-18 Kuparuk River Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): 6545' MD/5767' TVD 498' MD /497' TVD Perforation Depth TVD (ft): Tubing Size: L-80 6577' 6/11/2023 Packer: Baker SAB-3 Packer SSSV: Camco DS Nipple w/NoGo 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 Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Workover Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov BOP test to 2500 psig Annular preventer to 2500 psig 10-407 DSR-4/13/23 X VTL 6/12/2023 X MDG 5/24/2023GCW 06/13/2023 JLC 6/13/2023 06/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.13 17:09:07 -08'00' RBDMS JSB 061423 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 COPYRIGHTEDDATE: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 Suspension expires 6/30/2024 BJM 4/6/24 DSR-3/31/23 Inspection with AOGCC witness required within 12 months, unless the well is P&A'd earlier. Provide 10 days notice for opportunity to witness. SFD 4/5/2023 10-407 10-404 for inspection report. 04/06/23 04/06/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.06 12:16:13 -08'00' RBDMS JSB 040623 Verified cement volume -bjm Well Lo To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ! HOLES Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed : Print Name: READ Cased Hole, Inc. Attn: Diane Williams 4141 B Street Suite 308 Anchorage, AK 99503 Diane.Williams0readcasedhole com 07 -Nov -19 3S-18 1 Report / CD 202206 31470 RECEIVE NOV 19 2019 AOGCC 50-103-20433-00 Date : � ° �Iz& `q READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL: READ-ANCHORAGE(CDREADCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM SCANNED NOV 2 2 2019 hnps 'readcasedhole-my,sharepoint.com/personal/diane Williams readcasedhole com/Documents/D Drive/AchivesMaeteYl'emplateFiles?emplates�Dis[ributioM'ransmittalShuts/ConocoPhillips_Tmnsmil.d.. 202206 31470 CASED Memory Multi -Finger Caliper HOLE Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3S-18 Log Date: November 7, 2019 Field: Kuparuk Log No.: 1 State: Alaska Run No.: 15714 API No. 50-103-20433-00 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE8RDMOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 6,576 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the WLEG at 6,576 feet (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage, particularly with respect to buckling due to sub -surface subsidence. The caliper recordings indicate slight cork -screwed tubing from —5,200 feet to —6,400 feet. A 3-D log plot overlay of the centered and un - centered caliper recordings across the 3.5 inch tubing is included in this report. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with the exception of a 24% and a 21 % wall penetration in a line of pits in pup joint 0.1 (37 ft) and pup joint 189.1 (6,002 ft). No other significant wall penetrations or areas of cross- sectional wall loss are recorded. The caliper recordings indicate scale -like deposits from surface to —1,500 feet, restricting the I.D. to 2.78 inches in joint 2 (71 ft). A graph illustrating minimum recorded diameters on a joint -by -joint basis is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Description Percent Wall Penetration Joint Depth Line of Pits 24 0.1 37 Ft. (MD) Line of Pits 21 189.1 6,002 Ft. (MD) No other significant wall penetrations (> 15%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Description Minimum Recorded Diameter Joint Depth Deposits 2.78 inches 2 71 Ft. (MD) Deposits 2.78 inches 5 163 Ft. (MD) Deposits 2.79 inches 3 113 Ft. (MD) Deposits 2.79 inches 1 56 Ft. (MD) Deposits 2.79 inches 4 152 Ft. (MD) B. Suhanek C. Waldrop S. Ferguson Field Engineer(s) Analyst(-) lNitn ( 1 READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: AN5A-NorthAmerica(@readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 SCANNED NOV 2 2 2019 �e 0�1 47- 40-m- 2mw Aa' rt� ..ft W WE F }�§ ..�� = -5 i i + 01 1r s AM C mar ;) -r AST ice — 9 ZEN z-3 -+w i ___ mu Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (35Y -6,576Y) Well: 3S-18 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: November 7, 2019 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 38 790 1,571 2,351 D 3,154 ? c_ L 3,936 4,736 5,534 6,330 204.8 6,576 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey= 204.8 CASED 1.75 0.1 10' 79 29 39 49 59 69 79 minimum uiameter motile Survey Date: November 7, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 inches Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 2 2.25 2.5 2.75 96 106 116 126 136 143 153 163 170 180 189.1 197 203.1 204.7 320 604 915 1,227 1,540 1,853 2,164 2,476 2,790 3,028 3,341 3,654 3,967 4,2; 9 4,516 4,829 5,139 5,377 5,689 5,999 6,236 6,476 6,5569 W HOLE Well: 35-18 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA 1.75 0.1 10' 79 29 39 49 59 69 79 minimum uiameter motile Survey Date: November 7, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 inches Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 2 2.25 2.5 2.75 96 106 116 126 136 143 153 163 170 180 189.1 197 203.1 204.7 320 604 915 1,227 1,540 1,853 2,164 2,476 2,790 3,028 3,341 3,654 3,967 4,2; 9 4,516 4,829 5,139 5,377 5,689 5,999 6,236 6,476 6,5569 W Penetration (% wall) Damage Configuration (body) 10 8 6 4 -- 2 0 - –– --� i Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole �- -- —N-U_mm4€r�)_jpynYs_damaged 0 0_ 3 0 0 Damage Profile (% wall) 1111110 Penetration body Metal loss body 0 50 0.1 �T -T 49 GLM 1 (1:00) GLM 2 (6:00) — - 143 GLM 3 (3:30) -- GLM 4 (10:00) GLM 5 (8:00) CASED [Country: -� HOLE Body Region Analysis Well: 3S-18 Survey Date: November 7, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches USA No. of Fingers: 24 _. Pipe 3.5 in. 9.3 ppf L-80 EU E8RDMOD Analyst: Waldrop Pipe Morn &D Weight Grade & Thread Nom.ID Top Depth Bottom Depth — 35 in. _ 9.3 ppf _ L-80 EUE8RDMOD 2.992 in. 35 ft. _ _ __ 6,576_ft. J Penetration (% wall) Damage Configuration (body) 10 8 6 4 -- 2 0 - –– --� i Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole �- -- —N-U_mm4€r�)_jpynYs_damaged 0 0_ 3 0 0 Damage Profile (% wall) 1111110 Penetration body Metal loss body 0 50 0.1 �T -T 49 GLM 1 (1:00) GLM 2 (6:00) — - 143 GLM 3 (3:30) -- GLM 4 (10:00) GLM 5 (8:00) Bottom of Survey = 204.8 100 �SASE HOLE Well: 3S-18 Field: Kuparuk Company: ConocoPhillipsAlaska, Inc _ Pipe Description 3.5 in. 9.3 ppf L-80 EUE8RDMCD Tubing Joint Tabulation Shee Survey Date: November 7, 2 Analyst: Waldrop Nom. ID 2.992 in. Body Wall Top Depth Bottom Depth 0.254 in. 35 ft 6,576 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments(%wall) Damage Profile 10 50 100 0-A 1 2 35 38 _ 70 0.04 0 0 0.06_ 0.02 _ 0.02 24 _9 7 4 0 1 2.91 2.79 2 .78 Pu Line of Pits. Lt. Deposits. Deposits. D. e osits _ 3 100 0 0.02 6 0 2.79 e osits.4 Deposits - 4 132 _ 0 0.02 6 2.79 De osits. 5 6 163 194 00.01 1 0 0.01 4 5 _0 0 0 2.78 2.80 Deposits_ Deposits. _ 7 226 0 0.03 10 0 2.81 Deposits. 8 257 1 0 0.02 _ 7 0 _280 _. Deposits. 9 288 1 0 0.02 7 0 1 2.79 De osits. 320 0 0.03 10 2 2.81 Lt. Deposits. A10 11 351 0 0.02 9 0 2.81 Deposits. 12 383 0 0.03 10 1 2.81 Lt. De osits. 13 414 0 0.03 10 1 2.83 Lt. Deposits. 14 445 -0 ---0.03 11 _2 2.84 Lt. Deposits. 15 477 I_0 0.02 6 2 2.84 Lt Deposits. 15.1 508 0 0 0 0 2.86 Camco DS Ni le _ 16 509 0 _ 0.02 6 0 2.84 Lt. Deposits. 17 541 0 0.03 _ 12_ 3 1 2.84 Lt Deoosits. 18 572 0 0.02 9 1 2.86 Lt. Deposits. 19 604 0 0.01 1 5 0 2.84 Lt. De osits. 20 633 0 0.03 10 _ 3 2.85 Lt. Deposits. 21 665 0 0.03_ 10 4_ 2.85 Lt Detosits 22 696 0 0.03 12 4 2.85 Lt. Derrosits. 23 728 1 0 0.03 12 2 2.89 Lt. Deposits. 24 759 0 0.03 12 3 2.85 Lt. Devosits. -- 25 790 0 0.03 11 4 2.86 Lt Dits.e os 26 822 0 0.03 10 2 2.87 Lt. De osits. 27 853 I _ 0 0.02 9 2 2.86 Lt. Deposits. _ 28 883 1 0 0.03 11 1 2.87 Lt. De osits. 29 915 0 0.02 9 3 2.87 Lt. De osits. 30 _ 31 32 946 977 1008 1_ 0 0 0 0.02 0.02 0.03 7 7 13 1--2.87 2 _ 2.89 1 2.86 Lt. Deposits_ Lt, Deposits. Lt. Deposits. 33 34 1040 1071 0 0 0.03 0.03 112 11 1 _ 2.86Lt 2.89 De osits_. Lt. Deposits. _- 35 1103 0 0.03 11 2 2.91 Lt. De osits. 36 1134 0 0.02 7 2 2.90 Lt. Deposits. 37 38 39 1165 - 0- 1196 1 0 1227 0 0.02 0.03 _ 0.04 9 11 14 12.89 2 8 2.88 2.91 Lt Degpsits. Lt. De osits. Lt. Deposits. 40 12590 0.03 10 22.91 Lt. Deoosits. - 41 1290 0 _ 0.02 9 3 _ 2.90 Lt. Deposits. 42 1321 0 om-L 7 3 2.90 It Deposit,. 43 1352 0 0.03 13 6 2.91 Lt. De osits. 44 1384 -_ 0 0.02 1 8 3 _I 2.90 Lt. _Deposits._ __._- 45 1415 0 0.03 1 11 5 1 2.90 Lt. De osits. 46 1447 0 0.02 1 9 4 2.93 Lt. De osits. 47 1478 0 0.03 12 6 2.92 2.91 Lt. Deposits. _ -- - - _L#. Deposits. -- 48 1509 0 0.03 10 5 Penetration Body Metal Loss Body Page 1 CASED HOLE Joint Tabulation Sheet Well: 35-18 Survey Date: November 7, 2019 Field: Kuparuk Analyst: Waldrop Company: Cono coPhi[lips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE8RDMOD Tubing 2.992 in. 0.254 in. 35 ft 6,576 ft. Joint Jt. Depth P. Pen. Pen. Na (FL) Upset Body % (in.) (in.) Metal Loss % Min, 1. D. (in.) Damage Profile Comments (% wall) 0 50 100! 49 1540 0 0.02 9_ 4 3 _ _2.89 2.91 Lt._Deposits._ Lt. 50 1571 _ 0 0.02_ 7 51 1603 0 0.02 8 2 1 2.90 Lt. Deposits. 52 1634 0 0.02 8 3 2.93 53_ 1665 0 0.02 7 2 2.90 Lt. Depo,it,. 54 1697 0 0.02 8 - 3 2.92 Lt Deposits..__ 55 1728 0 0.03 10 2 2.92 Lt. De osits. 56 1759 _ 0 _ 0.02 7 2 2.92 Lt. Deposits.___. 57 1790 0 0.02 _7 58 1822 0 0.02 6 2 2 2.92 2.91 Lt. Deposits.__ Lt. De osits. 59 1853 0 0.02 8 2 2.95 60 1884 , 0 0.02 _.7 2 2.92_ Lt. Deposits. 61 1915 0 0.02 6 2 2.92 Lt. De osits. 62 1946 0 0.02 1 6 2 2.92 Lt. De osits. 63 1978__ 0 0.02 8 2 2.92 _ Li. Deposits.____,,, 64 2009 0 0.02 7 2 2.93__ _ Lt. Deposits. 65 2046 0 0.01 i 6 2 2.90 Lt. De osits. 66 2072 _ 0 0.03 - 11 _.._ 2 �_ 22 92_ Lt. Deposits. - - _67 2103 0 0,02 6 2 _ 2_91_ _LtD�osits_. 68 2133 0 0.01 5 1 2.92 Lt. De osits. 69 2164 0 0.03 i 12 2 1 2.92 1 Lt. Deposits. 70 _ 2196 _ 0 _ 0.015 2 2.92 „Li. DeDesits. ��OBItS. 71 2227 00.0 6 2 2.92 72 2258 0 0.02 6 1 2.92 Lt. De osits. 73 2290 0 0.02_ 7 __2 2.93 Lt.osits. Ltosits. i 74 2320 0 0.02 9 2 2.93 75 2351 0 0.02 8 3 2.91 Lt. De osits. - 76 2382 0 0.03 12 2 2.91 Lt. De osits. 77 2413 0 0.02 _ 6 2 2.92 Lt. Deposits.___ Lt. De osits. 78 2445 0 0.02 6 2 2.92 79 2476 0 0.03 11 2 2.91 Lt. De osits. 80_ 2508 0 0.02 _ 9 X81 2539 0 0.01 5 2 2.92 2.92 Lt. Deposits. 1 t_Dpnosits. Lt. De osrts _ 2_ 82 2570 0 0.01 5 2 2.91 83 2602 0 _ 0.02 7 2 2.94 84 2633 0_ 0.02 _ 6 1 2.92 Lt. De_posits. _ - - ..-- - Lt. De osits. 85 2664 0 0.02 7 2 2.92 86 2696 0 0.02 6 2 2.92 Lt. De osits. 87 2727 0 0.01_1 5 1 _2.91_ _Lt. D osits_ Lt. Deoosits. - U. De osits. I 88 2758 0 0.011- 6 _2_ 2.92 89 2790 0 0.01 5 2 2.92 90 2821 0 0.02 8 2 2.94 Pu DeDesosits. - - - --- 9911 28584 _r 0 0.02 - 9 --- 2 2.92 91.2 2890 0 0 0 0 2.90 CLM 1 Latch @ 1:00 I 973_. 2896 __..0 0.02_ 7_ 92 1 2902 10 0.03 10 _ 2 ,_2.92 -PuL_Deposits._-__ 2 2.94 ---- 93 2934 0 0.02 7 2 2.94 94 __. -2966 0 0.027_ 2 2.92 Lt. Deposits, 95 2997 0_ 0.02 -7 _ 2 2.92 _ Lt. Deposits._ Penetration Body Metal Loss Body Page 2 �CASED HOLE Joint Tabulation Sheet Well: 35-18 Survey Date: November 7, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUEBRDMOD Tubing 2.992 in. 0.254 in. 35 ft 6,576 ft. Penetration Body Mehl Loss Body Page 3 FFioeld: CASED HOLE : 3S-18 Kuparuk pany: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE8RDMCD Tubing loint Tabulation Sheet Survey Date: November 7, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 35 ft 6,576 ft. Jo No. 0 Jt. Depth (Ft.) Pen. Upset Pen. Body (in.) Peon. Metal Loss % Min. 1. D. (in.) Comments l Damage Profipset (% wall) 0 50 10 143 451 6 0 0.02_-7 2 295 2.91 2.93 _ Lt_Dsits. Lt. n --- e -146 r 144 4547 0 0.03 12 _ 2 145 4579 0 0.02 9 4 146 4610 0 0.03 10 4 2.91 Lt. De -sits. 147 148 149 4642 4673 4704 0 0.03 0:02_ 11 9 4 3 1 2.90 2.91 2.92 1 L _DenOSlt$. _ _ _ _____ Lt. Deposits._ Lt. Deposits. - _0 0 0.02 6 2 150 4736 0_ 0.03 10_ 2 2.94 _2.89 2.91 _ Lt, Dep -sits_ Lt. De osits. _ 151 _ 4766 _0 0.02 _7 __ 1 152 4798 0 0.03 I 11 3 153 4829 0 0.02 9 2 2,88 It De ,sits. 154_ 4860_ 0 0.02_ 7 1 _2.91 2.90 Lt. Deposits. Lt. De -sits. - _ ._ 155 4891 0 0.02 t 9 2 156 4923 0 0.03 11 3 2.91 Lt. De -sits. 157. 158 159 _4954 4984 5015 0 _- 0 _ 0 0_02 _ 0_03_ 0.02 9 12 8 _ 3 1 2.90.,- 2 I 2.91 2 2.92 Lt. Deposits Lt. Deposits. Lt. De osits - - 160 _161 _ 5046 5077 _ 0 0 0.02 0_03__ 7 12 - 1 6 1 2.90 2.91 2.90 Lt. Deposits _ Lt. De_nsits. P Lt. De -sits. - 162 5108 0 0.02 7 2� 163 5139 0 0.02 6 2 2.95 _164 165 5170 5202 0 - 0 0 _0.01 _0.02 0.02 5 17 9 2 _2_ 2 2.91 2.92 _Lt. Deposits.. - _-- -_- Lt. Deposits. _ Lt. Deposits. __-- - - 166 5233 167 5264 0 0.03 11 4 2.91 _2.91 2.91 Lt. Deposits._ _ Lt. Deposits.__ Pu Lt. De -sits. - 168 5295 0 0_02 8 2 168A 5327 0 0.02 7 2 168.2 5333 0 0 0 0 1 2.85 GLM 3 ft atch Q 3:30 168.3 169 5340 5346 0 0 0.03_ 0.02 12_ 8 3. 2.89 32.89 PuaLt. Deggsits. Li. De -sits. 170 5377 0 g 3 2.89 Lt. De -sits. 71 172 5408 5440 0.03_. 12 4 2.89 2 91_ 2.90 Lt.�losits. _...____ Lt. Deposits.____ Lt De osits _0 00-002 _ 0 - _ 7 _2- 0 0.02 7 2 _ _ 173 5471 174 5502 0 0.03 12 2 2.89 _2.91 2.90 Lt. Deposits -- - _ Lt Den-osits __. Lt Deposits.- 175 5534 176 5565 1 0 0.02 _7. _1 0 0.03 11 2 177 5596 1 0 0.02 8 4 2.91 Lt. Deposits 178 179 180 5627 1 5658 �_ 5689 _ _0 0 0 0.02 0.02_1_ 0.01 8 7 5 3 2.89 2 2.90 Lt. Deposits. Lt. De -sits. _ -- 181 _ 5720 0 10 6 2_ 2 90 2_ 2.89 Lt. Deposits. ,__ Lt. Degosits. - Shallow Line of Pits. Lt. De -sits. __ _782 575-0 002 183 5783 0 0.04 15 2 2.90 184 5814 0 0.03 it 4 2.90 Lt. De osits. 185 186 5845 5877 _ 0 0 0.02 0.02 _ 6_ 7 _2 2.90 2 2.90 Lt. Deposits. - _ -- _-- Lt. De osits. - 187 5907 0 0.02 8 1 2.90 Lt. De osits. 188 _ 183555969 5938 F-0 1. 0 _ 0_02 0_03 8_ i 1 2 2.90_. 3_2.90 Lt. Deas, Lt. Deposits.- eposits Page 4 0 Penetration Body Metal Loss Body r- -=�ff Well: Field: Company: - I CASE® HOLE 3S-18 Kuparuk ConocoPhillips Alaska, Inc. _ Joint Tabulation Sheet Survey Date: November 7, 2019 Analyst: Waldrop 3.DPipe escripbon .5 in. 9.3 ppf L-80 EUE8RDMDD Tubing Nom. ID - Body Wall Top -Depth Bottom Depth 2.992 in. 0.254 in. 35 ft 6,576 ft. Joint No. It. Depth (Ft.) Pen Upset (in.) Pen, Body (in.) Pen. 90 Metal Loss % 1 Min. 1. D. (in.) Damage Profile Comments (% wall) 0 50 100 189_5999 0 _ 0.05 21 3 2.96 Line of Pits. , 189.2 6005 1 0 0_ 0 0 .Pup _ 2.84 GLM 4 Latch @ 10:001 2.89 Pu Lt. De osits. _ 012 189.3 6 0 0.02 7 2 190 6018 0 0.02 6 1 2.90 Lt. Deposits. 191 6049 1 0 0.02 7 3 2.92 Lt. De osits. 192 6079 0__ 0.02 6 i 2.89 _ Lt D�sits_ 193 6111 0 0.02 9 1 2.90 Lt. De osits. _ 194 6142 _ _ 0 _0.,02 7 2 2.90 Lt. Deposits. 195 6173 _ 0 0_021 7 1 12.91 2.91 Lt Deposits. Lt. Deposits. 196 6205 0 0.02 1 9 4 197 6236 0 0.01 6 2 2.90 Lt. Deposits. 198 199 6267 6299 0 0 0.02_. 0.02 9_ 7 _ 3 2 2,91 - 2.90 Lt. Deposits._ _ Lt. De osits. 200 6330 0 0.02 9 4 2.90 Lt. De osits. 2016361_ 0 0.02 7 2 2.89 Lt. Deposits._ 202_ 6393 0 0.02 9 4 2.92 Lt. Deposits. 202.1 6424 0 0.02 8 2 2.93 Pup Lt. Deposits. 202.2 - - 202.3 6430 6438 - 1 0 0 0 0.02 0 9 0 2 2.89_ 2.94 GLM 5 Latch @�:0�__ - Pu__ 203 6444 0 0.02 6 3 2.89 Lt. De osits. I 20 3.1 6476 0 0.02 26 2 2,92 Pu Lt. Deposit 203.2 6482 _ 0-0- 0 3_+- 2.7-8 Baker CMU Sliding -Sleeve 203.3_ 6486 1 _0 0.03 ,11 2 289 2.91 _Pup�Lt Deposits. Lt. Deposits. - - _I 204 6492 0 0.02 8 3 1 204.1 6523 _ 0 0.02 7 22.89 Pup Lt. De>ts. SealAssembly 204.26529 0 0 0 0 2.87 204.3 6543 0 0 0 0 2.90 Baker SAB -3 Packer 204.4 6556 00.02 9 2 2.84 Lt. Deposits. 204.5 6562 00.027 ? _, 2.89 -Pun Pui3 Lt Carrico D Nipple - - 204.6 6568 0 0 0 0 2.72 204.7 6569 0 0.03 12 3 2.82 Pup Lt. De osits. 204.8 6576 Q- 0 0 0 3.16 WLEG Penetration Body Metal Loss Body Page 5 CASED HOLE Cross-sectional Illustration Well: 3S-18 Survey Date: November 7, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE8RDMOD _ Analyst: Waldrop Cross Section for Joint 0.1 at depth 36.820 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 3° Finger= 17 Penetration= Line of Pits —=_ CASED HOLE Cross-sectional Illustration I Well: 35-18 Survey Date: November 7, 2019 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 L Tubing_ _3.5 in. 9.3 ppf L_80 EUE8RDMOD Analyst -_ _- Waldrop _ Cross Section for Joint 189.1 at depth 6,002.120 ft Tool speed = 51 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 97% Tool deviation = 25° Finger = 15 Penetration = 0.054 in. Line of Pits 0.05 in. = 21% Wall Penetration HIGH SIDE = UP Cross-sectional Illustration Survey Date: November 7, 2019 Tool Type: UW MFC 24 No. 214320 CASED 1.69 inches No. of Fingers: HOLE Well: 3S-18 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: ___ 3.5 in, 9.3 ppf L-80 EUE8f Cross-sectional Illustration Survey Date: November 7, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 2 at depth 70.740 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area= 100% Tool deviation = 2° Minimum I.D. = 2.781 in. Deposits Minimum I.D. = 2.72 in. HIGH SIDE = UP CASED HOLE Well: 3S-18 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing_ 3.5 in. 9.3ppf -L-80 EUE8RDMOD Cross-sectional Illustration Survey Date: November 7, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 inches No. of Fingers: 24 _-Analysst:- Waldrop Cross Section for Joint 5 at depth 163.380 ft. Tool speed = 51 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 100 Tool deviation = 2° Minimum I.D. = 2.784 in. Deposits Minimum I.D. = 2.78 in. HIGH SIDE = UP • STATE OF ALASKA Alt OIL AND GAS CONSERVATION COMMSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other r WAG to Prod Alter Casing r Pull Tubing r Perforate New Pool r Waiver r lime Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r . - 202 -206 3. Address: 6. API Number.. P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 1,7 50 103 - 20433 - 00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 380107 " 3S - 9. Field /Pool(s): -, Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6900 feet Plugs (measured) None true vertical 6119 feet Junk (measured) None Effective Depth measured 6900 feet Packer (measured) 6545 true vertical 6119 feet (true vertucal) 5767 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 108 108' SURFACE 2810 9.625 2841 2547' PRODUCTION 6859 7 6887 6106' RECEI V zo1L D AUG A UG AU 10 Perforation depth: Measured depth: 6642 - 6678; 2012 True Vertical Depth: 5863 - 5899 AOQc Tubing (size, grade, MD, and ND) 3.5, L - 80, 6576 MD, 5798 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER SAB -3 PACKER @ 6545 MD and 5767 ND 'NIPPLE - CAMCO DS LANDING NIPPLE MD= 498 ND= 498 I 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 2502 450 1200 Subsequent to operation 494 1046 5091 1318 156 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development n _ Service r Stratigraphic r 15. Well Status after work: Oil pi Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 16. 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 311 -386 Contact NSK Production Engineering Specialist Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature A �( Phone: 659-7535 Date S-8 • /Z \_`^ 'Y- AUG la 1012 .ti Form 10 -404 Revised 10/2010 Pi- 4 / Slibmit Original Only rl� 3S -18 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/06/12 State Witnessed (Lou Grimaldi) MITIA Passed to 4140 psi. Initial T /I /O = 2300/1360/460. IA Starting T /I /O = 2300/4140/670. 15 min T /I /O = 2300/4020/630. 30 min T /I /O = 2300/4000/610. Passed. Bled IA from 4000 psi to 900 psi (3.5 bbls). Final T /I /O = 2300/900/320. 07 /14112IConvert from MI injection to Oil Production • " KUP • 3S -18 ...... �� « ��t; Well Attributes ps 0 Wallbore APl /UWI Field Name Well Status Maximum Inclination ( °) Total Depth (ftKB) Alaska. Inc. 501032043300 KUPARUK RIVER UNIT PROD 35.67 6,900.0 LOf MC'{h '4>S Comment H2S (ppm) Data Annotation End Date KB-Grd (ft) Rig Release Date •'• Well Coact - 35-16, 8/1/2008 10'44'18 AM , NIPPLE ... 60 1/1/2008 33.27 12/3/2002 Schematic - Actual Annotation Depth (RKB) End Date Annotation End Date Last Tag: 6,781.0 7/20/2008 Rev Reason: TAG SLM RATHOLE 8/1/2008 Casing Strings — — — - Set Depth Set Depth (TVD) Wt Casing Description OD (in) ID (In) Top (RKB) (RKB) (MB) (Iba/ft) Grade Top Thread CONDUCTOR 16 15.062 0.0 108.0 108.0 62.50 H -40 WELD SURFACE 95/8 8.697 0.0 2,840.0 2,546.9 40.00 L-80 BTCM HANGER, 25 - PRODUCTION 7 6.151 0.0 6,887.0 6,105.6 26.00 L-80 BTCM Tubing Strings Set Depth CONDUCTOR, Tubing Description OD (in) ID (in) Top (B) (ftK8) Sat Depth (TVD) (ftK8) Wt (Ibs/ft) Grade Top Thread 108 TUBING 3 1/2 2.992 0.0 6,577.0 5,798.5 9.30 L-80 EUE8rd Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) _ Top (ftK8) Description Comment Run Date ID (in) SSSV, 498 II 25.0 HANGER FMC 3.5" GEN 5 TBG HANGER 12/2/2002 3.500 498.0 SSSV NIPPLE CAMCO 'OS' LANDING NIPPLE W/NO GO PROFILE 12/2/2002 2.875 2,882.0 GAS LIFT CAMCO/KBUG/1/GLV/BK-5/.188/1865/ Comment: STATION #1 7/3/2005 2.920 SURFACE, 4,311.0 GAS LIFT CAMCO/KBUG/1/DMYBK-5/// Comment: STATION #2 12/2/2002 2.920 2,840 5,330.0 GAS LIFT CAMCO/KBUG /1/GLVBK- 5/.25/2097/ Comment STATION #3 7/3/2005 2.920 6,002.0 GAS LIFT CAMCO/KBUG/1 /DMY /BK -5/// Comment: STATION #4 12/2/2002 2.920 6,429.0 GAS LIFT CAMCO/MMG/1.5/OV /RK/.25// Comment: STATION #5 7/3/2005 2.920 GAS LIFT, 2,882 T, — 6,481.0 SLEEVE -C BAKER SLIDING CMU SLEEVE W/2.812' DS PROFILE - dosed 12/2/2002 2.812 -- 6,530.0 PBR BAKER 80-40 PBR 12/2/2002 2.990 6,544.0 ANCHOR ANCHOR NIPPLE 12/2/2002 2.993 NIPPLE TUBING, 0 6,545.0 PACKER BAKER SAB -3 PACKER W/4.5" MILLOUT EXTENSION @6549 W/3.75" ID 12/2/2002 3.250 -- 6,569.0 NIPPLE CAMCO 'D' NIPPLE 12/2/2002 2.750 GAS LIFT, 6,576.0 WLEG BAKER PUMP OUT SUB 12/2/2002 2.990 4,311 6,577.0 TTL 12/2/2002 2.992 - Perforations Shot Top (TVD) Btm (TVD) Dens GAS LIFT, _, Top (RKB) Btm ( RKB ) (RKB) (RKB) Type Zone (ahot... Date Comment 5,330 6,642.0 6,678.0 5,862.8 5,898.5 IPERF C-4, 3S -18 6.0 12/8/2002 2.5" 2506 PJ, 60 deg ph Notes: General & Safety End Date Annotation -_ 12/2/2002 NOTE: TREE CAP CONNECTION: TOP 5 3/4 "" ACME W/3.5 "" EUE 8RD THREAD GAS LIFT, s - 12/2/2002 NOTE: TREE: FMC / GEN 5 / 5M 6,002 ■ GAS LIFT, 6,429 I SLEEVE -C, 6,481 1 PBR, 6,530 I ANCHOR (1111 NIPPLE, 6,544 ((��(] i i PACKER, 6,545 NIPPLE, 6,569 WLEG, 6,576 TTL, 8,577 IPERF, 6,642-6,678 IPERF, PRODUCTION, 6,687 TD,6,900 z5 Z zee Regg, James B (DOA) From: Smith, Travis T [Travis.T.Smith @conocophillips.com] 1 � 1 ��l v Sent: Tuesday, August 07, 2012 4:48 PM To: Regg, James B (DOA) Subject: RE: 3S -18 Huff & Puff; Sundry 311 -386 Hello Jim- - I'm sorry about the delay in getting back to you -- I was out when this was sent, and it got delayed in the shuffle of emails. I will include the PTD number on future correspondence. The gas rates are MCF /day, water is in Bbl /day. PROD_FORM_CD is an indicator of whether the well is completed in the Kuparuk A -sand, C -sand, or both. I will include the plots in the future reports as well. Thanks, SCANNED k1k 0 7 2013 Travis From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 21, 2012 11:58 AM To: Smith, Travis T Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: 3S -18 Huff & Puff; Sundry 311 -386 Please add PTD 2022060 to your correspondence; we do not file and track well activities by Sunday and API #'s; we use PTD. Need some help with the data table: Gas/MI Rates in Mcf /day . What is PROD FORM CD? Water rates in Bbl/day? lumns would not be relevant to this trial Wa (co trial) If not too much trouble, I would appreciate your monthly report including plots of pressures (Tubing, IA. OA) and rate (produced and injected). Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage. AK 99501 907- 793 -1236 From: Smith, Travis T [mailto: Travis .T.Smith @conocophillips.com] Sent: Wednesday, June 20, 2012 4:59 PM To: Seamount, Dan T (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Specialist; CPF3 Prod Engrs; Seitz, Brian Subject: 3S -18 Huff & Puff; Sundry 311 -386 Hello: 1 • • The•administrative approval for Sundry 311 -386 (Kuparuk 3S -18 Huff & Puff trial) requires in #5 "CPAI shall submit to the AOGCC a monthly report of well pressures regardless of well status and injection rates while injecting ". Please find attached a report of injection rates and well pressures for May 2012. If you have any questions, please let me know. Sincerely, Travis Smith Drillsite Petroleum Engineer - 3B, 3F, 3G, 3J, 3S ConocoPhillips Alaska, Inc. Travis.T.Smith@conocophillips.com 907.265.6450 2 • kt 3 S- ► Prb 20Z- 206, o Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, June 21, 2012 11:58 AM To: 'Smith, Travis T' Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Subject: RE: 3S -18 Huff & Puff; Sundry 311 -386 Please add PTD 2022060 to your correspondence; we do not file and track well activities by Sundry and API #'s; we use PTD. Need some help with the data table: Gas /MI Rates in Mcf /day? What is PROD_FORM_CD? Water rates in Bbl /day? (columns would not be relevant to this trial) If not too much trouble, I would appreciate your monthly report including plots of pressures (Tubing, IA, OA) and rate (produced and injected). Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 JUL 8 dj l/ Anchorage, AK 99501 907 -793 -1236 From: Smith, Travis T [mailto: Travis .T.SmithOconocophillips.com] Sent: Wednesday, June 20, 2012 4:59 PM To: Seamount, Dan T (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Specialist; CPF3 Prod Engrs; Seitz, Brian Subject: 3S -18 Huff & Puff; Sundry 311 -386 Hello: The administrative approval for Sundry 311 -386 (Kuparuk 3S -18 Huff & Puff trial) requires in #5 "CPAI shall submit to the ✓ AOGCC a monthly report of well pressures regardless of well status and injection rates while injecting ". Please find attached a report of injection rates and well pressures for May 2012. If you have any questions, please let me know. Sincerely, Travis Smith Drillsite Petroleum Engineer - 3B, 3F, 3G, 3J, 3S ConocoPhillips Alaska, Inc. Travis.T.Smith pnconocophillips.com 907.265.6450 1 KRU 3S -18 Pressures and Temperature 4000 — - - -_ �_ -- - -- 45 :::: 40 - - - -_— _ __ 2500 - __ —_ f - 3 5 a 3 cu 2000 m 4 -�..., a E a` 30 r 1500 1000 ''''*"..*%".444."...* / - 25 500 • 0 . - 20 05/22/12 05/23/12 05/24/12 05/25/12 05/26/12 05/27/12 05/28/12 05/29/12 05/30/12 05/31/12 Date --CIA ----.CM -- »-WHP -- Temperature' KRU 3S -18 Injection and Production Rates 3500 – - 24 3000 - - • - 20 2500 A — - 16 c o 0 2000 a G 'c 2 - 12 tv o m 1500 La o 8 x f 1000 �_ —1 4 500 NOPPI.°Y `i\ • 0 --- —, 0 5/22/12 5/23/12 5/24/12 5/25/12 5/26/12 5/27/12 5/28/12 5/29/12 5/30/12 5/31/12 Date —Gas Production --MI Injection —MI Hrs STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM4110ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Fbrforations r Stimulate r Other r.7, Prod to WAG Alter Casing r Pull Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r — 202 - 206 3. Address: 6. API Number: — Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20433 - 00 " 0I0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 380107 , ` 3S - 9. Field /Pool(s): r Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6900 feet Plugs (measured) None true vertical 6119 feet Junk (measured) None Effective Depth measured 6900 feet Packer (measured) 6545 true vertical 6119 feet (true vertucal) 5767 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108' SURFACE 2810 9.625 2841 2547' PRODUCTION 6859 7 6887 .61.06'. E,C Wel) Perforation depth: Measured depth: 6642 - 6678; / � ,SUN 1 9 2412 True Vertical Depth: 5863 -5899 cL� N D JUN ', AOG Tubing (size, grade, MD, and TVD) 3.5, L - 80, 6576 MD, 5798 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3 PACKER © 6545 MD and 5767 TVD (NIPPLE - CAMCO DS LANDING NIPPLE MD= 498 TVD= 498 I 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 472 1910 5678 1802 236 Subsequent to operation 0 1010 0 950 2112 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service' i Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG GINJ r SUSP r SPLUG r 16. 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: 311 -386 Contact NSK Production Engineering Specialist Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature � 1, 4"'-""' Phone: 659 -7535 Date ( I y � (.� �DMS JUN 2 0 1012 ( lL Form 10-404 Revised 10/2010 6 _/,(. Submit Original Only ,ter (a- • 3S -18 • - DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/23/121WeII converted to MI Injection 06 /06 /12ISTATE WITNESSED (LOU GRIMALDI) MITIA PASSED TO 4140 PSI. 1 1 1 1 ., t KUP 3S -18 Conoco Phillips 04 Well Attributes Alaska. )n` Wel!bore API /UWI Field Name Well Status Maximum Inclination ( °) Total Depth (RIM corlocnvrril9ps 501032043300 KUPARUK RIVER UNIT PROD 35.67 6,900.0 Comment H23 (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date Well ConBO - 35.18 8/1200810:44:18 AM ,NIPPLE 60 1/112008 33.27 12/3/2002 Schematic - Actual Annotation Depth (ftKB) End Date Annotation End Date Last Tag: 6,781.0 7/202008 Rev Reason: TAG SLM RATHOLE 8/12008 Casing Strings - - - - -- Sat Depth Set Depth (TVD) Wt Casing Description OD (In) ID (In) Top (61(13) (RKB) (RKB) Wt Grade Top Thread CONDUCTOR 16 15.062 0.0 108.0 108.0 62.50 H -40 WELD SURFACE 9 5/8 8.697 0.0 2,840.0 2,546.9 40.00 L -80 BTCM HANGER, 25 . ' PRODUCTION 7 6.151 0.0 6,887.0 6,105.6 26.00 L -80 BTCM • Tubing Strings Sat Depth CONDUCTOR, _. Tubing Description 00 (In) ID (In) Top MUM MRS) Set Depth (TVD) (61513) Wt (16s /ft) Grade Top Thread toe TUBING 3 12 2.992 0.0 6,577.0 5,798.5 9.30 L EUEBrd Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top (61513) Description Comment Run Date ID (In) SSSV, 498 It 25.0 HANGER FMC 3.5' GEN 5 TBG HANGER 12/2/2002 3.500 498.0 SSSV NIPPLE CAMCO'DS' LANDING NIPPLE W/NO GO PROFILE 1222002 2.875 2,882.0 GAS LIFT CAMCO/KBUG /1 /GLVBK - 5/.188/1865/ Comment; STATION #1 7/3/2005 2.920 SURFACE. 4,311.0 GAS LIFT CAMCO/KBUG /1 /DMY /BK -5 /// Comment; STATION #2 12/2/2002 2.920 2,840 5,330.0 GAS LIFT CAMCO/KBUG /1 /GLVBK -5 /.252097 / Comment STATION #3 7/3/2005 2.920 6,002.0 GAS LIFT CAMCO/KBUG /1 /DMY /BK -5 /// Comment: STATION #4 12/2/2002 2.920 — - 6,429.0 GAS LIFT CAMCO/MMG /1.5/OV /RK/.25 // Comment: STATION #5 7/3/2005 2.920 GAS LIFT. 2,6e2 = 6,481.0 SLEEVE -C BAKER SLIDING CMU SLEEVE W2.812" DS PROFILE - closed 12/2/2002 2.812 6,530.0 PBR BAKER 80-40 PBR 12/2/2002 2.990 6,544.0 ANCHOR ANCHOR NIPPLE 12/2/2002 2.993 NIPPLE TUBING, 0 6,545.0 PACKER BAKER SAB -3 PACKER W/4.5" MILLOUT EXTENSION CA6549 W/3.75" ID 12/2/2002 3.250 6,569.0 NIPPLE CAMCO 'D' NIPPLE 12/2/2002 2.750 GAS LIFT, 6,576.0 WLEG BAKER PUMP OUT SUB 12/2/2002 2.990 4,311 6,577.0 TTL 12/2/2002 2.992 III Perforations Shot Top (TVD) Btm (TVD) Dens GAS 5 FT, _ Top (ftKB) Btm (61(8) (648) (61(8) Type Zone (shot... Data Comment U 330 6,642.0 6,678.0 5,862.8 5,898.5 IPERF C -4, 3S-18 6.0 12/8/2002 2.5" 2506 PJ, 60 deg ph I Notes: General & Safety End Data Annotation _... 12/2/2002 NOTE: TREE CAP CONNECTION: TOP 5 3/4 "" ACME W/3.5 "" EUE 8RD THREAD GAS LIFT, 12/2/2002 NOTE; TREE: FMC / GEN 5 / 5M 6.002 GAS LIFT, 6,429 SLEEVE -C, .. 6.481 PBR. 6.530 - r ■ ANCHOR 1r 11 NIPPLE, 6,544 I I r 1 PACKER. 8.545 II NIPPLE, 8,569 II Ti WLEG. 6.575 -- 1 TTL 6 577 ■ -8678 II I 8,84 IPERF, 6 PRODUCTION, 6,887 N. TD.6.900 , Prb .oho Regg, James B (DOA) From: Smith, Travis T [Travis.T. Smith @conocophillips.com]� 6 /g J � v Sent: Thursday, June 07, 2012 5:08 PM � �? 1 To: Regg, James B (DOA); Seamount, Dan T (DOA) Cc: Seitz, Brian; CPF3 Prod Engrs; NSK Well Integrity Proj Subject: 3S -18 Huff & Puff Trial Dear Mr. Seamount: Per Sundry #311 -386, Kuparuk well 3S -18 was converted to MI injection service and put on injection May 23 2012. The 10 -404 form for this work is being prepared and should be received by your office shortly. Due to an incompatibility of available choke components, designed injection rates for the trial are not possible. The current injection rate is not adequate to obtain meaningful trial results. To prevent unnecessary loss of production time, the well will be converted back to production service until proper components are available. The reports required by Sundry 311 -386 will be provided for this first abbreviated injection cycle, and you will be notified when the well is prepared for the next injection cycle. Please let me know if you have any concerns at this time. Thank you, Travis Smith Drillsite Petroleum Engineer - 3B, 3F, 3G, 3J, 3S ConocoPhillips Alaska, Inc. Travis .T.Smith(c�conocophillips.com 907.265.6450 litritittet4 jUL 3 2W 1 2 -0 1 -20 6 2-I 531 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 a JUN 2 0 a01Z RE: Cement Bond Log: 3S -18 Run Date: 3/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3S -18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20433 -00 Cement Bond Log 1 Color Log 50- 103 - 20433 -00 ACE Log 1 Color Log 50- 103 - 20433 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: v3 I Signed: Kea • 2 _02. Mao Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] �qiq 61141 Sent: Thursday, May 10, 2012 11:01 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: Smith, Travis T; NSK Well Integrity Proj Subject: MIT form for pre- injection MITIA on 3S -18 Attachments: MIT KRU 3S -18 pre- injection MITIA 5- 8- 12.xls All, Attached is a copy of the MITIA performed following the conversion wellwork on 3S -18 for the Huff and Puff project. Once the well has been brought on injection a witnessed MITIA will be scheduled with the North Slope inspectors. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.readaalaska.gov; doa .aogcc.prudhoe.bav(alaska.aov; phoebe.brooks(aalaska.gov; toal.ffletetweler4a4askaAkpv OPERATOR: ConocoPhllips Alaska Inc. 6 I( l z7 FIELD / UNIT / PAD: Kuparuk / KRU / 3S V--el DATE: 05/08/12 OPERATOR REP: Smith - HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S -18 Type Inj. N ' TVD / 5,767' Tubing 1,000 1,000 1,000 1,000 Interval 0 P.T.D. 2022060 J Type test P Test psi '1500 Casing 1,400 ' 2,500 ' 2,475 2,500 P/F 1- Z9'J ' Notes: 1st attempt pre- injection MITIA / OA 100 100 100 100 Well 3S -18 Type Inj. N TVD 5,767' Tubing 1,000 1,000 1,000 1,000 Interval 0 P.T.D. 2022060 Type test P Test psi 1500 Casing 2,500 2,500 ' 2,525' 2,540 - P/F - IRA' Notes: 2nd attempt pre - injection MITIA ✓ OA 100 100 100 150 Well 3S -18 Type Inj. N TVD 5,767' Tubing 1,000 1,000 1,000 1,000 Interval 0 P.T.D. 2022060 Type test P Test psi 1500 Casing 1,250 ' 2,500 — 2,450 - 2,450 P/F P ' 564 3rd attempt pre - injection MITIA OA 125 150 150 150 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitonng I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water 0 = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT KRU 3S-18 pre - injection MITIA 5 -8 -12 • • ti `6 ZOW Regg, James B (DOA) From: Regg, James B (DOA) Ref, 11/(4 (� Sent: Wednesday, April 04, 2012 11:18 AM To: 'Smith, Travis T' Cc: NSK Well Integrity Proj; Seamount, Dan T (DOA); Schwartz, Guy L (DOA) Subject: RE: 3S -18 CBL; Sundry 311 -386 Bond log looks good. You can commence your trial. Please send paper copies of both CBLs (2/9/2012 and 3/20/2012) for our files. Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 =` A APR `LU1 907 - 793 -1236 From: Smith, Travis T [mailto: Travis .T.SmithCaconocophillips.com] Sent: Tuesday, April 03, 2012 1:53 PM To: Seamount, Dan T (DOA) Cc: Regg, James B (DOA); NSK Well Integrity Proj Subject: RE: 3S -18 CBL; Sundry 311 -386 Hello All: Please find attached the information regarding a follow -up CBL on Kuparuk producer 3S -18 run 3/20/2012. Let me know if you have any questions. Thank you, Travis Smith From: Regg, James B (DOA) [mailto:jim.reggCTalaska.gov] Sent: Monday, March 05, 2012 4:41 PM To: Smith, Travis T Subject: [EXTERNAL]RE: 3S -18 CBL; Sundry 311 -386 We have reviewed the information provided. The bond log needs to be rerun. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Smith, Travis T [mailto: Travis .T.SrnithCa�conocophillios.com] Sent: Friday, March 02, 2012 3:53 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: 3S -18 CBL; Sundry 311 -386 f 1 KRU 3S -18 PTD 2022060 CBL dated 3/20/2012 '^ 2012_03 20_FlEID 35.18„C:l f 1 .pdF - Adobe — 71P A.. File Edrt 1euv Comments Document Co ments Forms Tools Advanced h ndo:v Help Create PDF • v Combine F le= • v , z , Export • Start Meeting • Secure • ! Sign • Forms - Wax & Comment Citk to rotate the page New clockwise m 90 degree f j 1 � I . • ' _ increments 11N I t . + �� ■■ l Allihr • 6550 �.=ei I I PI i {{ » _:. -... -goy ■ _ 'swap 0.- _ , )I A 0 a ` MIN mo� r Tubing tai @ 6577 ft r` ►i t 1111119ral AIENRNiIIUIw i! PillterF4 BE _ eaao ►7�®!� = . C4 MIMI s n�cM. :�_"' _ f ier...n 100 ft cement bonding; ►1ti...aalhF2"� ■ kiisME ! : 70 ft above top perf • ln4�iii■■i� MM'IM �,1, a�ml� { ' 4 EEC 1, • _. i�� e min ...a•.'�.•.... 4 Perfs @ 6642 — 6678 ft —.. - - - } C...a 1 - -. .i % :MI• * ` .. ' t • ' .. ,, .. low , G Ma i'si fi 401 (WI' .. .... ,, > 1 d -_ -- - - y � r , .• 23 AM I ;. ® ..� Is 6/4/2012 r • \gat 35 -1 Pry zw, n Regg, James B (DOA) From: Smith, Travis T [Travis.T.Smith @conocophillips.com] � e ' j � Sent: Tuesday, April 03, 2012 1:53 PM `f To: Seamount, Dan T (DOA) Cc: Regg, James B (DOA); NSK Well Integrity Proj Subject: RE: 3S -18 CBL; Sundry 311 -386 Attachments: 3S -18 3 -20 -2012 CBL submission.pdf; 2012_03_20_FIELD_3S_18_CBL.pdf Hello All: Please find attached the information regarding a follow -up CBL on Kuparuk producer 3S -18 run 3/20/2012. Let me know if you have any questions. Thank you, Travis Smith From: Regg, James B (DOA) [mailto:jim.reog(aalaska.gov] Sent: Monday, March 05, 2012 4:41 PM To: Smith, Travis T Subject: [EXTERNAL]RE: 3S -18 CBL; Sundry 311 -386 We have reviewed the information provided. The bond log needs to be rerun. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Smith, Travis T [mailto: Travis .T.Smith(ahconocophillips.com] Sent: Friday, March 02, 2012 3:53 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: 3S -18 CBL; Sundry 311 -386 Hello Jim - This is a follow -up to the State's request for a CBL before a huff and puff trial in Kuparuk well 3S -18 (sundry number 311- 386, AA AIO2B.069). Please let me know if this delivery is adequate, or if you would like an additional hard -copy delivery. Thank you very much, Travis Smith Drillsite Petroleum Engineer - 3B, 3F, 3G, 3J, 3S ConocoPhillips Alaska, Inc. Travis .T.SmithCa�conocophillips.com 907.265.6450 1 • • Daniel T. Seamount, Jr. 333 W. 7 th Ave., Ste. 100 Anchorage, AK 99501 -3539 Re: Kuparuk River Field, Kuparuk River Oil Pool, 35 -18 Sundry Number: 311 -386 Z Dear Mr. Seamount: In the approved 10 -403 form for the Huff & Puff injection trial at well 3S -18, the State has requested that CPAI submit CBL data to confirm zonal isolation prior to initiation of injection service. Per the request of Jim Regg dated March 5, 2012, a follow -up CBL was completed on March 20, 2012 by Halliburton Energy Services to eliminate inconsistencies seen in the first attempt. To improve data collection during the CBL, well 3S -18 was displaced to liquid prior to logging to improve validity of tool calibration, and additional centralizers were used to increase measurement accuracy. A main logging pass as well as three repeat passes were run. These four passes show consistent measurement. Unlike the first CBL attempt, this log measures very low amplitude readings and distinct wavetrain attenuation in the MSG display from 6670' up to the tubing tail at 6577'. These measurements indicate cement bond of the production casing in this interval. Sincerely, ` ravis Smith Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. Page 1 of 1 • 1 C( 35 - f� Regg, James B (DOA) Pr)ze Z>60 From: Regg, James B (DOA) Sent: Monday, March 05, 2012 4:41 PM ,-, � -3f To: 'Smith, Travis T'l / Subject: RE: 3S -18 CBL; Sundry 311 -386 We have reviewed the information provided. The bond log needs to be rerun. Jim Regg 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Smith, Travis T [mailto: Travis .T.SmithCa�conocophillips.com] Sent: Friday, March 02, 2012 3:53 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: 3S -18 CBL; Sundry 311 -386 Hello Jim- This is a follow -up to the State's request for a CBL before a huff and puff trial in Kuparuk well 3S -18 (sundry number 311- 386, AA AIO2B.069). Please let me know if this delivery is adequate, or if you would like an additional hard -copy delivery. Thank you very much, Travis Smith Drillsite Petroleum Engineer - 3B, 3F, 3G, 3J, 3S ConocoPhillips Alaska, Inc. Travis .T.Smith @conocophillips.com 907.265.6450 1 • • ! Regg, James B (DOA) 20-z_zow From: Smith, Travis T [ Travis .T.Smith @conocophillips.com] Sent: Friday, March 02, 2012 3:53 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: 3S -18 CBL; Sundry 311 -386 Attachments: 2012- 02- 09_FIELD_3S- 18_CBL.pdf; 3S -18 CBL for Huff and Puff.pdf Hello Jim - This is a follow -up to the State's request for a CBL before a huff and puff trial in Kuparuk well 3S -18 (sundry number 311- 386, AA AIO2B.069). Please let me know if this delivery is adequate, or if you would Tike an additional hard -copy delivery. Thank you very much, Travis Smith Drillsite Petroleum Engineer - 3B, 3F, 3G, 3J, 3S ConocoPhillips Alaska, Inc. Travis .T.Smith(cconocophillips.com 907.265.6450 1 • • Daniel T. Seamount, Jr. 333 W. 7` Ave., Ste. 100 Anchorage, AK 99501 -3539 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3S -18 Sundry Number: 311 -386, AA AIO2B.069 Dear Mr. Seamount: In the approved 10 -403 form for the Huff & Puff injection trial at well 3S -18, the State has requested that CPAI submit cement bond log (CBL) data to confirm zonal isolation prior to initiation of injection service. On February 9, 2012, Halliburton Energy Services performed a CBL logging operation at 3S -18; the resulting data is attached here. The CBL analysis indicates cement bond in the vicinity of the perforations, however is not completely conclusive with regards to effectiveness of the hydraulic isolation of the Kuparuk formation due to the lack of consistency in the repeat pass. The following observations support this assertion: 1. Amplitude measurements in the vicinity of the C -sand perforations are higher than ideal, averaging approximately 25 mV from the tubing tail at 6577' RKB to the end of the logging run. However: 2. Amplitude measurements vary significantly (as much as 100 %) between the main pass and repeat pass logging runs. The repeat pass run amplitude averages consistently over 45 mV from 6665' RKB and below, while the main pass consistently reads Tess than 30 mV (Callout #1 on attachment). 3. A qualitative interpretation of the wavetrain display shows inconclusive resulis_There appears to be some attenuation from 6665' RKB and down (particularly from 6665' RKB to 6674' RKB) versus the free pipe response in the tubing; however, the region from the tubing tail to 6665' RKB shows a muted response that appears inconclusive. 4. The sector mapping visualization shows varying indications of cement contact in the main pass, but is not consistent at all with the repeat pass data. Page 1 of 4 • • a i Given these observations ConocoPhillips Alaska, Inc (CPAI) believes there are enough positive indications to show hydraulic isolation is exhibited to allow Huff and Puff operations. However if additional information is required CPAI is willing to run a temperature or other qualitative memory logging tool before or during the MI injection cycle to demonstrate external mechanical integrity and hydraulic isolation of the Kuparuk formation during injection service in well 3S -18. Please let us know if the CBL information data is sufficient or if additional logging or other diagnostics in addition to the State Witnessed MITIA are required prior or during the MI slug. Sincerely, Travis Smith Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. Page 2 of 4 . • HAWBURTON MAIN PASS D at F c 5wrarnsAdata'3c- 18 „cbl tJS49bx:012t3t -19_cd 09144zX1.1 c4.• Damsel Pathrorne pess1B Presehtahon Format rctt t7aras tit C a. Ie n Thu Feb 09 16 49 02 2012 by Loo Hathateton Cesedho Charted br. Depth In Feet scated 1240 280 TT (used 180 0 Ampl tude (mVA50 AVG Sector Amprttude 200 MSG 1200 SECTORS CCL Amptdude x10 0 150 0 Gamma 150 10 ( my) 15 MAX Sector Arrtplkude 301XLrne Tens (Ib) 0 • 0 150 MIWJ Sector Anvaltete 0 150 -' i t 1 r , (1, '#i ,11. . .. k - i iira....mair... I F 4 ... , , )., 1 r 1' ACk „r • 5.`A } 1111161.111 e l I t il I 1,, k, , . A • . 0 . P 4 Syr i • 7 OA a 4 • A I Page3of4 • • HALLIBURTON REPEAT PASS Database File c %wan , tma'.38-18_chl_09feb20120s-18_pb1_09feb20 cla Lit81119e1P811109ine 081s1 ID Presentation Format tchl Dataset Creation Thu Feb 09 16 32 47 2012 by Log Ha Pluton Casecito Cl LOY Moil hi Fl vs,a t-411 240 ... I: IT (usec) 180 :0 Ariql rude lmV)150IAVG Sector Amplitude 200 MSG 1200 8EL CO_ Ampieude s10 O 150 0 ■-• I rott 150 0 (mV) 15 Sector Amplitude ' h ir+i rt. 1 01 r-, (IN U 11) ___ _ Inconclusive _ 1W _ Mit Sector Amplitude wavetrain data 0 150 ... - - .. , . I t, 1 ' it (I ' 1 1 I Ma • f 11P•I' - : ....... : , 1 I , 1 , , I Attenuation in this ,.. ■ 700 . area • • .., ...4 I i I , Il: 1 I I Inconsistent . amplitude I measurement , ... between runs .: 1 1 [ i Inconsistent sector data Page 4 of 4 'D V32,1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 14, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 3S -18 Run Date: 2/9/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3S -18 Data in LAS format, Digital Log Image files 1 CD Rom 50- 103 - 20433 -00 Cement Bond Log 1 Color Log 50 -103- 20433 -00 WOWED MAY 1 6 2 012 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com (1) I / Date: )\ Signed: • • 2.o2,-2.06 2.1c76 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 12, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 3S -18 Run Date: 1/6/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3S -18 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20433 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: � 12. Signed: • • ELAs[K(A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Travis Smith Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. rl 0 P.O. Box 100360 C � Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3S -18 Sundry Number: 311 -386 &LAMED JAN at la Dear Mr. Smith: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,. Daniel T. Seamount, Jr. Chair DATED this 6 ,� day of January, 2012. Encl. ' STATE OF ALASKA 1" �' '°" " ALASSIL AND GAS CONSERVATION COMMISS - 31: - Ti /ii' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ikinska Oil & G8z Cons. Commission 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change P priml ram r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate Alter casing 9 r Other: Convert Prod to H &P Inj r. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p - Exploratory r 202 -206 ' 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 -103- 20433 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 3S - . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 380107 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6900 ' 6119 ' 6798' 6017' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' SURFACE 2811 9.625 2841' 2547' PRODUCTION 6860 7 6887' 6106' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6642' -6678' 5863' - 5989 3.5 L -80 6577 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SAB - PACKER MD= 6545 TVD= 5767 SSSV - NIPPLE CAMCO'DS' NIPPLE MD= 498 TVD =498 12. Attachments: Description Surrnary of Proposal p- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2012 011 r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r - WAG T Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Smith @ 265 -6450 Printed Name avis Smith Title: Drilisite Petroleum Engineer Signature ; //� `' Phone: 265 -6450 Date /7 /�j/ / Commission Use Only Sundry Numberi !! // cJ 11 r 5 (o Conditions of approval: Notify Commission so that a represehtative may witness Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Ope.teileuft i ti • ta--1 AJ B. d t 1 S ,, cot. , 6e 4 re__ =n�. E2N LAC- - Subsequent Form Required: /p - zip y APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: I/ 4 7/ Form 10 -403 Revi'; i :1 &IAN 0 6 2012 ,. . Submit in Duplicate ; !�6' ,1 i,t; • ....." ... ,,,,,,, g /...(z__, • • ** *DRAFT 3S -18 Huff and Puff Injection DRAFT * ** DATE: December 15, 2011 SCOPE: The purpose of this test is to establish the incremental oil rate that can be gained from temporarily injecting MI gas into producer wells on a "Huff and Puff' basis. / OBJECTIVES: • No injuries or spills • Inject designed slug volume of MI gas into producer well 3S -18 ✓ • Obtain good quality surveillance data of production response after injection PROCEDURE: 1. Wellwork to satisfy internal / State requirements for safe injection (procedures for this work already on WWPL and in "In Progress" folder, see attached) a. Run in hole with PANEX gauges on CA -2 plug for C -sand SBHP b. Pull OV; perform CMIT c. Set DV; perform MITT d. Pull PANEX gauges e. Run CBL over C -sand perforations 2. Submit CMIT /MITT & CBL for State review before initiating any injection 3. Begin fabrication of spool to connect gas lift (MI) flowline to tubing header (see attached drawing) 4. Pull GLVs, run DVs, PT tubing 5. File 10 -404 form for H &P service swap from production to injection 6. Put well on MI injection service at maximum rate for XX days a. Expected injection rate 8 — 10 MMSCFD b. Perform State - required MITIA while on gas injection Aio � "�1 ``� l • hiffne5.51 7. Shut -in well for XX days for MI "soak time" 8. File 10 -404 form for H &P service swap from injection to production 9. Put well on production S cicdl. j�ject,0y oely t Ott i ii /14 *14e t nI Avid yield VG /v4 12/15/2011 (e5Qf t5, I/1 "roe • 800 /Z100 0000 - adYI 0000 ens e � I NOSN OH Dxx.. au 9x ON NOTES 1. BREAK -OUT FLANGES FOR REMOVAL OF LATERAL SPOOL PIECE - - — - - — - - — -' —' - - - —' _ — - - - - —I BETWEEN WELLHEAD AND VALVE SHELTER. r _ _ _ _ _ - ■ - - — - - — - - — - .. 2 ALL INSTRUMENTS ARE TAGGED WITH AN ADDITIONAL PREFIX TO FOR EACH STANDARD W/ ELECTRIC HEATER WHERE BER INSTRUMENTS BE NUMBERING PROCEDURE EXCEPT T TH U T IN THE WELL NUMBER INDICATE DRILL SITE FOR EXAMPLE. ROV-9201 IS ROV-3S9201 WELLHOUSE SHELTER V A L VE SHELTER W/ ELECTRIC HEATER _ 1 1 1 SET ®9750A HS-9201-SL PROD /TEST SELECTION I WILL BE INCLUDED AS A SUFFIX. FOR EXAMPLE ROV- 359201 -10. 1 1 1 I XA -92021 TORQUE STATUS 1 3000 PSIG I 3. CONNECTION FOR FUTURE CHEMICAL INJECTION I I I NOTE 7 SET ® 500 PSIC XA -92018 TRAVEL FAIL 4 DRAIN LOCATED ON SIDE OF PIPE PSLL -9350A HS -92018 CONTROL 5. SSV HYDRAULIC SUPPLY HAS FUSIBLE PLUG. 1 SET 0 XA- 9201130 TORQUE STATUS 1 6 SINGLE CHOKE DESIGNED FOR HANDLING THREE DIFFERENT LIFT 1 L\ 85 PSIG FLUIDS LIFT FLUID CAN BE MISCIBLE INJECTANT, LIFT GAS, 1 PSLL -93508 I OR WATER. SEL ® 7. CHOKE VALVE ACTUATOR REQUIREMENTS ARE PROJECT SPECIFIC ESD 85 PSIG I REFER TO DETAILED PROJECT SCOPE OF WORK. HDCP -9350^ ' •'� 1 1 NOTE 11 o — —o 8 FIT -1440 IS TEMPERATURE COMPENSATED BY Tli -7245 AND LE J I I r o MN 1 PRESSURE COMPENSATED BY PIT -5416 1 9350 NOTE 10 SIS I NOTE 5 IQ9 PSHH -5323 OR PSLL -5323 OR PSLL -5416 CLOSES ROV -9207 (MUST BE 9 � " • —o a— o —o —a— I o o —o— o— o— a— a —o —o— 0 0 -0 —o o RSV —o —o— IN REMOTE) AND IS NON CRITICAL 291: BPCS �\ s3s� ° 10 REMOTE EMERGENCY SHUTDOWN INTERLOCK WILL SHUT 1 I "..,./ PY SIS o I o I I o PAH -9350A PAL -9350A I o I SSV ALSO ON CLOSES ACTUADITION. �� 1 IVERT VALVES IN REMOTE (ROV) AND IN AUTO (SETCIM). 1 I 2 Q 1. © el I 1 NALGENE 4 " PC- 3527 -F4.4 (TEST) Li BOTTL I I m 1 • PI T 1.1 M 1 4 "VBCLE 3 FL 1 I SIS 59: 1 1 III TAL 1 303 o 11- VV NAN A o XA -9201A TRAVEL FAIL 1 I /z VNANA I I zS BPCS � HS -9201A CONTROL I SL 3 " LWN o o XA -9201 AT TORQUE STATUS RO I p ® 1 1 1 P . 1 1 0 smz 1 ILIIII 3 � •3 9 nw —oJ 1 BPCS I —o 2 1 1 NOTE 3 I I SAN %"VNANA 5 SIS © 01 NOTE ] BPCS o —o I IC Fc _ 1 1 " ; a"PC- 3szs -Fa.a 2 1 52 7 4. a l0 ∎4" 1 nXw zy, = I NO E 1 REMOVE LINE AND KEEP 4 "PC- 3526 -F4.4 4 "10CWW 1.1 4 "PC- 3526 -F4.4 (PROD m 1� i r \ 1 m 1 F OR RE- INSTALLATION 4 LE i V GGWB I I I s35o 313 ® 996 NOTE 4 1 1 "VGCWB . NOTE 4 M I PSLL -5416 0 NOTE 9 0 -0 0- 0- 0- 0 -0 -0 —o a 1 1 1 —o —o 0 0 -0 MPO -o20031 PSHH SE7 4;500 2 l TORQUE SHT 350 - 001 1 . PAH Q STATUS I PAL SET ®500 PSI Dv _ PI o P SLL G (I� 01 A Q i 1 1 Y 1 FAH 1 • 1 P1 T BPCS BPCS I r BPCS o �2 1 I 5Dfi VA., Pl 201 ,MO NOTE 8 ��'� FAL RV 63 23 3 FOR WATER, M AGM M4 "VNANA I "10008 %'VNANA AND GAS LIFT 1 ! [X] � I V %'VNANA 1 2 "GI- 3525 -G 111 2 "GI- 3525 -5007 NOTE 6 O 2 "01- 3525 -GKG7 I , ON w I a 88883 / "VGCWB 1 "VGCWB 1,,,,,,B s z NOTE 4 m I m NOTE 4 ® NOTE 4 m 1 1 1 I 1 �"VNA NA 4 ^ _ 1 I WELL 10 WELL 10 WELL HOUSE SHELTER VALVE SHELTER PRODUCTION PRODUCTION DETAIL 1 MPD -0350 -2003 SHT 002 msmE.we Dxc 3D/w, NO E. NO. 2313148AMP N..' AREA: 35 MODULE: 0486 UNIT D3 CC NO ConocoPhillips DS3S WELL m Alaska, Inc PON ID 2 03/05 REVISED PER K04114AEI (3066030) BR6 JL cam, 2 NO waux I DES,w D PRODUCTION DETAILS x E 1 6/23/04 DRAWN PER 2313148AMP WC C. E xco saw ma:. COYAN .wsDO.D. xo +oe . mxc xo r RE. DALE 2E051095 Dr a €a 50 NONE I w NSDK 5U8 0000 oAA MPD -03SX -2012 P � x 004 c, 2 • 400 /Z10Z XSLO - OdO 0000 NOSN •BN5MMINB , ON GOf finS ON WI' NOTES 1 BREAK -OUT FLANGES FOR REMOVAL OF LATERAL SPOOL PIECE ------------- " - " - -- " -" - '-I BETWEEN WELLHEAD AND VALVE SHELTER. _ _ - - - - - - - •-• - - - - - 2. ALL INSTRUMENTS ARE TAGGED WITH AN ADDITIONAL PREFIX TO - 1 INDICATE DRILL SITE. FOR EXAMPLE ROV -9201 IS ROV- 359201 VALVE SHELTER ELECTRIC HEATER 1 WHERE INSTRUMENTS ARE REPEATED FOR EACH WELL, THE SAME I WELLHOUSE SHELTER W/ NUMBER WILL BE USED FOR EACH INSTRUMENT USING STANDARD r W/ ELECTRIC HEATER A INSTRUMENT NUMBERING PROCEDURE EXCEPT THAT THE WELL NUMBER 1 1 1 SET 0 HS- 9201 - PSHH-93500 HS- 9201 -S AUTO/MANUAL PROD./ TEST S ELECTION I WILL BE INCLUDED AS A SUFFIX. FOR EXAMPLE. ROM- 359201 -10. SELECTION 1 1 1 I 00-9202T TORQUE STATUS 1 PSHH -9350B 31508 1 3 CONNECTION FOR FUTURE CHEMICAL INJECTION. I 1 I NOTE 7 SET ® 4 DRAIN LOCATED ON SIDE OF PIPE 500 P51G XA -92010 TRAVEL FAIL PSLL -9350A HS-92010 CONTROL 5. SSV HYDRAULIC SUPPLY HAS FUSIBLE PLUG. SET 0 AA-9201BT TORQUE STATUS 1 6. SINGLE CHOKE DESIGNED FOR HANDLING THREE DIFFERENT LIFT 85 PSIC FLUIDS. LIFT FLUID CAN BE MISCIBLE INJECTANT, LIFT GAS, 1 PAL -9350B I OR WATER 2 I ■SET 0 7 CHOKE VALVE ACTUATOR REQUIREMENTS ARE PROJECT SPECIFIC. � �ESD 65 PSIC I�,' I REFER TO DETAILED PROJECT SCOPE OF WORK. 1 IOC- 9350 _ _ S I mo' / { I NOTE 11 \ ro —o —o I 8 FIT-1440 IS TEMPERATURE COMPENSATED BY TIT -7245 AND 1 NOTE 10 SI6 I I I PRESSURE COMPENSATED BY PIT -5416 I NOTE 5 I i 9 PSHH 3 OR SL-533 OR LL - CLOSES ROV -9207 (MUST BE 1 IN REMOTE) -532 AND PL IS NON - 2 SAFETY PS CRITICAL. 5410 I r _� m —o—o — o— o— o —o —o -0 0 -0 -0 -0 ° o -o R3so s3sa ° 0 0 ° 0 0 o pqH -93500 z ®t` BP o I 10 REMOTE EMERGENCY SHUTDOWN INTERLOCK WILL SHUT 1 SIS ° I o I PAL -9350A 1 SSV ON ACTUATION I 0 � 1 ' ALSO CLOSES DIVERT VALVES IN REMOTE (ROV) AND IN AUTO (SETCIW). r 1 1 1 r 1 0 © ° I 1 1 NALGENE 1 � 1 El 4"PC- 3527 -F4.4 (TEST) 1 LJ BOTTLE 1 m 013 4 "VHCLE M I III 1 1 s. 1 1 I �TAL 1 \ I I 7z0 ° �1 : %"N 0NA_ 0 XA -92010 TRAV FAIL 1 1 1 BPCS HS -0201A CONTROL 1 1 0 XA- 9201AT TORQUE STATUS D" 1 1 PI z 5301 I I 3 se 3se z z o o ° 1 L D 4� I 1 3" BPCS �o , 201 - °J I I NOTE 3 I I SKIN SIS 9 M NOTE 7 BPCS I 1 I 11 FC a 4 I I"; 4 "P - 3026 -F4.4 Rip 4 PC- 3526 -F4 4! q^ © 1 D" SKIN = I NOTE 1 I= t 4 "PC- 3526 -F4.4 CICCWW NI 4 "PC- 3526 -F4.4 (PROD) nr -1 1 n3so rl \ 7 "VGCWd m n jn co N 4 ,, NOTE I'VGCWB 18 01E 0 1 0 4 B I 7113 ® szas NOTE 4 NOT 4 m= l 1 -o -o — 0- 0- 0 —e -0 —o - 2350 -416 1 1 I NOT 9 © ¢ 1 PSHH 501 0 2500 PSIC es TORQUE —O � ° —O < 970 -2050 -20031 �` SHT 001 1 I Ij PAH m Q ° STATUS PI I PAL 5300 4 1 I �pSLL SET 0 500 PSIC 0 2Q 1 711 BPCS BPCS rz , 7 40 Fl BPCS ,. FAH 1 s s Ivl_I 1 P1 szm7 t 80 \° i FAL 1 I^f'1 s323 33 23 FOR WATER, MI AGCO M4 "VNANA � VOCWB %NANA 000 GAS LIFT i %y" 2^ / 1 2 "G1- 3525 -GKG7 NOTE 6 25 -GKG7 1 - a - i1�4 l 1 >41. 1-11 1 '.,--9,, 2 "CI- 35 1 _ 2" c 200 1 I 1 I e -E I\ x La m 1 "00CWB 1"000/43 \ I 1 �°- Q NOTE 4 ® NOTE 4 m I " VNANA 1 I • • 1 L .____ —__ __ __—____— _____ ____ __— __ —__ —__ __ —__ —__ — __— __— ______.1 WELL 10 WELL 10 WELL HOUSE SHELTER VALVE SHELTER PRODUCTION PRODUCTION . DETAIL 1 MPD -D35Y -2003 SHT. 002 FORM DqIZEPID RECEPOICE LINO 90/5/47 004 Na 2313146AMP liv" AREA: 35 MODULE: XXXX UNIT. D3 LC NO ConocoPhillips DS3S WELL m 1/1170 FILE NO Alaska, Inc. PRODUCTION DETAILS P& ID 03/05 REVISED PER 0041148E1 (3066030) 000 JL ""' COYAN l''' rn c uBO tt 1 6/23/04 DRAWN PER 2313148AMP WC G.K. K002. K002. mou uvNO 00 JOB N �� o WING No r REV E 00 NY 7st0NS w0 E1PA, 4246 540 NONE IN °6/23/04 .tee NSDK 0000 MPD -D350 -2012 P °17 004, NE ° WE 2 T : P 0 3S -18 " `' eV Attribu ConocoP * � I Wellbore API/DWI Field Name Well Status Maximum Inclination ( °) Total Depth (ftKB) Alaska, Inc. 501032043300 KUPARUK RIVER UNIT PROD 35.67 6,900.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' NIPPLE ... 60 1/1/2008 33.27 12/3/2002 Well Confiq: - 3S -18. 811200810: 44: 18 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation End Date Last Tag: 6,781.0 7/20/2008 Rev Reason: TAG SLM RATHOLE 8/1/2008 Casing Strings -- Set Depth Set Depth (TVD) Wt Casing Description OD (In) ID (In) Top (ftKB) (ftKB) (ftKB) (Ibs /(t) Grade Top Thread CONDUCTOR 16 15.062 0.0 108.0 108.0 62.50 H-40 WELD t f SURFACE 95/8 8.697 0.0 2,840.0 2,546.9 40.00 L-80 BTCM HANGER,25 PRODUCTION 7 6.151 0.0 6,887.0 6,105.6 26.00 L -80 BTCM 1 Tubing Strings Set Depth CONDUCTOR, Tubing Description OD (in) ID (In) Top (ftKB) (668) Set Depth (TVD) (ftKB) Wt (Ibs /ft) Grade Top Thread toe - TUBING 3 1/2 2.992 0.0 6,577.0 5,798.5 9.30 L-80 EUE8rd Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) _ Top (ftKB) Description Comment Run Date ID (in) SSSV, 498 11 25.0 HANGER FMC 3.5" GEN 5 TBG HANGER 12/2/2002 3.500 498.0 SSSV NIPPLE CAMCO 'DS' LANDING NIPPLE W/NO GO PROFILE 12/2/2002 2.875 2,882.0 GAS LIFT CAMCO(KBUG /1 /GLVBK- 5/.188/1865/ Comment: STATION #1 7/3/2005 2.920 SURFACE, 4,311.0 GAS LIFT CAMCO/KBUG /1 /DMY /BK -5/// Comment: STATION #2 12/2/2002 2.920 2,840 5,330.0 GAS LIFT CAMCO/KBUG/1/GLV/BK-5/.25/2097/ Comment: STATION #3 7/3/2005 2.920 6,002.0 GAS LIFT CAMCO/KBUG /1 /DMY /BK -5/// Comment: STATION #4 12/2/2002 2.920 6,429.0 GAS LIFT CAMCO/MMG /1.5 /OV /RK/.25// Comment: STATION 50 7/3/2005 2.920 GAS LIFT, - 6,481.0 SLEEVE -C BAKER SLIDING CMU SLEEVE W/2.812" DS PROFILE - dosed 12/2/2002 2.812 2,882 - _ -- 6,530.0 PBR BAKER 8040 PBR 12/2/2002 2.990 6,544.0 ANCHOR ANCHOR NIPPLE 12/2/2002 2.993 NIPPLE TUBING,0 6,545.0 577.0 TT PACKER L BAKER SAB -3 PACKER W/4.5" MILLOUT EXTENSION @6549 W/3.75" ID 12/2/2002 3.250 2.992 6,569.0 NIPPLE CAMCO D' NIPPLE 12/2/2002 2.750 GAS LIFT, 6, 6,576.0 WLEG BAKER PUMP OUT SUB 12/2/2002 1212/2002 2.990 4,311 Perforations Shot (ft Top (TVD) Btm (TVD) Dens CAS Lrr. 5.33n 4 Top (ftKB) Btm 65) (ft (ftK KB) B) Type Zone (shot... Data Comment 6,642.0 6,678.0 5,862.8 5,898.5 IPERF C-4, 3S-18 6.0 12/8/2002 2.5" 2506 PJ, 60 deg ph Notes: General & Safety End Date Annotation 12/2/2002 NOTE: TREE CAP CONNECTION: TOP 5 3/4"" ACME W/3.5"" EUE 8RD THREAD GAS 6,002 LIFT, 12/2/2002 NOTE: TREE: FMC / GEN 5 / 5M GAS LIFT 5 , 25 SLEEVE -C, 6481 PBR. 6530 ANCHOR f' 00 NIPPLE. 6.544 I 0 0 0 { PACKER, 6,545 1 NIPPLE, 6.569 1 1 1 WLEG, 6,576 J TTL. 6577---- IPERF, 6,6426,678 PRODUCTION, 6,887 N 10,6,900 • ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.069 Mr. Travis Smith Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc.G c*--` P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 3S-18 (PTD 2022060) Administrative Approval Kuparuk River Oil Pool Dear Mr. Smith: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby GRANTS an administrative approval to alternately operate KRU 3S -18 as a service [injection] well and a development [production] well. ConocoPhillips Alaska, Inc. (CPAI) submitted an Application for Sundry Approval (Form 403) on December 15, 2011 requesting to alternately operate the subject well cyclically in service and development modes. The goal of the project is to determine if additional reserves can be recovered by injecting miscible injectant (MI), allowing a contact period with the well shut in, followed by a production period. Multiple cycles of this process are possible. After evaluation of the request, it was determined to treat the Sundry as an application for Administrative Approval under Rule 9 of AIO 02B.000 due to the multiple injection - production cycles that are likely. Administrative and operational efficiencies will be realized with an Administrative Approval for these activities. CPAI intends to demonstrate that the well has mechanical integrity as required by 20 AAC 25.412 and Rule 6 of AIO 02B.000 prior to beginning the first injection cycle. This approval will not endanger correlative rights, is based on sound engineering and will not result in any risk to fresh water. AOGCC's administrative approval to conduct cyclic service and development operation of KRU 3S -18 is governed by the following: 1. CPAI is authorized to conduct preliminary work including wellbore pressure testing and cement bond logging as outlined in the provided procedure and submit the results of this work to the Commission; 1 r AIO 2B.069 January 5, 2012 Page 2 of 3 2. If the submitted integrity information is determined satisfactory, Application for Sundry Approval #311 -386 will authorize CPAI to convert KRU 3S -18 from development to service and begin the first injection cycle; 3. CPAI shall submit Form 404, "Report of Sundry Operations" documenting the conversion; 4. CPAI shall notify the Commission Inspector and perform an MIT -IA to the maximum anticipated injection pressure when well conditions have stabilized; 5. Throughout the project, CPAI shall submit to the AOGCC a monthly report of well pressures regardless of well status and injection rates while injecting; 6. When it is determined to convert the well from service to development, CPAI shall provide electronic notification to the Commission and file Form 404 documenting the conversion; 7. When it is determined to begin the next injection cycle, CPAI shall provide electronic notification to the Commission and comply with Rules 3 — 6 for the duration of the project, however at the discretion of the Commission a new MIT -IA may not be necessary if pressure integrity continues to be demonstrated based on the monthly information required by Rule 5; 8. Within 60 days of the conclusion of each production cycle, CPAI shall provide an interim report of the well performance. 9. Within 60 days of the conclusion of the multiple cycle project, CPAI shall provide a final report for the project. DONE at Anchorage, Alaska and dated January 5, 2012. Daniel T. Seamount, Jr. John K. Norman Cathy P. Foerster Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, • • AIO 2B.069 January 5, 2012 Page 3 of 3 this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "(t)he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 4 4110 • Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Thursday, December 15, 2011 2:41 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; Smith, Travis T; Schwartz, Guy L (DOA); NSK Well Integrity Proj; Dethlefs, Jerry C Subject: RE: 3S -18 (PTD 202 -206) Huff and Puff Proposal Attachments: DS3S Huff and Puff .pdf Tom, Let us know, after you have a chance to mull it over, if we need to pursue an ERIO as well. Currently the 10-403 is in progress and well start on the AA as soon as we receive the approved 10 -403. Below are answers to your questions (provided by Travis Smith, the Engineer on the Project): But this prompts a question, is this going to be a process employed at/in other wells at Kuparuk and maybe other fields /pools? Possibly yes, in a good success case of this trial. At this point, we don't have any other wells named or identified for trials, but if we were convinced it is promising we might move in that direction. 1. How long do you expect the respective cycles of injection, soak and production to be? Not quite done with this analysis yet, but I would foresee something on the order of — a few weeks of injection, — a few days of soak, and a couple - few months of production before repeat. I'm sorry I don't have this quite calculated yet: the above is what I see the orders -of- magnitude being for these periods. 2. Are there a discrete number of complete cycles planned or will this be how the well is operated for the foreseeable future? There will be a discrete number of cycles, likely 2 -3, before returning to normal status quo production. 3. Do you expect the well to flow unassisted? I would expect this well to flow unassisted. In fact, we likely will allow it during the production period immediately following MI injection (to avoid changing GLVs in high MI environment) 4. Once pressure integrity (MIT) is verified, so long as the physical GL dummies are not disturbed I think a TIO plot might be able to be used to demonstrate continued integrity without needing to perform a "real" MIT. We will have to think further on this. 5. Pilot settings will also need to be determined for production versus injection. It is probably advisable to tag the wells indicating whether producer or injector. 6. A line drawing of how this all is laid out would be appreciated. The attached PDF is the DS Fac. Engr's plan for the connection from the (MI) gas lift connection to the tubing head. I'll be happy to find the answer to any additional questions. MJ Loveland / Martin Walters Well Integrity Project Supervisor 12/20/2011 Page 2 of 4 ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 15, 2011 9:48 AM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Smith, Travis T; Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: 3S -18 (PTD 202 -206) Huff and Puff Proposal MJ, et al, Guy and I have spoken and for multiple cycles, at this point we believe that the AA is the way to go. But this prompts a question, is this going to be a process employed at/in other wells at Kuparuk and maybe other fields /pools? That might point us to an ERIO since this could be considered a pilot project. By regulation a sundry needs to be submitted for conversions from producer to injector and having the AA in place should eliminate that need. 404s will be needed for each switch and a verification of integrity will also be needed when switched from producer to injector. Some questions ... 1. How long do you expect the respective cycles of injection, soak and production to be? 2. Are there a discrete number of complete cycles planned or will this be how the well is operated for the foreseeable future? 3. Do you expect the well to flow unassisted? 4. Once pressure integrity (MIT) is verified, so long as the physical GL dummies are not disturbed I think a TIO plot might be able to be used to demonstrate continued integrity without needing to perform a "real" MIT. We will have to think further on this. 5. Pilot settings will also need to be determined for production versus injection. It is probably advisable to tag the wells indicating whether producer or injector. 6. A line drawing of how this all is laid out would be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Thursday, December 15, 2011 7:47 AM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; Smith, Travis T; Schwartz, Guy L (DOA) Subject: RE: 3S -18 (PTD 202 -206) Huff and Puff Proposal Tom, Travis Smith is working on the Sundry this week. Let us know if we need an AA in addition to the Sundry. Regards MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] I I 12/20/2011 . Page 3 of 4 Sent: Tuesday, November 29, 2011 12:20 PM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Smith, Travis T; Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: 3S -18 (PTD 202 -206) Huff and Puff Proposal Marvin, Got your call. I think you /MJ have the appropriate process laid out. Has the sundry been filed? Where are "things" in the work process ?? I will have to talk with Guy /Jim on future paperwork; 404s for sure when the well is switched from producer to injector. I am not sure about multiple 403s. Maybe it would be appropriate to write an AA for the well and Huff and Puff process. I look forward to your reply. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Tuesday, November 15, 2011 5:49 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; Smith, Travis T Subject: 3S -18 (PTD 202 -206) Huff and Puff Proposal Tom, 3S -18 (PTD 202 -206) is being evaluated for a "Huff and Puff' MI cycle(s) in a producing well. A rough outline of our proposed steps are listed below. SCOPE: The purpose of this test is to establish the incremental oil rate that can be gained from temporarily injecting MI gas into producer wells on a "Huff and Puff' basis. OBJECTIVES: • No injuries or spills • Inject designed slug volume of MI gas into producer well 3S -18 • Obtain good quality surveillance data of production response after injection PROCEDURE: 1. Wellwork to satisfy internal / State requirements for safe injection a. Run in hole with PANEX gauges on CA -2 plug for C -sand SBHP Pull OV; perform CMIT Set DV; perform MITT Pull PANEX gauges Run CBL over C -sand perforations File 10-403 form with State for Huff & Puff injection Begin fabrication of spool to connect gas lift (MI) flowline to tubing header Pull GLVs, run DVs, PT tubing File 10 -404 form for H &P service swap from production to injection Put well on MI injection service at maximum rate for XX days a. Expected injection rate 8 —10 MMSCFD Perform State - required MITIA while on gas injection Shut -in well for XX days for MI "soak time" 12/20/2011 • • Page 4 of 4 File 10-404 form for H &P service swap from injection to production Put well on production Do we need any additional information other than a CBL, 10-403 approval, and subsequent MITIA to execute the proposal? Also would we need a 10-403 for each MI cycle or just a 10-404 after the original approval. Please advise. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 12/20/2011 • • TT [LAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.069 Mr. Travis Smith Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 3S -18 (PTD 2022060) Administrative Approval Kuparuk River Oil Pool Dear Mr. Smith: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby GRANTS an administrative approval to alternately operate KRU 3S -18 as a service [injection] well and a development [production] well. ConocoPhillips Alaska, Inc. (CPAI) submitted an Application for Sundry Approval (Form 403) on December 15, 2011 requesting to alternately operate the subject well cyclically in service and development modes. The goal of the project is to determine if additional reserves can be recovered by injecting miscible injectant (MI), allowing a contact period with the well shut in, followed by a production period. Multiple cycles of this process are possible. After evaluation of the request, it was determined to treat the Sundry as an application for Administrative Approval under Rule 9 of AIO 02B.000 due to the multiple injection - production cycles that are likely. Administrative and operational efficiencies will be realized with an Administrative Approval for these activities. CPAI intends to demonstrate that the well has mechanical integrity as required by 20 AAC 25.412 and Rule 6 of AIO 02B.000 prior to beginning the first injection cycle. This approval will not endanger correlative rights, is based on sound engineering and will not result in any risk to fresh water. AOGCC's administrative approval to conduct cyclic service and development operation of KRU 3S -18 is governed by the following: 1. CPAI is authorized to conduct preliminary work including wellbore pressure testing and cement bond logging as outlined in the provided procedure and submit the results of this work to the Commission; • • AIO 2B.069 January 4, 2012 Page 2 of 3 2. If the submitted integrity information is determined satisfactory, Application for Sundry Approval #311 -386 will authorize CPAI to convert KRU 3S -18 from development to service and begin the first injection cycle; 3. CPAI shall submit Form 404, "Report of Sundry Operations" documenting the conversion; 4. CPAI shall notify the Commission Inspector and perform an MIT -IA to the maximum anticipated injection pressure when well conditions have stabilized; 5. Throughout the project, CPAI shall submit to the AOGCC a monthly report of well pressures regardless of well status and injection rates while injecting; 6. When it is determined to convert the well from service to development, CPAI shall provide electronic notification to the Commission and file Form 404 documenting the conversion; 7. When it is determined to begin the next injection cycle, CPAI shall provide electronic notification to the Commission and comply with Rules 3 — 6 for the duration of the project, however at the discretion of the Commission a new MIT -1A may not be necessary if pressure integrity continues to be demonstrated based on the monthly information required by Rule 5; 8. Within 60 days of the conclusion of each production cycle, CPAI shall provide an interim report of the well performance. 9. Within 60 days of the conclusion of the multiple cycle project, CPAI shall provide a final report for the project. DONE at Anchorage, Alaska and dated January 4, 2012. tAiii/ ITAL4,,,,,, ..„,. /.0 Daniel T. eamount, Jr. OF to'rman Cath P. Foerster Chair, Commissioner ommissioner Commissioner OIL,q� i ' s "a i A -- 7 • AIO 2B.069 January 4, 2012 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within l0 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather. the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tNhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday. in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. ~~. 06/08/07 Schlumberger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: 1 zom SCANNED JUN 1 4 2007 Field: Kuparuk éJQÇ) -é)0f0 Well Job# Log Description ... Date CD BL Color 2M-13 11665442 SBHP SURVEY OS/28/07 1 1J-105 11632710 GLS OS/26/07 1 2N-305 11632713 SBHP SURVEY . OS/29/07 1 1 R-20 11665444 LDL 05/30/07 1 1Q-03 11630480 PRODUCTION PROFILE 06/01/07 1 3S-18 11629016 PRODUCTION PROFILE 06/03/07 1 2M-02 N/A SBHP SURVEY 06/04/07 1 2M-06 11628958 SBHP SURVEY 06/05/07 1 2M-04 11629022 SBHP SURVEY 06/05/07 1 1 H-11 11629026 PRODUCTION PROFILE 06/07/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. tJ~ . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 3S-16, 3S-17, 3S-17A, 3S-18. 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-16: UIC- 903-0ö? it 1(/3t'd.- Digital Log Images: 50-103-20445-00 1 CD Rom 3S-17: UIQ dö3 -bl5' :it 1'-{3~3 Digital Log Images: 50-103-20448-00 1 CD Rom SCANNED fEB 0 1 2007 U~Q - 3S-17A: Qö"3-o"f5D ~ Il13~1 Digital Log Images: 50-103-20448-01 1 CD Rom 3S-18: Qôé} -dÓ<":' ~ IL(375Ö Digital Log Images: 50-103-20433-00 1 CD Rom Cs, Jt\~~l '31001 /- ~ . ~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 ~O~"''d.Ð(P 3S-\8 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18,2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~~~ 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 Initial top Vol. of cement Final top of Cement top Name PTD # of cement um ed cement off date ft bbls ft e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2003 f ?)loOO RE: MWD Formation Evaluation Logs 3S-18, AK-MW-22 1 83 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-18: Digital Log Images 50-103-20433-00 QÓ {) - r;;-DCa 1 CD Rom t & ~/90/0~) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 'ð J., ~" ì--oo r DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022060 Well Name/No. KUPARUK RIV UNIT 3S-18 Operator CONOCOPHILLlPS ALASKA INC 5ìJ ~d. Æ) Il/ù v ..{ ó (} /-. API No. 50-103-20433-00-00 MD 6900./ TVD 6118"/ Completion Date 12/8/2002 Completion Status 1-01L Current Status 1-01L UIC N ----~- ------ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ---- --~-~--- DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neut Well Log Information: (data taken from Logs Portion of Master Well Data Maint) . Logl Data Digital Type Med/Frmt --~--_.-_._---~~~---- Log reD 0 .- Electr Dataset Number Name /Pressure ~43 LIS Verification Name Interval Start Stop ---' Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 5 Blu 1 6376 6787 Case 12/20/2002 Prior to Initial Perforations 52 6862 Open 4/29/2003 REPLACED BY NEW DATA RCCVD 07/24/2003 3 52 6862 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 5 Blu 6376 6787 Case 12/20/2002 After Initial Perforations 0 6900 Open 12/13/2002 Blu 6490 6669 Case 5/27/2004 FBHP SURVEY. PRESSITEMP 5 Blu 6380 6787 Case 12/20/2002 Prior to Initial Perforations 0 6900 Open 12/13/2002 3 52 6862 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 52 6862 Open 4/29/2003 REPLACED BY NEW ---- DATA RCVD 07/24/2003 Sample Set Sent Received Number Comments J2Ó 0 ¿.;(1643 LIS Verification Log Rpt Log Log ED D Rpt Rpt ........-pressure Directional Survey /Pressure ~mperature ,~;ctional Survey UIS Verification VLlS Verification ---~------- Well Cores/Samples Information: DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Well Name/No. KUPARUK RIV UNIT 3S-18 OperatorCONOCOPHILLlPS ALASKA INC Permit to Drill 2022060 MD 6900 TVD 6118 Completion Date 12/8/2002 Completion Status 1-01L Current Status 1-01L Well Cored? ADDITIONAL INFORMATION y{{J) Daily History Received? ~/N ~/N Formation Tops Chips Received? --_...Y.J-N- Analysis Received? -~._---------~-----~------- ----_._-----------_._----~-- Comments: -~~~._----~ Y / N -. .--- -- L } ----------~ Date: Compliance Reviewed By: API No. 50-103-20433-00-00 UIC N ~/ ;Z~~)~. ~.~ ~--- ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 202-206 38-18 6. Permit to Drill Number: 7. Well Name: 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 8. API Number: 50-103-20433-00 9. Field: 12/24/2002 Volume (bbls): Number of days disposal occurred Kuparuk River Field Disposal Source Wells: Ending Dates: 302-392 (h)(3) Other Commission approved substances (include descriptions in block 12) Disposal Beginning Dates: '~I Previous totals (bbls): 306* 306 3/4/2003 38-15, 38-16, 38-22, 38-08, 38- 08B 1/16/2003 31601 100 47 0 31501 2003/1st YYYY /0# YYYY /0# YYYY /0# ,~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. Total Ending Volume (bbls): 31907 47 100 306 31501 Step Rate Test 0 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~,. - ~_-lÌ" ~~.........e;.~ \("G{01 Signature: Date: ~~\~ \ e.-,.-. L<.--< 'uç-- 6~:$0 Printed Name: Phone Number: Title: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ) Conoc~hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 'iIEC€/' ; I",", J/}:;h i.. 'U 1'I'i8.teQy4 Gas ~ 1 200J ~, 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 MJ~ // ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off ConocoPhillips Problem Well Supervisor Kuparuk Field Attachment :Co\. "\ ~ f'<)~ «.. ~,~C""\. ~~ ~,,-<:t ~"'\-- +0 If ~\\ \P~c:...~" cA~~ b~"~ ';.~~ c¡,'!,.~..:> \ \ '-I ,~""«.,,,~d -\e::. ">""~. À \ \ o~ -\-4.. "T() <..'c ~~"" ~ ~\<ê. ~~~'1 ~Q~\ +'-'<ë. su~~. ~O.Çù'~~CL' <J..c...\\o ~ t"\<"L<::t.~{J..''i t ß)!/Yf(l~ Á -o-S Well Well TOC Volume Sacks Name PTD# Type ft BBLS Cement 38-03 2030910 Prod 8 0.6 3.6 38-07 2021870 Prod 8 1.5 9.1 38-09 2022050 Inj 14 2.5 15.1 38-10 2022320 Prod 12 1.5 9.1 38-14 2022210 Inj 3 1.5 9.1 38-15 2022540 Prod 8 0.8 4.8 3S-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 38-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 38-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0.3 1.8 ) ~:¡-~Ob ( t LPtf 3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 03, 2003 RE: MWD FonnationEvaluationLogs 3S-18, AK-MW-22183 1 LDWG fonnatted Disc with verification listing. PùPI#: 50-103-20433-00 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. Anfœße+ve~ JUL 24 2003 ('\ AIìIØIOiI & Gas Coos. Commisllion Signed:<;::--'~ Andtorage 0 Note: This Data Replaces Any Previous Data For We1l3S-18. TUBING (0-6577, 00:3.500, 10:2.992) Anchor Nipple (6544b545. 00:4 ì40) m (6ffi -6..1178 00:3.500) Perf (6642-B678) ') ~Oà~ d-Dlp ) ConocoPhillips Alaska, Inc. r 1-.1 . -I: 1 i ~ ~ .~~t, ., j~ ,.', .~;,ï il~;., I.i~; , ~+ II, 81iti" ,', i~t~ : ~, ,¡II. ,: ~r,¡¡:., I~, ]!'r. ,:: ~-" I i~, I .;t. i ii3'. ']~"'" ,>', ""'-irJ' , I ¡,i-. I~" ;:~~ 'I ~ ~Ii~;-: ,'~'.i. 5~' ~ I 'I n " . ... III:J'I' ~' Ii : ~ ;,.,',i,u~ i. , II ~ =t 3$18 API: 501032043300 SSSV Type: Nipple Annular Fluid: Reference Log: RKB 24.78' Last Tag: 6670'ELM Last Tag Date: 3/14/2003 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String - TUBING Size I Top 3.500 0 Periorations Summary Interval I TVD I Zone 6642 - 6678 5863 - 5898 C-4 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2882 2581 CAMCO KBUG 2 4311 3789 CAMCO KBUG 3 5330 4646 CAMCO KBUG 4 6002 5249 CAMCO KBUG 5 6429 5653 CAMCO IVMG QthQr l )JUg$,eqLÏip.;. øt¿,' :..JSWELRY Depth TVD Type 25 25 HANGER 498 497 NIP 6481 5704 SLEEVE-C 6530 5752 PBR 6544 5766 Anchor Nipple PACKER NIP WLEG TTL Bottom 6577 KRU 38-18 Well Type: PROD Orig 12/3/2002 Completion: Last W/O: Ref Log Date: TO: 6900 ftKB Max Hole Angle: 36 deg @ 2255 Angle (â1 TS: 8 deg (â16643 Angle@TD: 7 deg @ 6900 Rev Reason: Tag PBTD Last Update: 4/2/2003 Top Bottom TVD Wt Grade Thread 0 108 108 62.50 H-40 WELD 0 2840 2547 40.00 L-80 BTCM 0 6887 6106 26.00 L-80 BTCM TVD Wt I Grade I Thread 5798 9.30 L-80 EUE8rd I Status I Ft SPF Date I Type I Comment 36 6 12/8/2002 IPERF 2.5" 2506 PJ, 60 deg ph V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK-5 0.000 0 12/2/2002 DMY 1.0 BK-5 0.000 0 12/2/2002 DMY 1.0 BK-5 0.000 0 12/2/2002 DMY 1.0 BK-5 0.000 0 12/2/2002 DMY 1.5 RK 0.000 0 12/5/2002 Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE BAKER SLIDING CMU SLEEVE W/2.812" OS PROFILE - closed BAKER 80-40 PBR ID 3.500 2.875 2.812 2.990 2.993 6545 5767 6569 5791 6576 5797 6577 5798 Genëral Notes Date Note 12/2/2002 TREE: FMC / GEN 5/5M TREE CAP CONNECTION: TOP 5 3/4" ACME W/3.5" EUE 8RD THREAD BAKER SAB-3 PACKER W/4.5" MILLOUT EXTENSION @6549 W/3.75" 10 3.250 CAMCO '0' NIPPLE 2.750 BAKER PUMP OUT SUB 2.990 2.992 ) ') a ca-do to /lfoL/3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Carom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 18, 2003 RE: MWD Fonnation Evaluation Logs 38-18, AK-MW-22183 1 LDWG fonnatted Disc with verification listing. llPI#: 50-103-20433-00 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: Si~.~~ RECEIVED APR 2 9 2003 Alaska œ & Gas Cons, CommiSSìo Anchorage n Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 J an 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CD2-36, CD2-51 ì 2003 38-10 21104 100 0 21204 388 0 21592 March March 3S-21, 3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 2002 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October 2002 2002 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 Source Wells 2P-427, Heavenly CD2-13, CD2-37, CD2- 35 2P-44 1 , 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-38, CD2-44, CD2- 29, CD2-13 CD2-50, CD2-46, CD2- 22 ) Qj 0 (L; \ ~ Alaska Oil & Gas Cons. Commission 0 Anchorage \) <ECEIVED APR 1 6 Z003 fI' ,~ Annular Disposal during the first quarter of 2003: ¡~ \~ ~ h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells ~ Well Name Volume Volume Volume Quarter. Protect Total Total Date Date Volumes ('~ '(S 38-18 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 38-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 ( CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2.;08, CD2-36, CD2-51 2003 38-10 21104 100 0 21204 388 0 21592 March March 3S-21,3S-08 2003 2003 1 C-22 26944 100 0 27044 0 0 27044 March March lC-190,lC-174 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441,2P-431,Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 . , ~ ConocoPhlllips Alaska, Inc. TUBING f ~ . ! ¡- ((}fun, [ ~ ~ ï OD:3 500, ~ I "" " , I. I ID:2992) i: ~ U I ~, r I I [ I I ' ~ ,i.~ I ,'ii' IIÌJ I.;~I , I ¡8m,'':: t t;;:' , I~~ If}" .,' ~. ~~". ' ' I 1-11, ~ ~:: * .t1t ~' I I 11 ..L I ~,~ -,w.\.¡ tl' ".', , r J ! I I' , ;,'1:(. I. .', ,; ~,~ -',:, : jl I 'I k ~ ! : ! Anchor tJlpple (65446545, OD:4.740) TTL (6577.ß578, OD:3.500) - '-PII ~: ---'.'" :L Perf (6642-6678) . -- -t ) 3S-18 API' 501032043300 SSSV Type: Nipple Annular Fluid' Reference Log: RKB 24.78' Last Tag: 6788 E-Line Last Tag Date 12/8/2002 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String - TUBING Size I Top I Bottom 3.500 0 6577 Perforations Summary Interval I TVD I Zone 6642 - 6678 5863 - 5898 C-4 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2882 2581 CAMCO KBUG 2 4311 3789 CAMCO KBUG 3 5330 4646 CAMCO KBUG 4 6002 5249 CAMCO KBUG 5 6429 5653 CAMCO M'v1G Other l3lugs, equip., etc.: - JEWELRY Depth TVD Type 25 25 HANGER 498 497 NIP 6481 5704 SLEEVE-C 6530 5752 PBR 6544 5766 Anchor Nipple PACKER NIP WLEG TTL "') ~Od -f:)OCsJ KRU 35-18 Well Type: PROD Orig 12/3/2002 Completion: Last W/O' Ref Log Date: TO: 6900 ftKB Max Hole Angle: 36 deg @ 2255 Angle@TS: 8 deg @ 6643 Angle @ TO: 7 deg @ 6900 Rev Reason: Add Anchor nipple Last Update 1/17/2003 Top 0 0 0 Bottom 108 2840 6887 TVD 108 2547 6106 Wt Grade Thread 62.50 H-40 WELD 40.00 L-80 BTCM 26.00 L..80 BTCM TVD 5798 I Grade I L-80 Thread EUE8rd Wt 9.30 I Status I Ft SPF Date I Type I Comment 36 6 12/8/2002 ¡PERF 2.5" 2506 PJ, 60 deg ph V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK-5 0.000 0 12/2/2002 DMY 1.0 BK-5 0000 0 12/2/2002 DMY 1.0 BK-5 0.000 0 12/2/2002 DMY 1.0 BK..5 0.000 0 12/2/2002 DMY 1.5 RK 0.000 0 12/5/2002 Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE BAKER SLIDING CMU SLEEVE W/2 812" OS PROFILE - closed BAKER 80-40 PBR 10 3.500 2.875 2.812 2.990 2.993 6545 5767 6569 5791 6576 5797 6577 5798 General Notes Date Note 12/2/2002 TREE: FMC / GEN 5/5M TREE CAP CONNECTION: TOP 5 3/4" ACME W/3.5" EUE 8RD THREAD BAKER SAB-3 PACKER W/4.5" MILLOUT EXTENSION @6549 W/3.75" 10 CAMCO '0' NIPPLE BAKER PUMP OUT SUB 3.250 2.750 2.990 2.992 RECEIVE,) PI'lP ~i!i-" \ ~ t1 ~; ~') C¡ !) I '¡- '- ,¡ \-' -oJ AlaSK& 0;-; & , .. ~~',~:.'n:n~'rl I\n t~r¡ 01!~'::~'~ ) Casing Detail 9 5/8" Surface Casina ~.PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 66 Nabors 7ES RKB to Landing Ring 29.58' FMC Gen V Hanger 9-5/811 40# L-80 BTC Csg Davis Lynch Float Collar 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Shoe 64 Jts Jts 1 to 2 2Jts TD 12 1/4" Surface Hole 12-1/4" T.D. @ 28551 MD 25591 TVD 9-5/811 Shoe @ 28401 MD 2547' TVD RUN TOTAL 13 BOWSPRING CENTRALlZERS- 2 on jt.#1 (31 to 51 above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 51 below Float Collar) 1 per jt on Jt #3 - #12 Total of 84 Jts. On location (Including extra float equip.) Total of 7 Jts. Outside shed (Including extra float equip.) Total of 77 Jts. Inside shed Run Total of 66 Jts. Total of 11 Jts. Left out inside shed Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 130 Dn Wt - 105 Block Wt - 30k Drifted all casing to 8.679° Wen: 3S-18 Date: 11/25/2002 LENGTH 29.58 1.27 2723.54 1.46 83.08 1.69 DEPTH TOPS 29.58 30.85 2754.39 2755.85 2838.93 2840.62 2855.00 Supervisor: Mike Thornton / Pete Wilson ConocpPhillips Alaska Cementing Report Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING .'" . . . .. ':':'~'/P.~i:dã~" : Hole Size: 12.250 (in) TMD Set: 2,840 (ft) Date Set: 11/25/2002 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ) Page 1 of 3 Report #: Start: Spud Date: 11/23/2002 1 Report Date: 11/25/2002 11/22/2002 End: 12/3/2002 : '~: ~..", .... . . . . .';;~~J~~~:D::J~~;t¥~~;yp~~~~;~~: Hole Size: Hole Size: sa TMD: (ft) TMD Set: sa Date: Date Set: sa Type: Csg Type: SO TMD: sa Date: Cmtd. Csg: Cementer: Jerry Culpepper Cmtd. Csg: Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement: . " , ,Pipe.'Mov~m~nt. . Rot Time Start: Time End:: RPM: Ree Time Start:07:00 Time End: 10:30 SPM: 1 Type: Cement Casing Volume Excess %: 350.00 Meas. From: 308 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 281 (gpm) Mud Circ Press: 300 (psi) , Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 130 (Ibs) Max Torque: (ft-Ibf) Drag Down: 105 (Ibs) Stage No: 1 of 1 Start Mix Cmt: 10:00 Disp Avg Rate: 8.00 (bbl/min) Returns: 100 Start Slurry Displ: 10:30 Disp Max Rate: 8.00 (bbl/min) Total Mud Lost: (bbl) Start Displ: 12:00 Bump Plug: Y Cmt Vol to Surf: 308.00 (bbl) End Pumping: 12:25 Press Prior: 375 (psi) End Pump Date: 11/25/2002 Press Bumped: 1,000 (psi) Ann Flow After: N Top Plug: Y Press Held: 2 (min) Mixing Method: Bottom Plug: Y Float Held: Y Density Meas By: . . . ';M~~:Q~t~:':,.:';., Type: Spud Mud Density: 9.3 (ppg) Visc: 60 (s/qt) Bottom Hole Circulating Temperature: eF) Displacement Fluid Type:Mud PVIYP: 22 (cp)/24 (lb/100ft2) Gels 10 sec: 14 (lb/100ft2) Gels 10 min: 22 (lb/10Qft2) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 208.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) , Stage No: 1 S~ur.ry No: 1 of4 To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Class: Density: 8.40 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 12113(2002 2:51 :09 PM ) Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING " , : Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: ') ConocoPhiillps Alaska Cementing Report Page 2 of 3 Report #: Start: Spud Date: 11/23/2002 1 Report Date: 11/25/2002 11/22/2002 End: 12/3/2002 .' ..,." . ~t~.ge:'~():: 1'S1Ù~ti,;~~;'.i)f::~: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) , . Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) . '.... ..' ." .' ." . Stagé No: 1slurlj.: No: 3:-o(~ :.. Description: ARCTIC SET Class: G To: 1,681.00 (ft) Cmt Vol: 486.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Slurry Vol:637 (sk) Water Vol: 295.7 (bbl) Other Vol: 0 Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: eF) (OF) Trade Name D79 S001 D46 D65 D124 D53 D44 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 4 - Additives Type Concentration Units Liquid Cone. 1.5C %BWOC 1.5C %BWOC 0.60 %BWOC 0.5e %BWOC 43.1 C %BWOC 30.0C %BWOC . . . . -. ,"~tàg:e :~~:;1,;~IUfry"~,~;:,~,:~(~,,'::: Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 2,840.00 (ft)To: 1,681.00 (ft) Cmt Vol: 99.7 (bbl) Water Source: Slurry Vol:250 (sk) Test Data Thickening Time: 4.41 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Class: G Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 44.3 (bbl) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Units 9.0e %BWOW Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 12/13/2002 2:51 :09 PM ') ') ConocoPhillips Alaska, , Cementing Report Page 3 of.3 Legal Well Name: 3S-18 Common Well Name: 3S-18 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/23/2002 1 Report Date: 11/25/2002 11/22/2002 End: 12/3/2002 Stage No: 1 Slurry No: 4 of 4 . Additives Trade Name Type Concentration 'Units Liquid Cone. Units D79 D46 D124 D65 D164 0.50 %BWOC 0.6C %BWOC 29.54 %BWOC 1.00 %BWOC 16.63 %BWOC Casing Test Shoe Test Liner Top Test 'Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: - . . . . '.L~~StlrrèY:EV~IUåtion .,' ':. CBl Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to log: " . . . . . . . ..'lnt~r-pr~tå.tiOii :,801111nary.:'. Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Circ & Cond Mud for Cmtg Csg, lowered Vis from 128 to 60, YP from 48 to 24, Final Circ rate 6.7 Bpm at 300 Psi, last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg RU Dowell, Pumped 5 bbls CW 100 Chern Wash, Tested lines to 3,000 Psi, Pumped 45 bbls CW 100 Chern Wash at 8.3 ppg, 7 Bpm @ 200 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 6.8 bpm @ 200 Psi with Red Dye in Spacer, Mixed & Pumped 486 bbls, 637 sxs of lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.5 bpm @ 200 Psi, Reciprocated Pipe until Mudpush at Shoe, then Pipe got Tight-Landed Pipe, Did Not Observe Nut Plug or Red Dye Markers at Shaker,. Pumped- ~ead Cmt until Crnt to Surface.100 bbls late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield,Pumped @ 7 Bpm @ 350 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 188.7 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 630 Psi, Slowed to 3 bpm @ 375 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 308 bbls of 10.7 ppg Gmt back to Surface, Had Full Returns throughout Job- GIP at 12:25 Hrs 11/25/02 Printed: 12/13/2002 2:51 :09 PM ) ) ConocoPhillips, Alaska Daily Drilling Re,port I JOB NUMBER I EVENTODCRODE 124 HRS PROG TMD I TVD I DFS 3S-18 2,855.0 2,559.0 3.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Mike ThorntonlPeter Wils N1268@ppco.co Nabors 7ES Kuparuk River 6,879.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD Fin Testing BOP's, Prep to PU 81/2" Dir BHA 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL TIH, Ciro & Test Csg, Drill Fit Equip & 20' Perf LOT, Drill 11/25/2002 318,620 LrrHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE WCDK3S.0080.01 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 11/24/2002 2,786.43 34.620 289.290 9.625 (in) @ 2,840.0 (ft) 7.000 (in) @ 6,879.0 (ft) DENSI1Y(ppg) I 9.30 I PP I IECD IMUD DATAl DAILY COST I 0.00 I CUM COST ] 0.00 FV PVNP GELS WUHTHP FCrr.SOL OIUWAT %SandlMBT Ph/pM PflMf CI Ca H2S LIME ES 60 22/24 14/22 6.6/ 2/ / /22.5 8.5/ / Page 1 of 2 WELL NAME I REPT NO. I DATE 4 11/25/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 629,358 AUTH. 2,069,102 LAST BOP PRES TEST OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01 :30 1.50 CASE P RURD SURFAC Fin RU to Run 9 5/8" Csg, Made Dummy Run with Hanger & Landing Jt & Ck Ok. 01 :30 06:00 4.50 CASE P RUNC SURFAC Held Safety Mtg on Running of 9 5/8" Csg, MU 9 5/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 64 Jts of 95/8" Csg, (Total of 66 Jts Ran 2,840.62') While TIH Started taking Wt at 1,709", Est Circ and Washed from 1,709' to 1,751', Cont TIH with no Problems, Landed Csg in Head - Landed Csg wi FS @ 2,840', FC @ 2,754'. 06:00 07:00 1.00 CASE P RURD SURFAC RD Fill-Up tool & MU Cement Head 07:00 10:30 3.50 CASE P CIRC SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 60, YP from 48 to 24, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg 10:30 12:00 1.50 CEMENT P PUMP SURFAC RU Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lihes to 3,000 Psi, Pumped 45 bbls CW 100 Chem Wash at 8.3 ppg, 7 Bpm @ 200 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 6.8 bpm @ 200 Psi with Red Dye in Spacer, Mixed & Pumped 486 bbls, 637 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.5 bpm @ 200 Psi, Reciprocated Pipe until Mudpush at Shoe, then Pipe got Tight-Landed Pipe, Did Not Observe Nut Plug or Red Dye Markers at Shaker, Pumped Lead Cmt until Cmt to Surface-100 bbls Late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield,Pumped @ 7 Bpm @ 350 Psi, 12:00 12:30 0.50 CEMENT P DISP SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 188.7 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 630 Psi, Slowed to 3 bpm @ 375 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eft on Rig Pumps, Had 308 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 12:25 Hrs 11/25/02 12:30 15:00 2.50 CEMENT P RURD SURFAC RD Cmt Head, LD Landing JT & RD Csg Equipment, Cleared Rig Floor 15:00 16:00 1.00 CEMENT P OTHR SURFAC Flushed Out Stack with Jetting Tool 16:00 19:00 3.00 WELCTL P NUND SURFAC ND 21 1/4" Divertor & 16" Divertor Line 19: 00 20:00 1.00 WELCTL P NUND SURFAC Installed FMC Gen V 11" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead 20:00 23:30 3.50 WELCTL P NUND SURFAC NU 135/8" 5M BOP Stack 23:30 00:00 0.50 WELCTL P BOPE SURFAC RU to test BOP's Printed: 12/13/2002 2:50:10 PM WELL NAME ConocoPhillips, Alaska Daily Drilling Report JOB NUMBER EVENTODCRODE 24HRS PROG ITMD 2,855.0 3S-18 ) Page 2 012 I TVD I DFS I REPT NO. I DATE 2,559.0 3.00 4 11/25/2002 24 HR SUMMARY: Ran 95/8" Csg to 2,840', Circ & Cond Mud, Cmt'd Csg with 308 bbls of 10.7# Cmt to Surface, Bumped Plugs & Floats Held, ND Divertor, NU Gen V Wellhead & Tested, NU 135/8" 5M BOP's, RU to Test BOP COMPANY ConocoPhillips Nabors Doyon Universal Sperry Sun PERSONNEL DATA NO. HOURS COMPANY 2 I Baroid 34 CanRig 6 APC 4 SERVICE ITEM MATERIALS I CONSUMPTION ON HAND ITEM 22,925 Water, Potable 421 UNITS gals bbls USAGE 1,291 1,266 Fuel Water, Drilling SERVICE UNITS gals USAGE 5,590 NO. HOURS 2 1 2 ON HAND 15,210 Printed: 12/13/2002 2:50: 1 0 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. ¡Well Name: 3S-18 Rig: Nabors 7ES Date: 11/26/2002 I Volume Input Drilling Supervisor: Mike Thornton/Granville Rizek Pump used: 1#1 Mud Pump I. St k I ro es T 0.0706 Bbls/Strk T Type of Test: I Casing Shoe Test LOTIFIT ~ Pumping down annulus and DP. ~ Casin9 Test Pressure Integrity Test Hole Size: 18-1/2" I'" Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 27.0 Ft 2,840 Ft-MD 2,547 Ft-TVD 2,875 Ft-MD 2,575 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 19-5/8" 40#/Ft L-80 BTC I... 0 0 0 2650 0 0 0 1140 Casina Test Pressure IntearitvTest 7 316 1 2650 2 0 0.25 1140 Mud Weight: 9.5 ppg Mud Weight: 9.5 ppg 14 700 2 2650 4 36 0.5 1130 Mud 10 min Gel: 4.0 Lb/100 Ft2 Mud 10 min Gel: 4.0 Lb/100 Ft2 21 966 3 2630 6 125 1 1120 Test Pressure: 2,500 psi Rotating Weight: 98,000 Lbs 28 1340 4 2630 8 240 1.5 1100 Rotating Weight: 98,000 Lbs BlockslTop Drive Weight: 25,000 Lbs 35 1797 5 2630 10 377 2 1080 Blocks/Top Drive Weight: 25,000 Lbs Desired PIT EMW: 18.0 ppg 42 2357 6 2630 12 518 2.5 1050 Estimates for Test: 1.7 bbls Estimates for Test: 1126 psi 0.8 bbls 45 2650 7 2630 14 644 3 1040 I... I'" 8 2630 16 738 3.5 1020 EMW = Leak-off Pressure + Mud Weight = 1140 + 95 PIT 15 Second 9 2630 18 816 4 1010 0.052 x TVD 0.052 x 2547' Shut-in Pressure, psi 10 2620 20 900 4.5 1010 EMW at 2840 Ft-MD (2547 Ft- TVD) = 18.1 ppg 1140 15 2620 22 983 5 1010 20 2620 24 1055 5.5 1005 25 2620 26 1140 6 1000 30 2620 6.5 990 7 980 7.5 980 8 970 8.5 970 9 950 9.5 950 10 950 3000 . ~ost 30 psi during test, held 98.9% of test pressure. . w""~ . 2500 - 2000 - u..J c:::: ::> ~ 1500. u..J a:: a.. 1 000 . 500 - 0 0 4 0 10 15 20 25 30 Shut-In time, Minutes 0 PIT Point 2 Barrels ---CASING TEST --- LEAK-OFF TEST Comments: Changed hole over to 9.5 ppg new LSND mud prior to FIT. Volume Pumped 3.2 tsbls Volume/Stroke Pump Rate: 8.0 Strk/min T ~ Volume Bled Back 3.2 Bbls Volume Bled Back 1.8 tsbls \---/ Volume Pumped 1.8 Bbls ConocoPhillips Alaska Jt Number Num of Jts Jts 3 to 161 Jts 1 to 2 Remarks: 159 Jts 2 Jts Up Wt = 215k ~) ) Casing Detail 7" Intermediate Casina COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LOS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg pup joint (on hanger) 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Collar 7M 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe TD of 8-1/2" hole @ 6900' MD 6118' TVD 7" Shoe @ 6887' MD 6105' TVD Total Centralizers 1- 7" Bowspring centralizer over stop rings center of joints # 1 & #2 Bowspring centralizer over collar on joints #3 thru #20 (Total of 20) 7" x 8-3/8" Centering guide on every jt. From #96 thru #1 00 (Total of 5) 7" x 8-3/8" Centering guide on every third jt. From #148 to #160 (Total of 5) Total of 170 jts.in pipe shed I Total jts on location 183 Total of 161 jts. Ran in hole Total of 9 its. Out (9 its. Inside shed & 13 its. Outside shed) Use Jet Lube IIRun-N-Seal" pipe dope Drifted all casing to 6.151 M On Wt = 120k Block Wt= 30k Well: 38-18 Date: 12/1/2002 LENGTH 26.98 .73 1.47 6768.83 1.35 86.33 1.40 DEPTH TOPS 26.98 27.71 29.18 6798.01 6799.36 6885.69 6887.09 Supervisor: Mike Thornton /Granville Rizek ") ConocoPhlllip$ Alaska Cementing Report Legal Well Name: 3S-18 Common Well Name: 3S-18 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 6,887 (ft) 12/1/2002 Production Casing 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: ') Page 1 of 3 Spud Date: 11/23/2002 2 Report Date: 12/1/2002 11/22/2002 End: 12/3/2002 Cement Job Type: Primary Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Culpepper Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: SO Type: Cmtd. Csg: .. .. . . ... . ,~, ".!:. ~ '. ~ ':. . , '" . . ,... , ~~.P.e:.~.~Y~",,~~t.:. Rot Time Start: : Time End:: RPM: Init Torque: (ft-Ibf) Rec Time Start:18:30 Time End: 20:30 SPM: 42 Stroke Length: 15.0 (ft) T~pe: Cement Casing Volume Excess %: 0.75 Meas. From: none Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 435 (psi) Start Mix Cmt: 21 :00 Start Slurry Displ: 22:01 Start Displ: 22:41 End Pumping: 23:55 End Pump Date: 12/1/2002 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Mud Data Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating (ft) (ft) Avg Torque: (ft-Ibf) Drag Up: 215 (Ibs) 5.00 (bbl/min) 5.00 (bbl/min) Y 1,800 (psi) 2,300 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: 120 (Ibs) Returns: FULL Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch Density Meas By: Densometer Type: Non-Disp. LS Density: 12.3 (ppg) Vise: 46 (s/qt) PVfYP: 17 (cp)/20 (lb/10Oft2) Gels 10 see: 4 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Circulating Temperature:114 (OF) Bottom Hole Static Temperature: 143 (OF) Displacement Fluid Type:Seawater Density: 9.4 (ppg) Volume: 264.00 (bbl) Stage" N;o:, 1:$lurry ~o: "1' of 3 Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 3,193.00 (ftJfo: 3,635.00 (ft) Cmt Vol: (bbl) Water Source: Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (ec) Fluid Loss Pressure: (OF) Class: Density: 8.40 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp eF) (OF) Pressure (psi) (psi) Printed: 12/13/2002 2:51: 19 PM '~) ') ConocoPhillips Alaska Cementi"ng Report Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING Page 2 of 3 Report #: Start: Spud Date: 11/23/2002 2 Report Date: 12/1/2002 11/22/2002 End: 12/3/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 3,635.00 (ftJTo: 5,848.00 (ft) Cmt Vol: (bbl) Density: 13.30 (ppg) Yield: (fP/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Temperature: eF) Temperature: (OF) Temperature: eF) (OF) , , . .. ..' . . . ..' " ' :"Ståge N():"1":SI"~rrYNó: 3 of3 " Slurry Data Fluid Type: TAIL Description: Gasblok Slurry Interval: 6,887.00 (ftJTo: 5,848.00 (ft) Cmt Vol: 46.0 (bbl) Water Source: Slurry Vol223 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (fP/sk) WaterVol:31.0 (bbl) Other Vol: () Test Data Thickening Time: 3.70 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Stage No: 1 Slurry No: 3 of 3 - Additives Trade Name , Type DISPERSANT Gasblok DEFOAMER Concentration Units Liquid Conc. D-65 D600G D-47 O.3C %BWOC Purpose: Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: ZONAL ISOL Mix Water: 5.17 (gal) Foam Job: N Pressure (psi) (psi) Units 2.00 G P S 0.2C G P S Printed: 12/13/2002 2:51: 19 PM ') ') Conoco"Phillips Alaska' Cementing Report .Page 3 of 3 Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/23/2002 2 Report Date: 12/1/2002 11/22/2002 End: 12/3/2002 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBl Run: Under Pressure: (psi) Bond Quality: Cet "Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks , . .. Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 223 sxs (46 bbls) @ 15.8 ppg GasBLOK w/ Class G + .300%BWOC D65, 2.000 gal/sk D600G, .200 gal/sk 047, Pump 5 bbls CW100, Test lines to 3500 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 46 bbls cmt at rate of 5.0 bpm at 390 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 217 bbls seawater at rate of 5 bpm at 1050 psi until cmt around shoe, Slowed rate to 3.0 bpm @ 1600 psi & bumped plug w/ total of 264.0 bbls, Bumped plug wI 2300 psi, Bled back 1.8 bbls for a total of 262.2 total bbls displaced, CIP @ 2355 hrs 12/1/02, Had good circ. thru out job, (Note; Calculated displacement to float collar =260.3 bbls, Displacement to Shoe= 263.7 bbls, Displacement around shoe & 1/2 annular volume to base of Kuparuk C =265.9 bbls, Displaced entire job with Dowell. Casing stuck prior to start of cement job. Printed: 12/13/2002 2:51:19 PM 'ConocoPhillips, Alaska' , , Daily Drilling Beport WELL NAME 38-18 IJOB NUMBER EVENTODCRODE 124 HRS PROG TMD TVD DFS 6,900.0 6,118.0 9.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Mike Thornton/G. Rizek N1268@ppco.co Nabors 7ES Kuparuk River 6,879.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Slip & Cut 180+' drilling line 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL LID cement equip, install packoff, RU & Run 3 1/2"compl, N/D 11/29/2002 208,607 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 12.49 WCDK3S.0080.01 2,069,102 LAST SURVEY: DATE TMD INC AZIM I LAST CASING, I NEXT CASING LAST BOP PRES TEST 11/30/2002 6,830.51 7.350 288.280 9.625 (in) @ 2,840.0 (ft) 7.000 (in) @ 6,879.0 (ft) 11/26/2002 '. "~:D::""e,',,~.iv'.'.~,',,.'"",::,S,:",:,ITY:,,, ..:,n,'.(".',..~,~lY',~;",'".9."p",).'.",:,,: !,,:..,c.'.,"'G,",.' '.~E' ,"~" ;,2,:s, .'..3,::., 0, ,",w'. ..'Uti, ).:,'::,'~,TH.",!,'p;!.'.," ' " ".I~p~l. I M,~ 1?1?,t\ 'p~ I ,~A~.L. V Ç?ST I ..,:'Pf' , ,,'.:"'..',0,',',0., :0,' ..' .. , .:"I:I:..':(M~" :,;,'c.:~a:.','.S,,','.,:,:...T"..",.n,.I., :. ,.... ~.,S'. " 0.00 Æ ~¥ " ~ " :.':'FCrr.~öL.:, :--:'.:, QIL/W~J>':f>:\;;~~n~~~l". ::f::'~:;Pþ(P:~>" tm . :!L.~~.F.~)J~S.:~' 46 17/20 417 4.0/10.0 / I 112.5 9.01 I BHANO. I 3 I ,,'.'-::!,;:/.:,i:,2ãij4iHÓ~E>ÒQN,pï1iÖNS::[::'., ,.'c,: '.'" "," 'øH~::Wf~Bt;,L6:v¡:jAi:t~: .>/stRì~(rWr~~l)p:': ..,' '~SfFtING,Wf~)~N" ::,.;.' "':;'~~i~(ß"r:::.=ìQT .:.: .. ," <"TÓRq:~~jUNfTS: ,.: ft-Ibf I.D~ ' 2.850 4,753 2.500 2.813 2.900 2.900 2.900 2.813 2.813 2.813 3.000 2.750 3.000 ') -, : :: ITEM DESCRIPtiON' ::Nqm: 1 1 1 1 1 1 1 1 1 1 9 1 14 Bit Mud Motor Sub - Float Stabilizer LWD Nukes Drill Collar - Hang Off Jt Flex Joint - Non Mag Flex Joint - Non Mag Flex Joint - NonMag Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy W gt . LENGTH": 0.96 25.18 2.15 5.59 37.43 23.79 9.97 29.66 29.98 30.78 272.23 31.71 422.20 'ò~I,)~: . 8.500 6.875 6.625 6.750 6.750 6.750 6.750 6.500 6.500 6.500 5.000 6.250 5.000 BIT J RUN 31 2rr1 . SIZE MANUF. 8.500 HUGHES " BITS TYPE. ,SERIAL NO~ . JETS OR TFA ' HC605 0325531 13/13/13/12/12/ DEPTH IN DATE IN I-O-D-L-B-G..O-R 3,585.0 11/27/20021-1-BT-N-D-J-NO-TD Page 1 of 2 I REPT NO. I DATE 10 12/1/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1 ,463,296 -,.r ';S.IT NO:~j , , 3 -' '~BH~ ~~~G.rH ;. ':'" 921.63 CONN'SlzE: , . ' C;ONNTYPE ~;~¡~W~1'l~Î~~i;...:; ,;:,)¡i~.".'~¡¡,;,~~~'~;,~:{;r~~~~1~1~~;~;~,~i:).,~~t~.~~.,. .q~~:4~,.~J~!~~~~~~~~i 3/ 2rr1 15/25 1100 469 2,900 670 72.81 28.82 3,315.0 115.02 , OPERATIONS SUMMARY FROM TO . HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 02:00 2.00 DRILL P TRIP PROD Continue to POOH f/7" casing. SLM(no correction), Collect torque and drag data. 02:00 06:00 4.00 DRILL P OTHR PROD Work BHA. Remove source fl LWD tools. Download tools, Break & UD tools. Break bit and lay down MM. Hole fill 6.25 bbls over calc. 06:00 06:30 0.50 DRILL P OTHR CMPL TN Pull FMC wear bushing. 06:30 08:00 1.50 CASE P RURD CMPL TN RU casing tools. Change out bails, MU Frank's fillup tool. 08:00 12:30 4.50 CASE P RUNC CMPL TN PJSM, Run 7" 26#/ft L-80 BTC-M casing to 2822' using frank's fillup tool to fill full every 10 joints. 12:30 13:00 0.50 CASE P CIRC CMPL TN Circ csg volume at casing shoe. 3 bpm 230 psi. PU wt 100k, down wt 70k. 13:00 18:30 5.50 CASE P RUNC CMPL TN Continue to run in hole wI 7", 26 #/ft L-80 casing using Frank's fillup tool. Fill Printed: 12/13/2002 2:52:37 PM ConocoPhillips, Alaska , , Daily Drilling Report ¡JOB NUMBER IEVE~DC~DE 124 HRS PROG IT~~900.0 ) WELL NAME 3S-18 FROM TO HOURS CODE TROUBLE SUB 13:00 18:30 5.50 CASE P RUNC 18:30 19:30 1.00 CEMENT P CIRC 19:30 20:30 1.00 CEMENT P 20:30 22:00 1.50 CEMENT P RURD CIRC 22:00 00:00 2.00 CEMENT P PUMP ') Page 201'2 TVD IDFS REPTNO. DATE 6,118.0 9.00 10 12/1/2002 OPERATIONS SUMMARY PHASE ' DESCRIPTION CMPL TN full every 10 joints. MU landing joint and land casing @ 6887'. Displacement within 2 bbls. CMPL TN Circulate and recipicate 7" casing wi frank's fillup tool. PU wt start @ 230 k, finish @ 215 k. SO wt 120 k Circ @ 3 bpm with 618 psi starting, finish wi 280 psi. Circ total of 272 bbls.(3892 strokes) CMPL TN Rig down frank's fillup tool. RU Schlumberger/Dowell cement head. CMPL TN Circulate and condition mud and hole fl cement job. ATTEMPT TO RECIP 7" CASING, Pull to 250 k, no go. Pull to 265 k, no go. Leave casing hanger on load shoulder of casing head. Increased circulating rate fl 3bpm to final of 5 bpm in stages. At 5bpm = 495 psi. PJSM and batch mix cement while circulating. Circ total of 538 bbls. (7720 strokes) CMPL TN Switch over to Dowell. Pump 5 bbls CW 100 @ 8.3 ppg, test lines to 3500 psi, pump another 5 bbls CW 100 @ 8.3 ppg, drop bttm plug, load another bttm plug and top plug. Pump 50 bbls Mud Push XL @ 13.3 ppg, drop bottom plug, pump 46 bbls (223 sx) class G Gasblok with add's @ 15.8 ppg, flush lines w/ seawater to rig, floor. Drop top plug and follow w/ 8.42 ppg seawater till bump plug @ 264 bbls pumped. CIP @ 2355 hrs 12/1/2002. All pumping @ 5 bpm until cement @ shoe, then pump @ 3 bpm. Full returns. Bump plug w/ 2300 psi (500 psi over circ pressure). Bled back 1.8 bbls. Floats held 24 HR SUMMARY: POOH 1/7" casing, Download MWD/LWD tools, UD BHA, pull WB, RU & Run 7" 26 #/ft L-80 csg to 6887',Circ prior to cement job, cement 7" casing. COMPANY ConocoPhillips Nabors, Doyon Universal Sperry Sun SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 Baroid 30 ,CanRig 6 APC 4 SERVICE NO. 2 1 2 HOURS ,ITEM ,UNITS gals bbls , ,MATERIALS '1 CONSUMPTION USAGE' ON HÁND' , ' ITEM ' 2,793 6,583 Water, Potable 373 561 Fuel (camp) ON HAND 14,850 -2,173 Fuel Water, Drilling UNITS gals gals USAGE 4,950 403 'I,' ;" ,':;::"z~~~,:'~~~F~~,~~~~~,~'f~,~];E~~~~')~~[~,:,:,,:,,', ' 290 0 . ~ \r.~.>'" ~ , ' , ' ",'.., '.,'r. ,: ~;i;?:,;~riËsE:tn'öIR~ÄME,' 1 R-18 3S-18 Printed: 12/13/2002 2:52:37 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Nabors 7ES I Date: 12/3/2002 I Volume Input Volume/Stroke Pump used: I #1 Mud Pump I. Strokes'" 0.0698 Bbls/Strk ... ... Pumping down annulus. ... Well Name: 38-18 I Rig: Drilling Supervisor: Granville Rizek Type of Test: I Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" I'" Casing Shoe Depth RKB-CHF: 27.0 Ft 2,840 Ft-MD 2,547 Ft-TVD CasinQ Size and Description: 19-5/8" 40#/Ft L-80 BTC ChanQes for Annular Adequacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Pump Rate: 8.0 Strk/min ~ Casing Test Pum ing Shut-in Strks si Min si Pressure Integrity Test Pumping Shut-in Strks psi Min psi 0 0 0 360 4 25 0.25 280 8 90 0.5 250 12 120 1 220 16 200 1.5 220 20 275 2 210 24 350 2.5 205 28 425 3 200 32 480 3.5 200 36 490 4 200 40 490 4.5 195 44 460 5 195 48 425 5.5 195 52 410 6 190 56 410 6.5 190 60 400 7 190 64 390 7.5 190 68 380 8 190 72 375 8.5 185 76 360 9 185 80 360 9.5 185 84 10 185 88 92 Hole Depth 5,848 Ft-MD 5,107 Ft-TVD l'" Pressure InteQritvTest Mud Weight: 12.3 ppg Inner casing 00: 7.0 In. ,~/ Desired PIT EMW: Estimates for Test: 15.7 ppg 450 psi 0.2 bbls l... I... EMW = Leak-off Pressure + Mud Weight = 477 + 12 3 0.052 x TVD 0.052 x 2547 . EMW at 2840 Ft-MD (2547 Ft- TVD) = 15.9 PIT 15 Second Shut-in Pressure, psi 280 1 000 - , UJ c:x::: :::::> V) V) UJ c:x::: a.. 500 "~ 0;7 0 2 3 Barrels 4 5 6 7 0 10 1 5 20 25 30 Volume Volume Pumped Bled Back 0.0 tsbls _tsbls Volume Pumped 6.4 Bbls Volume Bled Back 2.0 tsbls Shut-In time, Minutes 0 PIT Point ""'-CASING TEST ---LEAK-OFF TEST Comments: 9 5/8" esg shoe tested to 15.7 ppg EMW with 10.8 ppg mud in hole (654 psi) ) ConocJPhiUips January 7, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for3S-18 (202-206) Dear Commissioner: ) Randy Thomas Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Phillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk well 3S-18. If you have any questions regarding this matter, please contact Scott Lowry at 265- 6869. Sincerely, .\~~~ R. Thomas Greater Kuparuk Team Leader CPAI Drilling --- RL T/skad RECEIVED JAN 1 0 2003 Alaska Oil & Gas Cons. Commission Anchorage ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 2538' FNL, 1149' FEL, Sec. 18, T12N, R8E, UM At Top Producing Interval 1628' FNL, 3882' FEL, Sec. 18, T12N, R8E, UM At Total Depth 1617' FNL, 3914' FEL, Sec. 18, T12N, R8E, UM (ASP: 473345, 5994808) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 28 feet ADL 380107 ALK 4624 12. Date Spudded 13. Date T.D. Reached 14. Date comp.,~p, Or Aband. 15. Water Depth, if offshore November 23,2002 November 30,2002 Decemb, 2002 l§») N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su ey 20. Depth where SSSV set 6900' MD / 6118' TVD 6798' MD / 6017' TVD YES 0 No D Land Nipple @ 498' 22. Type Electric or Other Logs Run GR/Res/Dens/Neut 23. 1. Status of well oil0 GasD 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Service D Abandoned D i j ~ \:'~~l a~{ f ,~~,,,,,.,.,O'¡\"ð"i!<,!,}j~ ¡ ì;:" ," ':~J;i; ~, Úšld:~;7::J (ASP: 473377, 5994798) ~ (ASP: 47611 0;'59lr3ã79)~ß' CASING SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2841' Surface 6887' WT. PER FT. 62.5# 40# 26# GRADE B L-BO L-80 HOLE SIZE Classification of Service Well 7. Permit Number 202-206 1 8. API Number 50-103-20433-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3S-18 11. Field and Pool Kuparuk River Oil Pool Kuparuk River Field 16. No. of Completions 21. Thickness of Permafrost 1625' MD 16" 42" CEMENTING RECORD 86 sx Arctic Crete AMOUNT PULLED 637 sx AS IIIL, 250 sx LiteCrete 223 sx Class G w/GasBlok 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 6577' PACKER SET (MD) 6545' 6642' - 6678' MD 5863' - 5898' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production December 20, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing Production for OIL-BBL GAS-MCF 5594 2547 OIL-BBL GAS-MCF 6848 4003 CORE DATA WATER-BBL 18 W A TER..BBL 23 1/4/2003 18 hours Flow Tubing Casing Pressure pressure 285 psi not available 28. Test Period> Calculated 24-Hour Rate> Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RBOMS 9Fl CHOKE SIZE GAS-OIL RATIO 585 97% OIL GRAVITY - API (corr) not available RECEIVED JAN 1 0 2003 Alaska Oil & Gas Cons. Commission Anchorage (/r v Submit in duplicate JAN I h 20m 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top C Sand Top A Sand 6643' 6677.5' 5864' 5898' Annulus left open - freeze protected with diesel. RECE'VED JAN 1 0 2003 1.., ou & Gas Gons. GommissioD A\asl\a Anchorage 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 S. ~\ ~,,, \~ - . Igned ".-.;:a. Title R. Thomas Kuparuk Drilling Team Leader Date I /7/0 3 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 10-407 ) ') Page 1 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-18 38-18 ROT - DRILLING N 1268@ ppco.com Nabors YES Date 8ub From - To Hours Code Code Phase 11/22/2002 00:00 - 08:00 8.00 MOVE RURD MOVE 08:00 - 12:00 4.00 MOVE RURD MOVE 12:00 - 13:00 1.00 MOVE SFTY RIGUP 13:00 - 16:00 3.00 WELCTL NUND SURFAC 16:00 - 21 :00 5.00 MOVE RURD RIGUP 21 :00 - 22:30 1.50 MOVE RURD SURFAC 22:30 - 23:30 1.00 RIGMNT RSRV SURFAC 23:30 - 00:00 0.50 RIGMNT RGRP SURFAC 11/23/2002 00:00 - 01 :00 1.00 WELCTL BOPE SURFAC 01 :00 - 03:00 2.00 RIGMNT RGRP SURFAC 03:00 - 04:00 1.00 WELCTL BOPE SURFAC 04:00 - 06:00 2.00 DRILL PULD SURFAC 06:00 - 09:30 3.50 RIGMNT RGRP SURFAC 09:30 - 00:00 14.50 DRILL DRLG SURFAC 11/24/2002 00:00 - 15:30 15.50 DRILL DRLG SURFAC 15:30 - 18:30 3.00 DRILL CIRC SURFAC 18:30 - 21 :00 2.50 DRILL TRIP SURFAC 21 :00 - 23:00 2.00 DRILL TRIP SURFAC 23:00 - 00:00 1.00 CASE RURD SURFAC 11/25/2002 00:00 - 01 :30 1.50 CASE RURD SURFAC 01 :30 - 06:00 4.50 CASE RUNC SURFAC 06:00 - 07:00 1.00 CASE RURD SURFAC Start: 11/22/2002 Rig Release: 12/3/2002 Rig Number: Spud Date: 11/23/2002 End: 12/3/2002 Group: Description of Operations Blow Down Service Lines from Ball Mill & Injection Skid & Move Same, Blow Down Lines from Pits and Unhook Service Lines, Move Rig Off 3S-07 Well at 08:00 Hrs Moved Rig In and Spotted over Well, Ru Held Pre-Spud Meeting with All Crews, Accepted Rig at 12:00 Hrs 11/22/2002 NU 21 1/4. Divertor with 16. Lines Filled Mud Pits & Mixed Spud Mud, RU Sperry Sun & Baroid Trailers, Set Injection Skid, Berm & Hook Up, Set In Generator for Ball Mill & Hook Up Uility Lines Load BHA into Pipe Shed & Bring Bit & Stab's to Rig Floor Serviced Rig & Top Drive Cleaned Out Hyd Filter on Top Drive PU 1 Std of DP & TIH to 94', No Tag, Function Divertor & Hyd Pump Not Press Up Correctly Rig Repaired Hyd Pump on Koomey Unit Fuction Test Divertor & Koomey Unit, Good Test, Note: John Spaulding with AOGCC Waived Witnessing of Test, Press Tested Standpipe & Mud Line to 3,500 Psi & Ck Ok PU 121/4. Bit #1 on Directional BHA #1, Est Circ & Tagged Up at 100', Shut Down. Repaired Air Boot on Bell Nipple & Repaired Drag Chain to Ball Mill Spud Well at 09:30 Hrs 11/23/02, Drill 12 1/4. Hole Per Directional Plan from 108' to 1,373' MD/1,332' TVD, ART 4.5 Hrs, AST 51/4 Hrs, Drill with 35-40K WOB, 80 RPM's, MM 75 RPM's, 155 Total, 150 SPM, 450 GPM, 1,200 PSi Off Btm, 1,350 Psi On Btm, 4,000 Ft#'s Torque Off, 5,500 Ft#'s On Btm, ROT Wt, 75K, Up Wt 78K, On Wt 75K, Ave 10-20 Units BGG Drill 121/4. Hole from 1,373' to 2,855' MD/ 2,559. TVD, 95/8. Csg Pt. ART 7 3/4 Hrs, AST 3 Hrs, 35-40K WOB, 80-90 Rpm's, Below 2,000' 167 Spm, 500-525 Gpm 1,800 Psi Off Btm, 1,900 PSi On Btm, 5K Torque Off Btm, 6K On, Rot Wt 93K, Up Wt 105K, On Wt 80K Ave 10-20 Units BGG Pumped Hi Vis Sweep & Circ Out Had Good Amount of Sand Back, Pumped 2nd Hi Vis Sweep & Circ Hole Clean at 600 GPM's, Init Press 2,300 Psi, Final Press 2,200 PSi, Rot Pipe at 100 RPM's, Pumped LCM With Sweeps, 1 st sweep Came up 4 bbls before Calc Strokes, 2nd Sweep came Up on Calc Strokes for Gauged Hole Monitored Well..Static, POOH to BHA, No Major Problems, Had 25K Pull at 1,460' & 1,290', Went Down & PU thru WINo Drag, Monitored Well at HWDP POOH & LD MWD & MM Began RU Nabor's Csg Equip, MU Fill-up Tool & Changed Out Elevator Bails Fin RU to Run 9 5/8" Csg, Made Dummy Run with Hanger & Landing Jt & Ck Ok. Held Safety Mtg on Running of 9 5/8. Csg, MU 9 5/8. Float Shoe, 2 Jts of 9 5/8. 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 64 Jts of 9 5/8" Csg, (Total of 66 Jts Ran 2,840.62' ) While TIH Started taking Wt at 1,709", Est Circ and Washed from 1,709' to 1,751', Cont TIH with no Problems, Landed Csg in Head - Landed Csg w/ FS @ 2,840', FC @ 2,754'. RD Fill-Up tool & MU Cement Head Printed: 12/9/2002 3:44:26 PM ") ) Page 2 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-18 3S-18 ROT - DRILLING N1268@ppco.com Nabors 7ES Date Sub From - To Hours Code Code Phase 11/25/2002 07:00 -10:30 3.50 CASE CIRC SURFAC 10:30 - 12:00 1.50 CEMENT PUMP SURFAC 12:00 - 12:30 0.50 CEMENT DISP SURFAC 12:30 - 15:00 2.50 CEMENT RURD SURFAC 15:00 - 16:00 1.00 CEMENT OTHR SURFAC 16:00 - 19:00 3.00 WELCTL NUND SURFAC 19:00 - 20:00 1.00 WELCTL NUND SURFAC 20:00 - 23:30 3.50 WELCTL NUND SURFAC 23:30 - 00:00 0.50 WELCTL BOPE SURFAC 11/26/2002 00:00 - 05:00 5.00 WELCTL BOPE SURFAC 05:00 - 06:00 1.00 WELCTL BOPE SURFAC 06:00 - 07:00 1.00 WELCTL BOPE SURFAC 07:00 - 08:00 1.00 RIGMNT RSRV SURFAC 08:00 - 12:00 4.00 DRILL PULD SURFAC 12:00 - 15:00 3.00 DRILL PULD SURFAC 15:00 - 15:30 0.50 DRILL CIRC SURFAC 15:30 - 16:30 1.00 DRILL OTHR SURFAC 16:30 - 18:30 2.00 DRILL OTHR SURFAC 18:30 - 19:30 1.00 DRILL CIRC SURFAC 19:30 - 20:30 1.00 DRILL OTHR SURFAC 20:30 - 21 :00 0.50 DRILL OTHR PROD 21 :00 - 00:00 3.00 DRILL DRLG PROD Start: 11/22/2002 Rig Release: 12/3/2002 Rig Number: Spud Date: 11/23/2002 End: 12/3/2002 Group: Description of Operations Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 60, YP from 48 to 24, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg RU Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lines to 3,000 Psi, Pumped 45 bbls CW 100 Chem Wash at 8.3 ppg, 7 Bpm @ 200 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 6.8 bpm @ 200 Psi with Red Dye in Spacer, Mixed & Pumped 486 bbls, 637 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.5 bpm @ 200 Psi, Reciprocated Pipe until Mudpush at Shoe, then Pipe got Tight-Landed Pipe, Did Not Observe Nut Plug or Red Dye Markers at Shaker, Pumped Lead Cmt until Cmt to Surface-100 bbls Late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield,Pumped @ 7 Bpm @ 350 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 188.7 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 630 Psi, Slowed to 3 bpm @ 375 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eft on Rig Pumps, Had 308 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 12:25 Hrs 11/25/02 RD Cmt Head, LD Landing JT & RD Csg Equipment, Cleared Rig Floor Flushed Out Stack with Jetting Tool NO 21 1/4" Divertor & 16" Divertor Line Installed FMC Gen V 11" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead NU 13 5/8" 5M BOP Stack RU to test BOP's RU & test 135/8" BOPE. Test Hydril to 250 psi low & 3500 psi high. Test all valves and rams to 250 psi low & 5000 psi high.Test witness waived by AOGCC inspector John Spaulding. RID test joint. PU 7" test joint to test 4.5" x 7" variable rams. Test to 250 and 5000 psi. UD 7" test joint, Install wear bushing. Blow down all lines. Service top drive. PU 8 1/2" BHA. Orient and load same. PU Flex DC's. Test tools. Load sources. RIH wI HWDP. PU 51 jts of 5" DP f/ pipe shed, rabbit pipe. Tag cement @ 2720'. Circ and condition mud f/ casing test. RU to test 9 5/8" casing. Test to 2650 psi for 30 min. Chart test. Good test. Lost 30 psi in 30 min. Drill out cement fl 2720' to FC @ 2754', cement to FS @ 2840', drill out rat hole to 2855', 20' of new hole to 2875'. Circ and displace mud to 9.5 ppg LSND. RU fl FIT test @ 2875' MD (TVD = 2575').9.5 ppg mud with 1140 psi = EMW of 18 ppg. PWD baseline test. 9.5 ppg mud,S" DP, 63/4" DC's, 921' BHA length, 95/8" 40#/ft csg (108.835) @ 2840' 450 gpm - 500 gpm 80 - 120 rpm torque 5530- 5940 ftllb ECD's with clean hole 1 0.02ppg - 10.06ppg Directional drill 8 1/2" f/2875' to 3299' (424') TVD @ 3299' = 2929') ART = 2.25 hrs. AST = .25 hrs Drill wI 10-20k WOB, 100-120 RPM, MM 145-161 RPM's, 150-167 total Printed: 12/9/2002 3:44:26 PM ) ) Page 3 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-18 3S-18 ROT - DRILLING N1268@ppco.com Nabors 7ES Date Sub From - To Hours Code Code Phase 11/26/2002 21 :00 - 00:00 3.00 DRILL DRLG PROD 11/27/2002 00:00 - 01 :00 1.00 DRILL DRLG PROD 01 :00 - 08:30 7.50 DRILL OTHR PROD 08:30 - 09:30 1.00 DRILL CIRC PROD 09:30 - 10:30 1.00 DRILL REAM PROD 10:30 - 12:00 1.50 DRILL TRIP PROD 12:00 - 13:00 1.00 DRILL TRIP PROD 13:00 - 14:30 1.50 DRILL OTHR PROD 14:30 - 15:00 0.50 DRILL TRIP PROD 15:00 - 16:00 1.00 DRILL PULD PROD 16:00 - 19:30 3.50 DRILL OTHR PROD 19:30 - 20:30 1.00 DRILL OTHR PROD 20:30 - 22:30 2.00 DRILL TRIP PROD 22:30 - 00:00 1.50 RIGMNT RSRV PROD 11/28/2002 00:00 - 02:30 2.50 DRILL REAM PROD 02:30 - 03:30 1.00 DRILL CIRC PROD 03:30 - 12:00 8.50 DRILL DRLG PROD Start: 11/22/2002 Rig Release: 12/3/2002 Rig Number: Spud Date: 11/23/2002 End: 12/3/2002 Group: Description of Operations SPM, 440-490 GPM, 1350 psi off bttm, 1550 psi on bttm, torque 6,000 ftllb off bttm, 7,000 ftllb on bttm, PU wt 125 k, SO wt 85 k, rot wt 105 k. Directional drill 8 1/2" f/ 3,299' to 3585' (286') TVD @ 3585' = 3176' ART = 1 hr Drill w/ 10-20 k WOB, 100-120 RPM, MM 145-161 RPM's, 150-167 SPM, 440-490 GPM, 1350 psi off bttm, 1550 psi on bttm, torque 6,000 ftllb off bttm, 7,000 ftllb on bttm, PU wt 125 k, SO wt 85 k, Rot wt 105 k. PWD tool baseline @ 95/8" shoe was 10 ppg. Drilling @ 3200', ECD's had increased to 11 ppg. From 3200' to 3400' ecd's increased to 11.5 ppg while drilling @ 250~300 ft per hour. While drilling f/3400' to 3500' @ 250-350 ftlhr, ecd's were 11-11.6 ppg. with a spike over 12 ppg. While drilling 3500'-3585' @ 300-400 ftlhr, ecd's increasing f/11 + ppg to over 12 ppg. Log showed 12.6 ppg when lost circ. While working pipe prior to connection, lost returns. Pull pipe out of hole attempting to gain circ. No extra torque or drag when lost circ. Had just drilled down a stand, then worked stand out of hole. Discussions were underway that PWD readings were climbing or errattic, that a sweep was maybe in order when returns were lost. Stood stand back, made up top drive, apply 300-400 psi while rotating out of hole @ 70-80 rpm torque and drag normal (6-7 k ftllb). No circ. Pull another 3 stands, each time not able to circ. While attmpting to pull 4th stand, torque increased to 12 k, then 17k, drag became 25k over. on 5th stand torque increased to 28k, drag increased to 45k over. Was able to pull out slow to 2950' when hole freed up and circ was possible. Circ regained @ 2950' (shoe @ 2840'). Pump nut plug sweep to clean cutttings from hole. Ream & wash back in hole f/2840' to 3016'. Lost signal on MWD. Attempt to restart MWD. No good. POOH f/ MWD. Monitor hole @ BHA. Continue to POOH f/ MWD failure. PJSM w/ Sperry sun on radioactive sources. Download MWD. Pull to bit, check and grade bit. UD MWD PU/MU MWD, orient same. Trouble with new MWD trying to Upload, change out battery pack, change out cables & plugs. Upload and pulse test. Load radioactive sources. Trip in hole to csg shoe @ 2840'. Service rig and change out swivel packing on top drive. Test swivel packing @ 3500 psi. OK. Wash and ream open hole f/ shoe to TO @ 3585'. Rotary 100 RPM, pumps 400 gpm (136 spm), 5" DP x 81/2" open hole AV = 207 ftlmin, torque 6,000-6,400 ftllb, PU wt 125 k, Rotating wt 100 k, ROP 400-800 Pump hi vis sweep, perform PWD baseline test. MW 9.6 ppg, 400-500 gpm, rotating 80-120 rpm= 10.2 ppg Directional drill 8 1/2" f/3,585' to 4443' (858') TVD @ 3585' = 3901' ART 5.2 hrs AST.5 hrs Drill w/ 10-20 k WOB, 100 RPM, MM 165-173 RPM's, 170-180 SPM, 500-527 GPM, 1900 psi off btm, 2100 psi on bttm, PU wt 145 k, SO wt Printed: 12/9/2002 3:44:26 PM .) ) Page 4 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-18 3S-18 ROT - DRILLING N1268@ppco.com Nabors 7ES Date Sub From - To Hours Code Code Phase 11/28/2002 03:30 - 12:00 12:00 - 00:00 8.50 DRILL DRLG PROD 12.00 DRILL PROD 11/29/2002 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 15:00 3.00 DRILL DRLG PROD 15:00 - 17:00 2.00 DRILL CIRC PROD 17:00 - 20:00 3.00 DRILL TRIP PROD 20:00 - 21 :00 1.00 DRILL CIRC PROD 21 :00 - 22:00 1.00 DRILL FIT PROD 22:00 - 23:00 1.00 RIGMNT RSRV PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 11/30/2002 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 06:30 5.50 DRILL CIRC PROD 06:30 - 08:30 2.00 DRILL CIRC PROD 08:30 - 09:00 0.50 DRILL OTHR PROD 09:00 - 12:00 3.00 DRILL DRLG PROD 12:00 - 13:00 13:00 - 17:00 1.00 RIGMNT RGRP PROD 4.00 DRILL DRLG PROD Start: 11/22/2002 Rig Release: 12/3/2002 Rig Number: Spud Date: 11/23/2002 End: 12/3/2002 Group: Description of Operations 95 k, Rot wt 115 k, torque off bttm 6 k ft/lb, torque on bttm 8 k ft/lb. Directional drill 8 1/2" f/4443' to 5489' (1046') TVD @ 5489' = 4782 ART = 7.5 hrs AST.9 hrs Drill w/10-15 k WOB, 100-110 RPM, MM 173 RPM, 180 SPM, 527 GPM, 1900-2360 psi off bttm, 2100-2700 psi on bttm, PU wt 175 k, SO wt 125 k, Rot wt 133 k, torque off bttm 7-8.5 k ft/lb, torque on bttm 8-9 k ft/lb. Directional drill 8 1/2" hole fl 5489' to 6347' (858') TVD = 5572' AST = 2 hrs ART = 5.35 hrs Drill wi 10-20 k WOB, 100-110 RPM, mm 174 rpm,180 spm, 528 GPM, 2500-2700 psi off bttm, 2750-2900 psi on bttm, PU wt 175-195 k, SO wt 105-115 k, Rot wt 135-145 k, torque off bttm 9,000 ft/lb, torque on bttm 10,000 to 11,000 k ftllb. Directional drill 8 1/2" hole f/6347' to 6520' (173') TVD = 5741' AST = 1.25 hrs ART = 1.25 hrs Drill wi 10-25 k WOB, 80-100 RPM, MM 170 rpm, 175 spm, 513 GPM, 2650-2750 psi off bttm, 2900-3050 psi on bttm, PU wt 200 k, SO wt 120 k, Rot wt 150 k, torque off bttm 9,500 ftllb, torque on bttm, 10,000 ftllb. Pump up survey, circ hi vis sweep around @ 520 GPM & 2700 psi. POOHlshort trip to 2826'. Pulled a little tight @ 6120' (25 k over). Pump out fl 6156' to 6061'. Rest of trip out --hole in good shape. Circulate and condition mud and hole f/ formation integrity test. RU to perform FIT. Pump 36 strokes(2.5 bbls), bleed back .6 bbls after test. Tested to 13 ppg EMW @ 5741' TVD = 15.7 ppg EMW @ 2547' TVD( 9 5/8" Shoe) Service rig and top drive. RIH w/ drilling assembly to 4686'. Hole in good shape. RIH fl 4686' to 6520' after FIT test to continue drilling 8 1/2" hole. Hole in good shape. Circ and condition (10.8 ppg mud) while preparing to weight up to 12.3 ppg. Displace mud in hole to f/1 0.8 ppg to 12.3 ppg. Circ mud till even @ 12.3 ppg. monitoring f/ G/L. Hole OK. Perform PWD baseline test w/12.3 ppg mud. Obtain SPA. 415-500 gpm, 70-90 rpm, 12.83 ppg to 13 ppg Directional drill 8 1/2" hole f/6520' to 6667' (147') TVD = 5877' ART = 1.67 hrs AST = 0.0 hrs Drill w/1 0-20 k WOB, 80 RPM, MM 154 rpm, 160 SPM, 469 gpm, 2250 psi off bttm, 2500 psi on bttm, PU wt 205 k, SO wt 125 k, Rot wt 155 k, torque off bttm 9,500 k ft/lb, torque onbttm 10,500 ft/lb. gas 11-30 units Change out liner and swab on # 2 mud pump. Directional drill 8 1/2" hole f/6667' to 6900' (233') TVD 6118' ART = 3.2 hrs AST = 0.0 hrs Drill w/1 0-20 k WOB, 80 RPM, MM 154 RPM, 160 SPM, 469 gpm, 2350-2400 psi off bttm, 2600-2650 psi on bttm, PU wt 205-210 k, SO wt 130 k, Rot wt 160 k, torque off bttm 9,500 ft/lb,torque on bttm 10,000-11,000 ft/lb. Printed: 12/9/2002 3:44:26 PM ) ) ConocoPhillips Alaska Operations Summary Report Page 5 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-18 3S-18 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 11/22/2002 Rig Release: 12/3/2002 Rig Number: Spud Date: 11/23/2002 End: 12/3/2002 Group: Sub FrOrtl'"To HoUts' Code Code Phase D$$criptionofÇ)ÞØr~tiØI'1~ 11/30/2002 17:00 - 19:00 2.00 DRILL CIRC PROD Pump up survey @ TO. Circ hi vis sweep. Monitor well. Blow down top drive. 19:00 - 20:00 1.00 DRILL TRIP PROD Short trip 10 stands fl TO @ 6900' to 5965'. Hole in good shape. 20:00 - 21:30 1.50 DRILL CIRC PROD Circ after short trip to condition hole fl casing. Monitor well. Pump dry job. 21 :30 - 00:00 2.50 DRILL TRIP PROD Pooh fl 7" casing. SLM. Collect torque and drag data every 5 stands in open hole, every 10 stands in casing. 220 k PU wt off bttm.5.8 bbls over calc wI 45 stands out of hole.Monitor well @ shoe. 12/1/2002 00:00 - 02:00 2.00 DRILL TRIP PROD Continue to POOH f/7" casing. SLM(no correction), Collect torque and drag data. 02:00 - 06:00 4.00 DRILL OTHR PROD Work BHA. Remove source fl LWD tools. Download tools, Break & UD tools. Break bit and lay down MM. Hole fill 6.25 bbls over calc. 06:00 - 06:30 0.50 DRILL OTHR CMPL TN Pull FMC wear bushing. 06:30 - 08:00 1.50 CASE RURD CMPL TN RU casing tools. Change out bails, MU Frank's fillup tool. 08:00 - 12:30 4.50 CASE RUNC CMPL TN PJSM, Run 1" 26#/ft L-80 BTC-M casing to 2822' using frank's fillup tool to fill full every 10 joints. 12:30 - 13:00 0.50 CASE CIRC CMPL TN Circ csg volume at casing shoe. 3 bpm 230 psi. PU wt 100k, down wt 70k. 13:00 - 18:30 5.50 CASE RUNC CMPL TN Continue to run in hole wI 7", 26 #/ft L-80 casing using Frank's fillup tool. Fill full every 10 joints. MU landing joint and land casing @ 6887'. Displacement within 2 bbls. 18:30 - 19:30 1.00 CEMENTCIRC CMPL TN Circulate and recipicate 7" casing wI frank's fillup tool. PU wt start @ 230 k, finish @ 215 k. SO wt 120 k Circ @ 3 bpm with 618 psi starting, finish wI 280 psi. Circ total of 272 bbls.(3892 strokes) 19:30 - 20:30 1.00 CEMENT RURD CMPL TN Rig down frank's fillup tool. RU Schlumberger/Dowell cement head. 20:30 - 22:00 1.50 CEMENTCIRC CMPL TN Circulate and condition mud and hole fl cement job. ATTEMPT TO RECIP 7" CASING, Pull to 250 k, no go. Pull to 265 k, no go. Leave casing hanger on load shoulder of casing head. Increased circulating rate fl 3bpm to final of 5 bpm in stages. At 5bpm = 495 psi. PJSM and batch mix cement while circulating. Circ total of 538 bbls. (7720 strokes) 22:00 - 00:00 2.00 CEMENT PUMP CMPL TN Switch over to Dowell. Pump 5 bbls CW 100 @ 8.3 ppg, test lines to 3500 psi, pump another 5 bbls CW 100 @ 8.3 ppg, drop bttm plug, load another bttm plug and top plug. Pump 50 bbls Mud Push XL @ 13.3 ppg, drop bottom plug, pump 46 bbls (223 sx) class G Gasblok with add's @ 15.8 ppg, flush lines wI seawater to rig floor. Drop top plug and follow wI 8.42 ppg seawater till bump plug @ 264 bbls pumped. CIP @ 2355 hrs 12/1/2002. All pumping @ 5 bpm until cement @ shoe, then pump @ 3 bpm. Full returns. Bump plug wI 2300 psi (500 psi over circ pressure). Bled back 1.8 bbls. Floats held 12/212002 00:00 - 01 :00 1.00 CEMENT PULD CMPL TN Blow down lines. RID Dowell cement head. 01 :00 - 01 :30 0.50 CEMENT OTHR CMPL TN Pump 50 bbls @ 300 gpm of water in stack to flush mud out of pump lines and to keep mud out of 7" casing prior to removing landing joint. 01 :30 - 02:30 1.00 CEMENT PULD CMPL TN UD landing joint. RID casing equip. Clear floor of 7" casing tools. Change bails fl top drive to shorter drilling bails. 02:30 - 04:00 1.50 WELCTL OTHR CMPL TN Install FMC packoff on 7" hanger. Test f/10 min @ 5000 psi. OK. Danny Mossin FMC rep. 04:00 - 05:00 1.00 CMPL TN RURD CMPL TN RU to run 31/2" completion equipment. 05:00 - 05:30 0.50 CMPL TN SFTY CMPL TN PJSM on cutting drilling line. First time wI crew. Printed: 12/9/2002 3:44:26 PM ) ) ConocoPhillips Alaska Operations Summary Report Page 6 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-18 3S-18 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 11/22/2002 Rig Release: 12/3/2002 Rig Number: Spud Date: 11/23/2002 End: 12/3/2002 Group: 12/2/2002 05:30 - 07:00 1.50 CMPL TN OTHR CMPL TN Slip & cut 180' of 1.25" drilling line. Service rig and top drive. 07:00 - 08:00 1.00 CMPL TN SFTY CMPL TN PJSM on running 31/2" completion. 08:00 - 17:30 9.50 CMPL TN RUNT CMPL TN Running 3 1/2" 9.3 #/ft L-80 EUE tbg with jewelry to 6577'. Ran total of 205 joints tubing to packer setting depth. MU torque 2,600 ft/lb. PU wt 90 k SO wt 66 k Blocks and TO weight 26 k 17:30 - 19:30 2.00 CMPL TN OTHR CMPL TN RU to test casing. Test 7" casing to 3500 psi. Chart test and hold f/30 min. bled to 3490 psi. Good test. 19:30 - 21 :00 1.50 CMPL TN CMPL TN Drop 2" ball to set packer. Wil set SAB-3 packer @ 6545'. RU pumping lines. Pressure tubing to set packer. PBR appeared to shear @ 2950 psi. Repressure to 3000 psi. hold 5 min. bleed to 890 psi, PU 4', SO tag wI 10k weight. PU to packer setting depth of 6545'. Pressure tubing to shear ball fl seat. Sheared @ 3700 psi. Bleed off all pressure. RID pumping equip. 21 :00 - 23:00 2.00 CMPL TN CMPL TN Pull joint # 205 and 4' pup joint out of hole. Figure space out. MU hanger on top of joint # 204 in the hole. Land tubing spaced 2' above PBR wI locator. RILDS's. 23:00 - 23:30 0.50 CMPL TN CMPL TN RU pumping lines to test tbg & ann. with ann. open, pressure 31/2" tbg to 3500 psi fl5 min., bleed to 1500 psi. RU to pump into annulus.Pressure 7" x 31/2" annulus to 3500 psi, hold fl5 min.( pressure on tbg increased to 2200), Bleed tbg pressure. RP sheared WI tbg pressure @ 1200 psi. Bleed both sides to zero. 23:30 - 00:00 0.50 CMPL TN CMPL TN RID pumping lines. UD 3 1/2" landing joint. Install two way check. Blow down mud lines. 12/3/2002 00:00 - 02:30 2.50 CMPL TN NUND CMPL TN Nipple down 13 5/8" BOPE. 02:30 - 04:30 2.00 CMPL TN NUND CMPL TN Nipple up WKM, Gen v tree. Orient per FMC rep. Fill tree wI water. 04:30 - 05:30 1.00 CMPLTN OTHR CMPL TN RU and try to test Tree. Two way check leaking. 05:30 - 06:30 1.00 CMPL TN OTHR CMPL TN RID test equip. Pull two way check. Redress two way check (replaced body seal & poppett). 06:30 - 07:00 0.50 CMPL TN SEaT CMPL TN RU. Test tree to 250 psi low & 5000 psi high. Hold fl 10 min. OK. 07:00 - 08:00 1.00 CMPL TN OTHR CMPL TN Perform injectivity test on 9 5/8" x 7" annulus wI 12.3 ppg mud. Leak off @ 477 psi @ 2547'TVD (2840' MD). EMW = 15.9 ppg. Pumped total of 5.6 bbls, bleed back 2 bbls. 08:00 - 11 :00 3.00 CMPL TN FRZP CMPL TN RU fl Lttle Red to freeze protect 3 1/2" tubing and 31/2" x 7" annulus. Little red pump total of 109 bbls diesel down tubing. Tbg cap to shear valve = 56 bbls. 2000' md diesel in ann = 53 bbls. Shut valves. Let diesel in ann migrate to surface. Tubing full of diesel. Circ @ 2BPM, final circ pressure 1100 psi. SITP 250 psi. SICP 0 psi While Little Red pumping on tubing- Rig flushed 9 5/8" x 7" ann wI 250 bbls water @ 3bpm and 850 psi. 11 :00 - 12:00 1.00 CMPL TN FRZP CMPL TN Little Red RU on 9 5/8" x 7" OA. Pressure test to 2000 psi. Pumping diesel @ 1 bpm & initial press 500 psi. Pump 53 bbls diesel to 1875' MD= 1750' TVD. Final circ press 1100 psi. SI OA 700 PSI. 12:00 - 14:00 2.00 CMPL TN OTHR CMPL TN Set BPV with lubricator. 300 psi on tbg. Secure tree. 14:00 - 15:00 1.00 CMPL TN NUND CMPL TN Remove flow riser. Install 20" extension. 15:00 - 18:00 3.00 CMPL TN OTHR CMPL TN Install mousehole. Prep to UD Dp fl derrick. UD 54 joints 5" dp fl derrick, using mouse hole, LD mousehole. Released rig to 3S-09 @ 1800 hrs. Printed: 12/9/2002 3:44:26 PM Date 12/05/02 12/08/02 ) ') 3S-18 Event H ¡story Comment REPLACED SHEARED DCR VALVE @ 6428' RKB WI 1.5" DV. TESTTBG & CSG TO 2500 PSI, GOOD. DRIFT TBG WI 22' X 2.5" DUMMY GUN TO 6788' SLM (BOTTOM PERF 6678'). [TAG, PT TBG-CSG, GLV] PERFORATE INTERVAL = 6642 - 6678 FT MD. 2.5" GUN, CHARGES = 2506 POWERJETS @ 6 SPF, 60 DEG PHASING. RIH AFTER PERFORATING TO OBTAIN SBHP SURVEY - WHP = 1420 PSI AND CLIMBING. MID-PERF AT 6660 FT MD = 3519.4 PSI @ 160.4 DEGF. AT 6460 FT MD = 3432.9 PSI @ 151.1 DEGF. Page 1 of 1 12/9/2002 ) ) ~ca-d(Jto 08-Dec-02 AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-18 Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00 I MD 0.00' M D (if applicable) 6,900.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, R IVED DEC 1 3 2002 William T. Allen Survey Manager Alaska O~ & Gas Cons. Conurunion Anchorage Attachment( s) Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-18 ~ Job No. AKMW22183, Surveyed: 30 November, 2002 Survey Report 6 December, 2002 Your Ref: API 501032043300 Surface Coordinates: 5993878.54 N, 476110.46 E (70023' 39.8584" N, 150011'39.7407" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '~ Surface Coordinates relative to Project H Reference: 993878.54 N, 23889.54 W (Grid) Surface Coordinates relative to Structure: 34.44 N, 344.65 W (True) Kelly Bushing: 56.27ft above Mean Sea Level Elevation relative to Project V Reference: 56. 27ft Elevation relative to Structure: 0.17ft 5p1!!'-''''Y-SUI! DFlILLING 5ERVIt:ES A Halliburton Company Survey Ref: svy10001 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-18 Your Ref: API 501032043300 Job No. AKMW22183, Surveyed: 30 November, 2002 ConocoPhi/lips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -56.27 0.00 O.OON 0.00 E 5993878.54 N 476110.46 E 0.00 MWD Magnetic 192.99 0.620 202.220 136.72 192.99 0.97 S 0.39W 5993877.57 N 476110.06 E 0.321 0.07 285.27 2.460 275.730 228.96 285.23 1.23 S 2.55W 5993877.32 N 476107.90 E 2.558 2.04 378.81 3.430 284.910 322.38 378.65 0.31 S 7.26W 5993878.25 N 476103.20 E 1.150 6.79 467.63 5.040 285.930 410.95 467.22 1.44 N 13.58 W 5993880.03 N 476096.89 E 1.815 13.34 558.49 6.750 290.810 501.33 557.60 4.44 N 22.41 W 5993883.05 N 476088.07 E 1.960 22.66 ~ 648.72 9.040 289.430 590.70 646.97 8.68N 34.05 W 5993887.33 N 476076.44 E 2.546 35.05 740.95 11.420 289.640 681.46 737.73 14.16 N 49.48 W 5993892.86 N 476061.02 E 2.581 51.42 828.84 13.520 286.230 767.27 823.54 19.96 N 67.55 W 5993898.71 N 476042.98 E 2.531 70.39 924.42 16.360 287.910 859.61 915.88 27.22 N 91.09 W 5993906.05 N 476019.46 E 3.005 95.02 1019.71 18.360 287.470 950.56 1006.83 35.85 N 118.17 W 5993914.77 N 475992.40 E 2.103 123.45 1115.35 20.930 289.980 1040.62 1096.89 46.21 N 148.60 W 5993925.23 N 475962.01 E 2.828 155.59 1210.49 22.590 288.460 1128.98 1185.25 57.81 N 181.91 W 5993936.93 N 475928.74 E 1.842 190.86 1306.28 26.230 287.170 1216.19 1272.46 69.89 N 219.60 W 5993949.13 N 475891.09 E 3.840 230.43 1399.16 29.500 287.860 1298.29 1354.56 82.96 N 260.99 W 5993962.34 N 475849.74 E 3.538 273.83 1493.07 31.530 288.030 1379.19 1435.46 97.66 N 306.35 W 5993977.17 N 475804.43 E 2.164 321.51 1587.70 35.040 288.440 1458.29 1514.56 113.91 N 355.66 W 5993993.59 N 475755.16 E 3.717 373.44 1682.68 34.920 287.230 1536.11 1592.38 130.59 N 407.49 W 5994010.43 N 475703.39 E 0.741 427.88 1780.02 34.810 286.930 1615.98 1672.25 146.93 N 460.68 W 5994026.94 N 475650.25 E 0.209 483.51 1875.57 34.200 290.200 1694.72 1750.99 164.15 N 511.98W 5994044.32 N 475599.01 E 2.041 537.62 1969.16 33.820 289.330 1772.31 1828.58 181.85 N 561.24 W 5994062.18 N 475549.80 E 0.660 589.95 2064.03 34.450 290.930 1850.83 1907.10 200.18 N 611.22W 5994080.67 N 475499.88 E 1.156 643.16 2159.35 34.830 289.160 1929.26 1985.53 218.74 N 662.12 W 5994099.40 N 475449.05 E 1.128 697.31 ~ 2255.14 35.670 292.710 2007.49 2063.76 238.51 N 713.73 W 5994119.33 N 475397.50 E 2.311 752.52 2349.69 34.300 293.920 2084.96 2141.23 259.95 N 763.51 W 5994140.93 N 475347.78 E 1.624 806.53 2446.02 33.710 294.050 2164.81 2221.08 281.85 N 812.73 W 5994162.99 N 475298.63 E 0.617 860.15 2541.24 33.910 292.660 2243.93 2300.20 302.85 N 861.37 W 5994184.14 N 475250.06 E 0.839 912.93 2636.91 34.120 289.410 2323.24 2379.51 322.05 N 911.31 W 5994203.50 N 475200.18 E 1.913 966.37 2731.70 34.560 290.220 2401.51 2457.78 340.18 N 961.62 W 5994221.79 N 475149.94 E 0.669 1019.83 2786.43 34.620 289.290 2446.56 2502.83 350.68 N 990.86 W 5994232.39 N 475120.73 E 0.971 1050.89 2851.28 34.890 290.210 2499.84 2556.11 363.17 N 1025.65 W 5994244.99 N 475085.98 E 0.910 1087.84 2947.45 34.530 291.580 2578.90 2635.17 382.70 N 1076.81 W 5994264.68 N 475034.88 E 0.893 1142.55 3041.64 33.740 292.450 2656.86 2713.13 402.51 N 1125.81 W 5994284.64 N 474985.94 E 0.986 1195.30 3136.53 33.260 285.950 2736.01 2792.28 419.73 N 1175.20 W 5994302.02 N 474936.61 E 3.813 1247.60 3229.62 32.500 285.770 2814.19 2870.46 433.54 N 1223.81 W 5994315.99 N 474888.04 E 0.823 1298.08 6 December, 2002 - 15:26 Page 2 of5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-18 Your Ref: API 501032043300 Job No. AKMW22183, Surveyed: 30 November, 2002 ConocoPhitlips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3324.01 31.690 286.4 70 2894.16 2950.43 447.46 N 1271.99 W 5994330.06 N 474839.91 E 0.944 1348.19 341 7. 11 30.510 284.500 2973.88 3030.15 460.31 N 1318.32 W 5994343.06 N 474793.61 E 1.673 1396.22 3515.32 29.850 284.200 3058.77 3115.04 472.55 N 1366.15 W 5994355.45 N 474745.82 E 0.689 1445.47 3611.47 31 .990 285.370 3141.25 3197.52 485.17 N 1413.92 W 5994368.23 N 474698.10 E 2.312 1494.77 3704.26 31.670 285.310 3220.09 3276.36 498.12 N 1461.11 W 5994381.32 N 474650.95 E 0.347 1543.64 512.22 N 1510.01 W ~ 3801.79 31.250 286.880 3303.28 3359.55 5994395.59 N 474602.09 E 0.944 1594.50 3896.92 30.780 285.870 3384.81 3441.08 526.05 N 1557.04 W 5994409.56 N 474555.11 E 0.737 1643.48 3992.82 33.380 285.080 3466.06 3522.33 539.62 N 1606.12 W 5994423.29 N 474506.07 E 2.746 1694.34 4088.89 33.310 286.060 3546.32 3602.59 553.80 N 1656.99 W 5994437.63 N 474455.25 E 0.565 1747.08 4183.56 32.940 285.500 3625.60 3681.87 567.86 N 1706.78 W 5994451.86 N 474405.51 E 0.507 1798.76 4278.01 32.380 286.510 3705.12 3761.39 581.91 N 1755.77 W 5994466.06 N 474356.56 E 0.827 1849.69 4374.08 31.900 286.040 3786.47 3842.74 596.24 N 1804.83 W 5994480.54 N 474307.55 E 0.563 1900.76 4467.76 31.730 285.190 3866.07 3922.34 609.53 N 1852.39 W 5994493.99 N 474260.03 E 0.512 1950.09 4564.18 34.500 286.230 3946.83 4003.10 623.81 N 1903.09 W 5994508.43 N 474209.38 E 2.933 2002.70 4659.55 34.360 286.720 4025.49 4081.76 639.10 N 1954.80 W 5994523.89 N 474157.72 E 0.325 2056.59 4754.36 34.350 286.370 4103.76 4160.03 654.34 N 2006.08 W 5994539.29 N 474106.48 E 0.209 2110.07 4849.95 34.150 286.380 4182.77 4239.04 669.51 N 2057.70 W 5994554.62 N 474054.91 E 0.209 2163.83 4945.12 33.360 286.010 4261.90 4318.17 684.26 N 2108.48 W 5994569.53 N 474004.18 E 0.858 2216.68 5039.17 32.760 285.810 4340.72 4396.99 698.32 N 2157.82 W 5994583.75 N 473954.88 E 0.648 2267.93 5134.95 32.350 285.060 4421.45 4477.72 712.04 N 2207.50 W 5994597.63 N 473905.25 E 0.601 2319.40 5230.56 30.420 286.990 4503.07 4559.34 725.76 N 2255.36 W 5994611.50 N 473857.43 E 2.276 2369.15 5326.22 29.480 288.4 70 4585.96 4642.23 740.29 N 2300.84 W 5994626.18 N 473811.99 E 1.250 2416.90 5418.60 28.590 289.520 4666.73 4723.00 754.88 N 2343.24 W 5994640.91 N 473769.65 E 1.110 2461.73 ~ 5513.90 27.820 288.960 4750.71 4806.98 769.73 N 2385.76 W 5994655.89 N 473727.17 E 0.854 2506.76 5609.70 26.740 288.680 4835.85 4892.12 783.89 N 2427.32 W 5994670.19 N 473685.65 E 1.135 2550.67 5704.57 25.640 294.040 4921.00 4977.27 799.09 N 2466.29 W 5994685.51 N 473646.73 E 2.749 2592.45 5800.14 24.460 294.200 5007.57 5063.84 815.63 N 2503.23 W 5994702.16 N 473609.85 E 1.237 2632.71 5895.19 23.340 293.840 5094.47 5150.74 831.31 N 2538.40 W 5994717.95 N 473574.73 E 1.188 2671.03 5991.47 22.500 294.180 5183.15 5239.42 846.56 N 2572.65 W 5994733.32 N 473540.53 E 0.883 2708.34 6086.36 22.170 294.680 5270.92 5327.19 861.47 N 2605.48 W 5994748.33 N 473507.74 E 0.401 2744.20 6181.28 20.750 293.830 5359.26 5415.53 875.75 N 2637.14 W 5994762.71 N 473476.13 E 1.531 2778.75 6276.90 18.340 291.220 5449.37 5505.64 888.04 N 2666.66 W 5994775.09 N 473446.65 E 2.680 2810.64 6372.68 14.030 287.890 5541.33 5597.60 897.06 N 2691.77 W 5994784.20 N 473421.57 E 4.601 2837.31 6467.21 10.130 285.950 5633.75 5690.02 902.87 N 2710.67 W 5994790.07 N 473402.68 E 4.147 2857.08 6562.04 8.240 286.970 5727.36 5783.63 907.14 N 2725.19 W 5994794.39 N 473388.18 E 2.000 2872.21 6 December, 2002 - 15:26 Page 3 of5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-18 Your Ref: AP/501032043300 Job No. AKMW22183, Surveyed: 30 November, 2002 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) 6655.67 7.950 286.920 5820.06 5876.33 910.99 N 2737.81 W 5994798.27 N 473375.58 E 6751.38 7.670 289.350 5914.88 5971.15 915.03 N 2750.16 W 5994802.35 N 473363.23 E 6830.51 7.350 288.280 5993.33 6049.60 918.37 N 2759.95 W 5994805.72 N 473353.46 E 6900.00 7.350 288.280 6062.25 6118.52 921.15 N 2768.39 W 5994808.54 N 473345.02 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.27' MSL. Northings and Eastings are relative to 2538' FNL, 1149' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2538' FNL, 1149' FEL and calculated along an Azimuth of 288.383° (True). Magnetic Declination at Surface is 25.2700(22-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 6900.00ft., The Bottom Hole Displacement is 2917.62f1., in the Direction of 288.404° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 6900.00 921.15N 2768.39 W 6118.52 Projected Survey 6 December, 2002 - 15:26 Page 4 0'5 ConocoPhi/lips Dogleg Rate (0/100ft) 0.310 2885.39 0.452 2898.39 0.441 2908.73 0.000 2917.62 Projected Survey Vertical Section Comment ~. ~; DrillQuest 3.03.02.004 Western North Slope Survey too/prof/ram for 35-18 From Measured Vertical Depth Depth (ft) (ft) 0.00 6 December, 2002 - 15:26 To Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-18 Your Ref: API 501032043300 Job No. AKMW22183, Surveyed: 30 November, 2002 ConocoPhillíps Survey Tool Description 0.00 6900.00 6118.52 MWD Magnetic ~' ~ Page 50f5 DrillQuest 3.03.02.004 .) . ConocJ>'hillips Randy Thomas Greater Kuparuk Team Leader Drilling & Wells ao~~~cJt, P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas@ppco.com January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re:AnnularDisposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, - . \ "":::> ~ , ,.~'~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison I R. Overstreet Sharon Allsup-Drake Well Files RECE\VED Jò}! 1 5 2003 A \aska Oil & Gas Cons. Commission . ". Anchorôge Annular Disposal during the fourth quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec 2002 3S-09,3S-14,3S~10 3S-18 206 100 0 306 0 0 306 Dec 2002 Dec 2002 3S-18 ( Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze' Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 . 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 Cook Inlet Annular Disposal during the fourth quarter 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October 2002 2002 ... Source Wells Hansen # 1 ') Conoc~hilUps Post Office Box 100360 Anchorage, Alaska 99510-0360 Scott Lowry Phone (907) 265-6869 Fax: (907) 265-1535 Email: scott.l.lowry@Conocophillips.com December 13, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well 3S-18 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that 3S-18 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on 3S-18 by 12/31/2002. Please find attached fonn 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Production Casing Description 7. Production Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View ofl~~~nd Future Planned Adjacent Wells , 10. Details on wetÞC1ne only existing wen within Y. mile of38-18 at the surface casing shoe) ./ If you have any questions or require further information, please contact Scott Lowry at 265-6869, or Randy Thomas at 265-6830. Sincerely, ~Jt~ Scott Lowry Drilling Engineer ) ~~GA- 1212. ^Sf (j Z- p. }"'t.'J/~ ~ tV'-- vI?> IJrtj I <"(2..1- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program - 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2538' FNL, 1149' FEL, Sec. 18, T12N, R8E, UM At top of productive interval 1628' FNL, 3882' FEL, Sec. 18, T12N, R8E, UM At effective depth At total depth 1617' FNL, 3914' FEL, Sec. 18, T12N, R8E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 6900 6118 6798 6017 measured true vertical Length 108' 2813' 6859' Casing Conductor Surface Size 16" 9.625" Production 7" Perforation depth: measured 6642' - 6678' true vertical 5863' - 5898' Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 6577' Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _XX Exploratory Stratigraphic - Service - (asp's: 476110, 5993879) (ASP: 473377, 5994798) (ASP: 473345, 5994808 ) feet feet feet feet Plugs (measured) Junk (measured) Cemented 86 sx Arctic Crete 637 sx AS IllLite, 250 sx LiteCrete 223 sx Class G w/GasBlok Packers & SSSV (type & measured depth) Baker SAB-3 pkr # 6545', No SSSV 13. Attachments Description summary of proposal _XX 14. Estimated date for commencing operation December 31 , 2002 16. If proposal was verbally approved Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (OF or KB feet) RKB 28 7. Unit or Property name Other _XX / Annular Disposal Kuparuk River Unit 8. Well numbe/, 3S-18 9. Permit number / approval number 202-206 I 10. API number 50-103-20433-00 11. Field / Pool Kuparuk River FieldlW est Sak Oil Pool Measured Depth 108' 2841' 6887' True vertical Depth 108' 2548' 6106' RECEIVED DEC 20 2002 Alaska Oil & Gas Gons. Commission Anchorage Detailed operations program 15. Status of well classification as: Oil_XX Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed.~'~ \~ R. Tho~as --I Title: Kuparuk Drilling Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - ~OP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10- RBOMS 8Fl ORIGINAL SIGNED BY M L. DiU Approved by order of the Commission ?, \' I Form 10-403 Rev 06/15/88 . BOP sketch - Gas- Suspended - Questions? Call Scott Lowry 265-6869 \ Z'/("7 (Ð'š Date Prepared by Sharon Allsup-Drake i2<fh) Approval no. ,3CJd- - -~ ý ,;;L ~I"J of '\. ;.\..., l ti-let if di~ f () S It. t. Date 1aP06? Commissioner SUBMIT IN TRIPLICATE ') Annulus Disposal Transmittal Form - Well 35-18 A. Designation of the well or wells to receive drilling wastes: B. The depth to the base of freshwater aquifers and permafrost, if present. 3S-18 No Aquifers / Base Permafrost = +/- 15461 TVD RKB C. A stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the Cement top all that is op~n open annulus and other information sufficient to support is interbedded claystone, siltstone and shale with / a commission finding that the waste will be confined and occasional minor non-hydrocarbon bearing sands. will not come to the surface or contaminate freshwater. D. A list of all publicly recorded wells within one-quarter See attached horizontal plane clearance report and plot mile and all publicly recorded water wells within one mile indicating one well (38-26) within 1/4 mile of the surface of the well to receive drilling waste. casing shoe of 38-18. There are no potable water wells within one mile of 38-18. As of 12/13/02, 3S-07' is the only other well that has been permitted for annular disposal on D8-38. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. G. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: H. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: I. Any additional data required by the Commission to confirm containment of drilling wastes: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 2,129 psi. 8ee attached calculation page. See attached: cementing reports, LOT / FIT reports and casing reports. See attached casing summary sheet and calculation pages. ~ ~ :J :J C/) C/) C/) C/) ~ Q) c. 0- êi5 êi5 '"C '"C (I (I Q) Q) ..s:: ..s:: ïi> ïi> c. a 0 0 It) It) C') C') ,.... + + ~ ~ ïi> ïi> c. a ,.... ,.... ,.... ,.... 0 0 C/) C/) (I (I (!) (!) L.. Well 3S-18 Date 12/6/2002 ~ 9 518" Surface Csg .---------- .--- --.. ---ï-õë-Ë'SC@-Š-79"9' MOl 5063' TVD Z~ 3 1/2"Tb£ L ~ 7" Production Csg ') ) TVD 2575 ft. Assumptions Maximum injection pressure of 1500 psi / Maximum density of the injection fluid is 13.0 ppg Pore pressure at the 9 5/8" casing shoe is .4316 psilft Gas lift gas pressure is 0.11 psilft + 1350 psi header pressure Maximum Pressure at Surface Shoe Max Disposal MW 13.0 ppg 2129 psi / Max Pressure at Surface Shoe = Max Pressure at Surface Shoe Max Press=Max Disposal Press+(Max Disposal MW)(.052)(TVD)-(Fluid Wt. On Backside)(.052)(TVD) (FIT performed on surface casing shoe to 18.1 ppg EMW or 2412 psi) ./' Production CasinQ Size Wt. Grade Pcollapse @ 100% Pcollapse @ 85% Gas Depth (TVD) Gas Gradient Max Disposal Pressure Gas Lift Header Pressure 7.000 In. 26.00 Ibs. L 80 5410 psi 4599 psi 5063 ft. 0.11 ppg 1500 psi 1350 psi 19.0 ppg/ Maximum Mud Weight = (to collapse casing) Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradient)(Gas TVD)+Gas Lift Header Pressure-Max Disposal Press (TVD)(.052) Surface CasinQ Size Wt. Grade Pburst @ 100% Pburst @ 85% Fluid Weight on Backside Max Disposal Pressure 9.625 In. 40.00 Ibs. L 80 5750 psi 4888 psi 8.3 ppg 1500 psi 33.6 ppg / Maximum Mud Weight = (to burst casing) Surface Casing Burst MMW = Pb@85%+(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) ) ') Casing Detail 9 5/8" Surface Casinc¡ ì~.m..~.~~'~~PHILLIPS Alaska, Inc. ~' A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 66 64 Jts Nabors 7ES RKB to Landing Ring 29.58' FMC Gen V Hanger 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Collar 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Shoe Jts 1 to 2 2 Jts TD 12 1/4" Surface Hole 12-1/411 T.D. @ 28551 MD 25591 TVD 9-5/811 Shoe @ 2840' MD 25471 TVD /'~' RUN TOTAL 13 BOWSPRING CENTRALlZERS- 2 on jt.#1 (31 to 51 above Shoe on stop ring and over collar) / 1 on Jt. #2 (On stop ring 51 below Float Collar) 1 per jt on Jt #3 - #12 Total of 84 Jts. On location (Including extra float equip.) Total of 7 Jts. Outside shed (Including extra float equip.) Total of 77 Jts. Inside shed Run Total of 66 Jts. Total of 11 Jts. Left out inside shed Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 130 Dn Wt - 105 Block Wt - 30k Drifted all casing to 8.679" Well: 3S-18 Date: 11/25/2002 LENGTH 29.58 1.27 2723.54 1.46 83.08 1.69 DEPTH TOPS 29.58 30.85 2754.39 2755.85 2838.93 2840.62 2855.00 Supervisor: Mike Thornton / Pete Wilson ) ConocoPhillips Alaska Cementing Report Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,840 (ft) 11/25/2002 Surface Casing 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ') Page 1 of 3 Report #: 8tart: Spud Date: 11/23/2002 1 Report Date: 11/25/2002 11/22/2002 End: 12/3/2002 Cement Job Type: Primary Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cementer: Jerry Culpepper Squeeze Open Hole Hole Size: SO TMD: (ft) SO Date: SO Type: Cmtd. Csg: Pipe Movement Pipe Movement: Rot Time Start:: Time End:: RPM: Rec Time Start:07:00 Time End: 10:30 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 130 (Ibs) Type: Cement Casing Volume Excess %: 350.00 Meas. From: 308 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 281 (gpm) Mud Circ Press: 300 (psi) Stage No: 1 of 1 Start Mix Cmt: 10:00 Start Slurry Displ: 10:30 Start Displ: 12:00 End Pumping: 12:25 End Pump Date: 11/25/2002 Top Plug: Y Bottom Plug: Y Type: Spud Mud Density: 9.3 (ppg) Visc: 60 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) Y 375 (psi) 1,000 (psi) 2 (min) Y Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Mud Data Max Torque: (ft-Ibf) Drag Down: 105 (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 308.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: PVNP: 22 (cp)/24 (lb/100ft2) Gels 10 sec: 14 (lb/100ft2) Gels 10 min: 22 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 208.00 (bbl) To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.40 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 12/13/2002 2:51 :09 PM Legal Well Name: 3S-18 Common Well Name: 3S-18 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Trade Name 079 S001 046 D65 0124 053 044 ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Report #: Start: Spud Date: 11/23/2002 1 Report Date: 11/25/2002 11/22/2002 End: 12/3/2002 Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 4 Description: ARCTIC SET Class: G To: 1,681.00 (ft) Cmt Vol: 486.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft31sk) Slurry Vol:637 (sk) Water Vol: 295.7 (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Stage No: 1 Slurry No: 3 of 4 - Additives Type Concentration Liquid Cone. Units 1.50 %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.10 %BWOC 30.00 %BWOC Stage No: 1 Slurry No: 40f4 Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 2,840.00 (ft)To: 1,681.00 (ft) Cmt Vol: 99.7 (bbl) Water Source: Slurry Vol:250 (sk) Test Data Thickening Time: 4.41 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Class: G Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 44.3 (bbl) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Units 9.00 %BWOW Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 12/13/2002 2:51:09 PM ') ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 3S-18 Common Well Name: 3S-18 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/23/2002 1 Report Date: 11/25/2002 11/22/2002 End: 12/3/2002 Stage No: 1 Slurry No: 4 of 4 . Additives Trade Name Type Concentration Units Liquid Conc. Units 079 046 0124 065 0164 0.50 %BWOC 0.60 %BWOC 29.54 %BWOC 1.00 %BWOC 16.63 %BWOC Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 60, YP from 48 to 24, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg RU Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lines to 3,000 Psi, Pumped 45 bbls CW 100 Chern Wash at 8.3 ppg, 7 Bpm @ 200 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 6.8 bpm @ 200 Psi with Red Dye in Spacer, Mixed & Pumped 486 bbls, 637 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.5 bpm @ 200 Psi, Reciprocated Pipe until Mudpush at Shoe, then Pipe got Tight.Landed Pipe, Did Not Observe Nut Plug or Red Dye Markers at Shaker, Pumped Lead Cmt until Cmt to Surface-100 bbls Late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield, Pumped @ 7 Bpm @ 350 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 188.7 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 630 Psi, Slowed to 3 bpm @ 375 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 308 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 12:25 Hrs 11/25/02 Printed: 12/13/2002 2:51:09 PM .) ) Page 1 of 2 ConocoPhillips, Alaska Daily Drilling Report 3S-18 SUPERVISOR I RIG NAME & NO. Mike Thornton/Peter Wi Is N1268@ppco.co CURRENT STATUS Fin Testing BOP's, Prep to PU 81/2" Dir BHA 24 HR FORECAST TIH, Circ & Test Csg, Drill Fit Equip & 20' Perf LOT, Drill LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 11/24/2002 2,786.43 34.620 289.290 9.625 (in) @ 2,840.0 (ft) DENSITY(ppg) I 9.30 'PP I IECDI IMUD DATAl DAILY COST I FV PVNP GELS WUHTHP Fcrr.SOL OIUWAT 'YoSandlMBT Ph/pM 60 22/24 14/22 6.6/ 2/ /22.5 8.5/ I JOB NUMBER I EVE~DC~DE 124 HRS PROG I FIELD NAME I OCS NO. Nabors 7ES Kuparuk River ACCIDENTS LAST 24 HRS.? TMD I TVD I DFS 2,855.0 2,559.0 3.00 AUTH MD I DAILY TANG 6,879.0 0.00 DAILY INTW/O MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 11/25/2002 318,620 I LEAKOFF AFE WCDK3S.0080.01 I NEXT CASING 7.000 (in) @ 6,879.0 (ft) 0.00 I CUM COST I 0.00 PflMf CI Ca H2S LIME ES / I REPT NO. I DATE 4 11/25/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 629,358 WELL NAME AUTH. 2,069,102 LAST BOP PRES TEST OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01 :30 1.50 CASE P RURD SURFAC Fin RU to Run 9 5/8" Csg, Made Dummy Run with Hanger & Landing Jt & Ck Ok. 01 :30 06:00 4.50 CASE P RUNC SURFAC Held Safety Mtg on Running of 9 5/8'~ Csg, MU 9 5/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 64 Jts of 9 5/8" Csg, (Total of 66 Jts Ran 2,840.62' ) While TIH Started taking Wt at 1,709", Est Circ and Washed from 1,709' to 1,751', Cont TIH with no Problems, Landed Csg in Head - Landed Csg w/ FS @ 2,840', FC @ 2,754'. 06:00 07:00 1.00 CASE P RURD SURFAC RD Fill-Up tool & MU Cement Head 07:00 10:30 3.50 CASE P CIRC SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 60, YP from 48 to 24, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg 10:30 12:00 1.50 CEMENT P PUMP SURFAC RU Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lines to 3,000 Psi, Pumped 45 bbls CW 100 Chem Wash at 8.3 ppg, 7 Bpm @ 200 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 6.8 bpm @ 200 Psi with Red Dye in Spacer, Mixed & Pumped 486 bbls, 637 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.5 bpm @ 200 Psi, Reciprocated Pipe until Mudpush at Shoe, then Pipe got Tight-Landed Pipe, Did Not Observe Nut Plug or Red Dye Markers at Shaker, Pumped Lead Cmt until Cmt to Surface-100 bbls Late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield,Pumped @ 7 Bpm @ 350 Psi, 12:00 12:30 0.50 CEMENT P DISP SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 188.7 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 630 Psi, Slowed to 3 bpm @ 375 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eft on Rig Pumps, Had 308 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 12:25 Hrs 11/25/02 12:30 15:00 2.50 CEMENT P RURD SURFAC RD Cmt Head, LD Landing JT & RD Csg Equipment, Cleared Rig Floor 15:00 16:00 1.00 CEMENT P OTHR SURFAC Flushed Out Stack with Jetting Tool 16:00 19:00 3.00 WELCTL P NUND SURFAC NO 21 1/4" Divertor & 16" Divertor Line 19:00 20:00 1.00 WELCTL P NUND SURFAC Installed FMC Gen V 11" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead 20:00 23:30 3.50 WELCTL P NUND SURFAC NU 135/8" 5M BOP Stack 23:30 00:00 0.50 WELCTL P BOPE SURFAC RU to test BOP's Printed: 12/13/2002 2:50:10 PM -) WELL NAME ConocoPhillips, Alaska Daily Drilling Report ¡JOB NUMBER IEVE~Dc~DE [24HRS PROG IT;~855.0 3S-18 --) Page 2 of 2 I TVD I DFS [ REPT NO. I DATE 2,559.0 3.00 4 11/25/2002 24 HR SUMMARY: Ran 9 5/8" Csg to 2,840', Circ & Cond Mud, Cmt'd Csg with 308 bbls of 10.7# Cmt to Surface, Bumped Plugs & Floats Held, NO Divertor, NU Gen V Wellhead & Tested, NU 135/8" 5M BOP's, RU to Test BOP COMPANY ConocoPhillips Nabors Doyon Universal Sperry Sun PERSONNEL DATA NO. HOURS COMPANY 2 Baroid 34 CanRig 6 APC 4 SERVICE ITEM UNITS gals bbls MATERIALS I CONSUMPTION ON HAND ITEM 22,925 Water, Potable 421 Fuel Water, Drilling USAGE 1,291 1,266 SERVICE UNITS gals USAGE 5,590 NO. 2 1 2 HOURS ON HAND 15,210 Printed: 12/13/2002 2:50:10 PM .PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: 38-18 I Rig: Nabors 7E8 I Date: 11/26/2002 I Volume Input Drilling Supervisor: Mike Thornton/Granville Rizek Pump used: I #1 Mud Pump I... II S k ---'---- tro es ... 0.0706 Bbls/Strk ... Type of Test: I Casing Shoe Test LOT/FIT ... Pumping down annulus and DP. ... Casing Test Pressure Integrity Test Hole Size: 18-1/2" I... - Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 27.0 Ft 2,840 Ft-MD 2,547 Ft-TVD 2,875 Ft-MD 2,575 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 19-5/8" 40#/Ft L-80 BTC I... 0 0 0 2650 0 0 0 1140 Casing Test Pressure IntegritvTest 7 316 1 2650 2 0 0.25 1140 Mud Weight: 9.5 ppg Mud Weight: 9.5 ppg 14 700 2 2650 4 36 0.5 1130 Mud 10 min Gel: 4.0 Lb/100 Ft2 Mud 10 min Gel: 4.0 Lb/100 Ft2 21 966 3 2630 6 125 1 1120 Test Pressure: 2,500 psi Rotating Weight: 98,000 Lbs 28 1340 4 2630 8 240 1.5 110' J Rotating Weight: 98,000 Lbs Blocks/Top Drive Weight: 25,000 Lbs 35 1797 5 2630 10 377 2 108ò-" Blocks/Top Drive Weight: 25,000 Lbs Desired PIT EMW: 18.0 ppg 42 2357 6 2630 12 518 2.5 1050 Estimates for Test: 1.7 bbls Estimates for Test: 1126 psi 0.8 bbls 45 2650 7 2630 14 644 3 1040 I... I... 8 2630 16 738 3.5 1020 EMW = Leak-off Pressure + Mud Weight = 1140 + 95 PIT 15 Second 9 2630 18 816 4 1010 0.052 x TVD 0.052 x 2547' Shut-in Pressure, psi 10 2620 20 900 4.5 1010 EMWat2840Ft-MD(2547Ft-TVD)= 18.1 ppg 1140 15 2620 22 983 5 1010 20 2620 24 1055 5.5 1005 25 2620 26 1140 6 1000 30 2620 6.5 990 7 980 7.5 980 8 970 8.5 970 9 950 9.5 950 1 0 9~, '~ 3000.. lliost 30 psi during test, held 98.9% of test pressure. 'WH\t 2500 - ... / 2000 - UJ c:::: ~ ~ 1 500 . UJ c:::: c... 1 000 - 500 . 0 0 2 Barrels 4 0 10 20 15 25 30 Shut-In time, Minutes 0 PIT Point ~CASING TEST -8-LEAK-OFF TEST Comments: Changed hole over to 9.5 ppg new LSND mud prior to FIT. Volume/Stroke Pump Rate: 8.0 Strk/min .. Volume Bled Back 3.2 Bbls Volume Pumped 1.8 Bbls Volume Bled Back 1.8 Bbls ConocoPhillips Alaska Jt Number Num of Jts Jts 3 to 161 Jts 1 to 2 Remarks: 159 Jts 2 Jts Up Wt = 215k ') ') Casing Detail 7" Intermediate Casina COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LOS FMC 11" X 7" Hanger r 26# L-80 BTCM Csg pup joint (on hanger) 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Collar r 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe TD of 8-1/2" hole @ 6900' MD 6118' TVD 7" Shoe @ 6887' MD 6105' TVD Total Centralizers 1- 7" Bowspring centralizer over stop rings center of joints # 1 & #2 Bowspring centralizer over collar on joints #3 thru #20 (Total of 20) 7" x 8-3/8" Centering guide on every jt. From #96 thru #100 (Total of 5) 7" x 8-3/8" Centering guide on every third jt. From #148 to #160 (Total of 5) Total of 170 jts.in pipe shed I Total jts on location 183 Total of 161 jts. Ran in hole Total of 9 jts. Out (9 jts. Inside shed & 13 jts. Outside shed) Use Jet Lube "Run-N-Seal" pipe dope Drifted all casing to 6.151 II On Wt = 120k Block Wt= 30k Well: 38-18 Date: 12/1/2002 LENGTH 26.98 .73 1.47 6768.83 1.35 86.33 1.40 DEPTH TOPS 26.98 27.71 29.18 6798.01 6799.36 6885.69 6887.09 Supervisor: Mike Thornton /Granville Rizek ) ) ConocoPhillips Alaska Cementing Report Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 6,887 (ft) 12/1/2002 Production Casing 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Page 1 of 3 Report #: Start: Spud Date: 11/23/2002 2 Report Date: 12/1/2002 11/22/2002 End: 12/3/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: SO Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cementer: Jerry Culpepper Cmtd. Csg: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Pipe Movement Rot Time Start: : Time End:: RPM: Init Torque: (ft-Ibf) Rec Time Start:18:30 Time End: 20:30 SPM: 42 Stroke Length: 15.0 (ft) Type: Cement Casing Volume Excess %: 0.75 Meas. From: none Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 435 (psi) Avg Torque: (ft-Ibf) Drag Up: 215 (Ibs) Stage No: 1 of 1 Start Mix Cmt: 21 :00 Start Slurry Displ: 22:01 Start Displ: 22:41 End Pumping: 23:55 End Pump Date: 12/1/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 5.00 (bbl/min) Y 1,800 (psi) 2,300 (psi) 5 (min) Y (ft) (ft) Max Torque: (ft-Ibf) Drag Down: 120 (lbs) Returns: FULL Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch Density Meas By: Densometer Type: Non-Disp. LS Density: 12.3 (ppg) Visc: 46 (s/qt) PV/yP: 17 (cp)/20 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Circulating Temperature:114 (OF) Bottom Hole Static Temperature: 143 (OF) Displacement Fluid Type:Seawater Density: 9.4 (ppg) Volume: 264.00 (bbl) Mud Data StâgeNo:1Slurry Nö:1()f3 Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 3,193.00 (ft}To: 3,635.00 (ft) Cmt Vol: (bbl) Water Source: Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.40 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 12/13/2002 2:51:19 PM .') ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Legal Well Name: 38-18 Common Well Name: 38-18 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/23/2002 2 Report Date: 12/1/2002 11/22/2002 End: 12/3/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 3,635.00 (ftJTo: 5,848.00 (ft) Cmt Vol: (bbl) Density: 13.30 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: TAIL Description: Gasblok Slurry Interval: 6,887.00 (ftJTo: 5,848.00 (ft) Cmt Vol: 46.0 (bbl) Water Source: Slurry Vol:223 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 31.0 (bbl) Other Vol: 0 Purpose: ZONAL ISOL Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: 3.70 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) 0-65 D600G 0-47 Type DISPERSANT Gasblok DEFOAMER Concentration ~tag~ NC):., 1 , Slurry Nø:3,Qf3-AdditiVØ$ Units 0.30 %BWOC 2.00G P S 0.20G P S Printed: 12/13/2002 2:51:19 PM ) ) ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 3S-18 Common Well Name: 3S-18 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/23/2002 2 Report Date: 12/1/2002 11/22/2002 End: 12/3/2002 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: CetRun: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 223 sxs (46 bbls) @ 15.8 ppg GasBLOK wI Class G + .300%BWOC D65, 2.000 gallsk D600G, .200 gallsk 047, Pump 5 bbls CW100, Test lines to 3500 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 46 bbls cmt at rate of 5.0 bpm at 390 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 217 bbls seawater at rate of 5 bpm at 1050 psi until cmt around shoe, Slowed rate to 3.0 bpm @ 1600 psi & bumped plug wI total of 264.0 bbls, Bumped plug wI 2300 psi, Bled back 1.8 bbls for a total of 262.2 total bbls displaced, CIP @ 2355 hrs 12/1/02, Had good circ. thru out job, (Note; Calculated displacement to float collar =260.3 bbls, Displacement to Shoe= 263.7 bbls, Displacement around shoe & 1/2 annular volume to base of Kuparuk C =265.9 bbls, Displaced entire job with Dowell. Casing stuck prior to start of cement job. Printed: 12/13/2002 2:51:19 PM ') '> Page 1 of 2 ConocoPhillips, Alaska Daily Drilling Report WELL NAME 3S-18 I JOB NUMBER I EVE~DC~DE 124 HRS PROG T~~900.0 I T~~ 118.0 I DFS9.00 I REPT 1N~. I ~~~/2002 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANG Mike Thornton/G. Rizek N1268@ppco.co Nabors 7ES Kuparuk River 6,879.0 0.00 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD Slip & Cut 180+' drilling line 0.00 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD UD cement equip, install packoff, RU & Run 3 1/2"compl, N/D 11/29/2002 208,607 1,463,296 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOF~ 2.49 AFEWCDK3S.0080.01 AUTH. 2,069,102 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 11/30/2002 6,830.51 7.350 288.280 9.625 (in) @ 2,840.0 (ft) 7.000 (in) @ 6,879.0 (ft) 11/26/2002 DE NSITY(ppg) I 12.30 I PP I IECDI IMUD DATAl DAILY COST I 0.00 I CUM COST I 0.00 FV PVNP GELS WUHTHP FCIT.SOL OIUWAT %SandIMBT Ph/pM Pf/Mf CI Ca H2S LIME ES 46 17/20 4n 4.0/10.0 / / /12.5 9.0/ BHANO. I 3 BHA WT. BELOW JARS STRING WT. UP BHA I HOLE CONDITIONS STRING WT. DN STRING WT. ROT TORQUE I UNITS ft-Ibf I BIT NO. I 3 BHA LENGTH 921.63 CONN SIZE CONN TYPE ITEM IJESCRIPl'ION NOJTS 1 1 1 1 1 1 1 1 1 1 9 1 14 Bit Mud Motor Sub - Float Stabilizer LWD Nukes Drill Collar - Hang Off Jt .Flex Joint - Non Mag Flex Joint - NonMag Flex Joint - NonMag Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt LENGTH 0.96 25.18 2.15 5.59 37.43 23.79 9.97 29.66 29.98 30.78 272.23 31.71 422.20 O~D~ 8.500 6.875 6.625 6.750 6.750 6.750 6.750 6.500 6.500 6.500 5.000 6.250 5.000 2.850 4.753 2.500 2.813 2.900 2.900 2.900 2.813 2.813 2.813 3.000 2.750 3.000 BITS SERIAL NO: JETSORTFA 0325531 13/13/13/12/12/ DEPTH IN DATE IN ;oO~~L~B;G..O~R 3,585.0 11/27/2002 1-1-BT-N-D-I-NO-TD BIT OPERATIØNS PRESS P BIT HRS 2,900 670 24Hr DIST 24HrROP CUM HRS CUMDEPTH CUMROP 72.81 28.82 3,315.0 115.02 OPERATIONS SUMMARY FROM TO HOURS CODE ¡TROUBLE SUB PHASE DESCRIPTION 00:00 02:00 2.00 DRILL P TRIP PROD Continue to POOH f/7" casing. SLM(no correction), Collect torque and drag data. 02:00 06:00 4.00 DRILL P OTHR PROD Work BHA. Remove source f/ LWD tools. Download tools, Break & UD tools. Break bit and lay down MM. Hole fill 6.25 bbls over calc. 06:00 06:30 0.50 DRILL P OTHR CMPL TN Pull FMC wear bushing. 06:30 08:00 1.50 CASE P RURD CMPL TN RU casing tools. Change out bails, MU Frank's fillup tool. 08:00 12:30 4.50 CASE P RUNC CMPL TN PJSM, Run 7" 26#/ft L-80 BTC-M casing to 2822' using frank's fillup tool to fill full every 10 joints. 12:30 13:00 0.50 CASE P CIRC CMPL TN Circ csg volume at casing shoe. 3 bpm 230 psi. PU wt 100k, down wt 70k. 13:00 18:30 5.50 CASE P RUNC CMPL TN Continue to run in hole wI 7" , 26 #/ft L-80 casing using Frank's fillup tool. Fill Printed: 12/13/2002 2:52:37 PM ConocoPhillips, Alaska Daily Drilling Report JOBNUMBER IEVE~Dc~DE 124HRSPROG IT~~900.0 ) / WELL. NAME 3S-18 FROM TO HOURS CODE TROUBLE SUB 13:00 18:30 5.50 CASE P RUNC 18:30 19:30 1.00 CEMENT P CIRC 19:30 20:30 1.00 CEMENT P 20:30 22:00 1.50 CEMENT P RURD CIRC 22:00 00:00 2.00 CEMENT P PUMP ) Page 2 of 2 I TVD I DFS I REPT NO. I DATE 6,118.0 9.00 10 12/1/2002 OPERATIONS SUMMARY PHASE DESCRIPTION CMPL TN full every 10 joints. MU landing joint and land casing @ 6887'. Displacement within 2 bbls. CMPL TN Circulate and recipicate 7" casing wI frank's fillup tool. PU wt start @ 230 k, finish @ 215 k. SO wt 120 k Circ @ 3 bpm with 618 psi starting, finish wI 280 psi. Circ total of 272 bbls.(3892 strokes) CMPL TN Rig down frank's fillup tool. RU Schlumberger/Dowell cement head. CMPL TN Circulate and condition mud and hole fl cement job. ATTEMPT TO RECIP 7" CASING, Pull to 250 k, no go. Pull to 265 k, no go. Leave casing hanger on load shoulder of casing head. Increased circulating rate fl 3bpm to final of 5 bpm in stages. At 5bpm = 495 psi. PJSM and batch mix cement while circulating. Circ total of 538 bbls. (7720 strokes) CMPL TN Switch over to Dowell. Pump 5 bbls CW 100 @ 8.3 ppg, test lines to 3500 psi, pump another 5 bbls CW 100 @ 8.3 ppg, drop bttm plug, load another bttm plug and top plug. Pump 50 bbls Mud Push XL @ 13.3 ppg, drop bottom plug, pump 46 bbls (223 sx) class G Gasblok with add's @ 15.8 ppg, flush lines wI seawater to rig floor. Drop top plug and follow wI 8.42 ppg seawater till bump plug @ 264 bbls pumped. CIP @ 2355 hrs 12/1/2002. All pumping @ 5 bpm until cement @ shoe, then pump @ 3 bpm. Full returns. Bump plug wI 2300 psi (500 psi over circ pressure). Bled back 1.8 bbls. Floats held 24 HR SUMMARY: POOH f/7" casing, Download MWD/LWD tools, UD BHA, pull WB, RU & Run 7" 26 #/ft L-80 csg to 6887',Circ prior to cement job, cement 7" casing. COMPANY ConocoPhillips Nabors Doyon Universal Sperry Sun SERVICE UNITS gals bbls USAGE 2,793 373 Fuel Water, Drilling PERSONNEL DATA NO. HOURS COMPANY 2 Baroid 30 CanRig 6 APC 4 SERVICE NO. 2 1 2 HOURS MA TERIALSICONSUMPTION ON HAND ITEM 6,583 Water, Potable 561 Fuel (camp) UNITS gals gals USAGE 4,950 403 ON HAND 14,850 -2,173 RESERVOIR NAME 1 R-18 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 290 0 COMMENTS 3S-18 Printed: 12/13/2002 2:52:37 PM Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" I. ~ Casing Shoe Depth RKB-CHF: 27.0 Ft 2,840 Ft-MD 2,547 Ft-TVD Casing Size and Description: 19-5/811 40#jFt L-80 BTC Changes for Annular AdeQuacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Well Name: Drilling Supervisor: 3S-18 I Rig: Granville Rizek PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 12/3/2002 I Volume Input Volume/Stroke Pump used: I #1 Mud Pump I"" Strokes'" 0.0698 Bbls/Strk ... ... Pumping down annulus. ... Casing Test Hole Depth Pum ing Shut-in 5,848 Ft-MD 5,107 Ft-TVD Strks si Min si I'" Pressure IntegritvTest Mud Weight: 12.3 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 15.7 ppg 450 psi 0.2 bbls 1.1 I. EMW = Leak-off Pressure + Mud Weight = 477 + 123 0.052 x TVD 0.052 x 2547 . EMW at 2840 Ft-MD (2547 Ft-TVD) = 15.9 1000 .. uJ c:::: :J ~ 500 - uJ c:::: (l. 0 0 4 Barrels "'-CASING TEST -"LEAK-OFF TEST 9 5/8" csg shoe tested to 15.7 ppg EMW with 10.8 ppg mud in hole (654 psi) Comments: PIT 15 Second Shut-in Pressure, psi 280 ~ { I t 6 7 10 0 5 15 20 25 Shut-In time, Minutes 0 PIT Point 30 Volume Volume Pumped Bled Back 0.0 Bbls -'Bbls Pump Rate: 8.0 Strk/min ... Pressure Integrity Test Pumping Shut-in Strks psi Min psi 0 0 0 360 4 25 0.25 280 8 90 0.5 250 12 120 1 220 16 200 1.5 22 20 275 2 21()-~Ø 24 350 2.5 205 28 425 3 200 32 480 3.5 200 36 490 4 200 40 490 4.5 195 44 460 5 195 48 425 5.5 195 52 410 6 190 56 410 6.5 190 60 400 7 190 64 390 7.5 190 68 380 8 190 72 375 8.5 185 76 360 9 185 80 360 9.5 18f. 84 10 1 ' 88 '~ 92 Volume Pumped 6.4 --ebls Volume Bled Back 2.0 Bbls Name +N/-S WELL DETAILS +E/.W Northing &sting 476110.46 70'23'39.858N 150'll'39.74IW N/A ~,~ $Jt ~~:¥VD 0.000 3S.18 34.458 -344.684 5993878.54 -1333 -1250 -1000 -750 -500 -250 -0 -250 -500 -750 -1000 -1250 -1333 -~_-... /;lan: øS-19 (Plan 3S-19F) ~~; 38-19 (PI"" 3S-19) ANTI-COLLISION SETTINGS COMPANY DETAILS WELLPATHDETAlLS 38-18 501032043300 Latitude Phillips Alaska Inc. En~=g CalcuJation Method: Minimum Curvature ~:~~ ~;:~~Plan. Error Surface: Elliptical + Casing Warning Method: Rill.. Based, 0.000 Longitude Slot Interpolation Method:1VD Interval: 5.000 Depth Range From: 2555.000 To: 2565.000 Maximtnn Range: 1320.000 Reference: Definitive Survey Rig: Ref. Datum: N7ES 3S.18: 56.270ft V.Section Angle 288.38' 0 0.000 J:~JJ 270. _/ 90 125u 1~-'I'~,la,n,.-:-20 (plan: 3S-20) 180 ~ 1/4 Mile Radius of 3S-18... 9-5/8" Csg Pt (@ 2855' MD / 2559' TVD) Reference Azimuth Angle [deg] vs Centre to Centre Separation [500ft/in] PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY T(~:~ II ;ä, 'PALM 1A API: 501032036101 OD:3500, r . .. SSSV Type: NIPPLE ID 2 992) - . P .. Annular Fluid: Reference Log: Last Tag: Last Tag Date: CasinsJ' String . ALL STRINGS" Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing. String ;;TUBING . Size I Top 3.500 0 Perfotâtions SUmmäry, .' . Interval I TVD 9047-9137 5811 -5845 Gås Lift: MandrelsNalVes , St MD TVD Man Man Mfr Type 1 2514 2513 CAMCO KBMM-2 2 3995 3784 CAMCO KBMM-2 3 6194 4675 CAMCO KBMM-2 4 7764 5307 CAMCO KBMM-2 5 8777 5710 CAMCO KBMM-2 Production MandrelslValves . St MD TVD Man Man Mfr Type 6 8934 5769 CAMCO KBUG 7 8961 5779 CAMCO KBUG Other (;Iugs~ equip., etc.:.JEWELRY Depth TVD Type 506 506 NIP 8819 5726 SLEEVE-C 8859 5741 SEAL 8860 5741 PBR 8881 5749 PKR 8987 5789 NIP .. 8987 5789 PLUG 8999 5793 XO 9000 5794 TBG 9002 5794 GUN ~ODUCTION (0-9389, OD:7,000, Wt-%M\ .', :'~- ,~" I,.~ J.II.. ":i~ , '- r ' JI:,~,:, ~,"'.,. :r 1';:'.".1. I;"J ,"'\;.' " ~~.~ ,..' «".. - : ' r I II"~::" ~ ¡ t "_l,':'~" J :~~, t,i¡~.j:~iJ,f , r it) :~~ ~,-~." "', ~.~ , 1- )It ~:. -..i'- ') ') KRU 38-26 Well Type: TH Orig Completion: Last W/O: Ref Log Date: TO: 9400 ftKB Max Hole Angle: 68 deg ~ 8935 Angle @ TS: 68 deg @ 9044 Angle @ TD: 68 deg @ 9400 Rev Reason: New Well by ImO Last Update: 4/11/2002 Top 0 0 0 TVD Wt Grade Thread 115 65.50 WELD 2615 36.00 J-55 BTCM 5941 26.00 J-55 BTCM ", ':" Bottom 115 2616 9389 Bottom 9005 Wt I Grade l 9.30 L-80 . ,.' Thread 8rdMOO TVD 5796 , . . . ' ..". . '. . . .., '. .' . .. ...' I Zone I Status 1Ft SPF Date I Type I Comment C-4 90 5 3/13/2001 PERF 45/8" Scallop guns .' '"",' ':"' . . . ',. -: .". V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BEK 0.000 0 3/21/2001 DMY 1.0 BK5 0.000 0 3/13/2001 OMY 1.0 BK5 0.000 0 3/13/2001 DMY 1.0 BK5 0.000 0 3/13/2001 OMY 1.0 BK5 0.000 0 3/13/2001 VMfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK5 0.000 0 3/13/2001 DMY 1.0 BK5 0.000 0 3/13/2001 Description CAMCO 'OS' NIPPLE 2.875 NO GO BAKER COMMINGLING SLEEVE W/2.813 'OS' PROFILE, closed 4/20/01 BAKER SEAL ASSEMBLY BAKER POLISHED BORE RECEPTACLE W/12' SEAL TRAVEL BAKER SAB-3 PACKER PINNER FOR 1500 PSI SHEAR HOWCO 'XN' NIPPLE W/2.75" NO GO, 2.813" BORE SET XXN PLUG 4/20/2001 XO 3.5" TO 2 7/8" ID 2.875 2.812 2.992 3.000 3.250 2.750 0.000 2.440 2.441 0.000 HOWCO 4 5/8" Scallop Guns, 5 spfw/27' of stirn sleeves; tubing auto release & spaces 3'x15' GeneråfNöte.s ' " '. . , . . Date I Note 4/11/2002 This well is a Kuparuk well, pad 3S; pdf included with CPF3 schematics ) Casing Detail 9-5/8" surface casing PHilLIPS Alaska, Inc. COMPLETE DESCRIPTION OF EQUIPMENT RUN Nabors 19E RKB to GLE = 34.85 9 5/8" Landing Joint ( Above RKB) 95/8" Landing Joint (34.85' Below RKB) 9 5/8" FMC GEN V FLUTED MANDREL HANGER W / 40# Pup jt. jts.40-63 9 5/8", 36#, J-55 BTC (24 jts) 9 5/8", 40# TAM Port Collar jts 3-39 9 5/8", 36#, J-55 BTC (38 jts) Gemeco Float Collar jts 1-2 95/8", 36#, J-55 BTC (2 jts) Gemeco Float Shoe # ITEMS BTM OF SHOE @ TD of 12.2511 hole = 2633' MD/2622' ND, rat hole = 16.95' 38 Gemeco Bow Spring Centralizers Run on stop collars in center of jts. 1, 2, 39,40 Run over collars on Jts.3-12, 14, 16, 18, 20, 22, 24, 26, 28, 30, 32 34,36,38,42,44,46,48,50,52,54,56,58,60,62 ). WELL: Palm # 1 DATE: 2/3/01 1 OF 1 PAGES LENGTH DEPTH TOPS 6.02 -6.02 34.85 2.80 34.85 981.62 37.65 2.95 1019.27 1506.65 1 022.22 1.45 2528.87 84.01 2530.32 1.72 2614.33 2616.05 Remarks: String Weights with Blocks: 700k Up, 85k On, ??k Blocks. Ran 63 joints of casing. Drifted casing with 8.765" plastic rabbit.. Used National Lead Free Modified thread compound on all connections. Nabors 79E Drilling Supervisor: R.Morrisonj D. Simonton )! Phillips Alaska Drilling I Well Name: Palm 11 Rig Name: Nabors 19E Casing Size 2, 9.1)5 ' ¿. Centralizers tp Comments: See Casing Detail for Placement Mud Comments: Wash Comments: 0 Spacer Comments: 0 Lead Cement 0 Comments: Tall Cement 0 CommenlS: Displacement 0 Comments: Calculated top of cement: Surface I Cement Company: Dowell ') Shoe Depth: 2616.05 Cementing Details Report Number: 1 I Field: Exploration I Hole Diameter: 12.25 Angle thru KRU: nla Report Date: 0210512001 AFC No.: AX2141 % washout: ? We'ght' 10.2 PV(pnor coMI' 41 Gels before 23124 Ge.ls att..r 4/8 Type' ARC a Wash Type' MUDPUSHXL Type: AS III Ute Mix wlr temp. 80 LC Depth: 2528.87 Stata type used. in/ëlT\als co\'arad and spacing PV(atter cond) 24 YPlprior condl, 42 YP(atter cond)' 11 Tolal Volume Circulated 1200 bbls Volume: Weight: 8.3 20 Volume: 40 Weight 10.2 No. 01 Sacks. 580 Weight: 10.7 Yield' 4.44 Type G MIX wlr Ie.mp. 80 Additives: G+50% D124, 0.9% D44, 0.4% D46, 30% D53, 1.5% 51,1.5% D79 Yield. 1.17 AddItives' G+ 1 % s t, 0.2~'. D46, 0.3% D65 Ralelbelore lad at shoe) 6 Reciprocation length. 10 Theoretical Displacement: 195.5 BBlS I Rig Contractor: NABORS, No 01 Sacks. 340 Weight. 15.8 CP: Date:02l05l01 Time:10:36 am Remarks:Had full returns throughout job. Reciprocated casing until top plug was dropped. Had 80 barrels good cement returns to surface @10.7 ppg. Mixed and pumped lead and tail at 6.2 to 6.4 BPM. Displaced using 25 barrels wash up water from Dowell and 170.5 barrels mud with the rig pumps at 6 BPM. RalE:(lall around shoel 6 Sir. WI. Up. 100 Reclprocallon spe€:d 10 FPM SIr WI DoVlln 85 Aclual Dlsplacemenl 195.5 BBlS Bumped plug: Yes SIr. WI. in mud. 85 Floats held: Yes Approved By: Robert L. Morrison Jr. ) ') I Rig Accept. hrs 01/31/2001 2633/2622 Prev Depth MD: 2633 Cum Cost $ 1245241 Next Csg: 7 @7440' Daily Drilling Report Phillips Alaska Drilling AFC No. I Date AX2141 02105/2001 Well: PALM #1 Contractor: NABORS Rig Name: Nabors 19E Operation At 0600: Make up BHA #2 Upcoming Operations: Trip In to cement, test casing, drill out, change over to fresh mud, LOT. RptNo 11 Depth (MDITVD) Daily Cost $ 594715 Last Csg: 9.625 @2616' Days Since AccepVEst: 4/5 Rig Relase - hrs: Progress: 0 Est Cost To Date $ Shoe Test: NIA MUD TYPE LSND WEIGHT 10.1 ppg VISCOSITY 50sqc PV/yP 24/11 GELS 4/8/ APIWL 6 HTHP WL ml/30 min SOLIDS 12% HOLE VOLUME 181 bbl MBT 20 ph 8.8 LGS 1 0.7% PIT VOL 550 DAILY MUD $921 TOTAL MUD $38059 COMPANY BAROID ßHÀ'O.ÉSCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS' . TIME I END 12:00 AM 12:30 AM 12:30 AM 01:00 AM 01:00 AM 02:30 AM 02:30 AM 07:00 AM 07:00 AM 07:3Õ AM 07:30 AM 08:00 AM DEPTH BIT NO. SIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL 2 N TST 02106/2001 02106/2001 ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 8.5 01/0812001 PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL HYC N SPACE 01/19/2001 SOWT TYPE TYPE TYPE DS70FNPV AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2705 24312 MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRilL WATER USED 620 0210512001 - BBLS TRQ BTM DEPTH IN DEPTH IN .~~;:";.:(~:/~:,',.' ..~:.:'.':' ~ POTABLE WATER 100 ~ ':.~ ~>;:~ ;{J :;,: ';':.t:~.~;~:;: 2633 . INJECTION USED - BBLS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATtlER ~ 0 PERSONNEL DATA PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of .5 1500 I I I / / PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 23 1121 1 LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 100° 6161 I SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -49.20 571581 I 0 GPM2 JETS JETS PHILLIPS 3 239124311 1211211211211212 11111 0 PERSONNEL I 0 SPS 1 BIT COST BIT COST CONTRACTOR 35 III 35825 0 PERSONNEL 0 SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 III III III 0 MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 10.1 I I I I I III PERSONNEL TOTAL 60 18.5" bit, 8" spe,rry.motor @1.22 d~rees, mwdllwd ~/fI~at sub, 3- nm flex ~rill collars, xo, 4- 4",hwdp,lar, 25 - 4" hWdp, xo..... Bit to RES = 35.14. bit to PWD 43.69. bit to GR = 44.95. bit 10 Survey = 60.19. bit to DEN. = 86.35, bit to NUT. = 91.61 . ,"", '.: ,,' ','::. '.'ÐAlìilPIi?E,ÐÅtA.' . ' ' .. '. ," " .-,' '. ' qD 10 . WEIGH:T . GRADE" CPNNECTION cLAss 2 . LENGTH 4 3.24 15.7 5-135 4" HT 40 PREM 2 1110.86 0-14710019 HOURS OPS CODE HOLE SECT I PHASE ai's I OPERATIONS FROM DODO" 0000 0.50 OTHER SURF Casing and Finish repairs to flow riser. Cementing 0.50 CASG SURF casing and Circulate through tight spot at 2040'. Cementing 1.50 CASG SURF Casing and Finish run 9.625. casing to bottom at 2616'. Land casing on Cementing hanger and make up Dowell cement head. 4.50 CIRC SURF Casing and Circulate and cnditlon mud prior to cement Job. Cementing 0.50 OTHER SURF Casing and Held PJSM with all contact personnel. Cementing 0.50 PRB_EFC SURF Casing and The 2" cement line on the rig floor got a pin hole in it when Cementing we psi tested the line prior to cementing. Replaced line with hi..psl hose. Daily Drilling Report: PALM #1 02/05/2001 Page 1 ) ) 08:00 AM 11:00 AM 3.00 CEMENT SURF Casing and Test cement line to 3500 psi. Cement casing per Cementing procedure-see cementing detail for additional Info. CIP @ 1036 hrs. 0210512001. Bumped plugs and floats held. 11:00AM 01:00 PM 2.00 CEMENT SURF Casing and PJSM. Clean out dlverter . nipple down and set out Cementing same.Set In and nipple up 13 5/8 - Sm BOPE. 01:00 PM 10:00 PM 9.00 BOPE PROD Other Set In and nipple up 13 5/8, 5m BOPE. 10:00 PM 11:00 PM 1.00 OTHER PROD Other Rig down casing elevators. balls. Rig up floor to drill ahead. 11:00 PM 12:00 AM 1.00 BOPE PROD Other Rig up to test BOPE. 24.00 Supervisor: R. MORRISON! D. SIMONTON Daily Drilling Report: PALM #1 02/05/2001 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: Palm #1 Date: 2/6/01 Supervisor: R. Morrison Jr. [tI Initial Casing Shoe Test Reason(s) for test: D Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", 36#, J-55, BTC Casing Setting Depth: 2,616' TMD Hole Depth: 2,653' TMD 2,816' lVD 2,6521 TVD Mud Weight: 9.3 ppg Length of Open Hole Section: 37' EMW= Leak-off Press. + Mud Weight = 925 psi + 9.3 ppg 0.052 x TVD 0.052 x 2,652' EMW for open hole section = 16.0 ppg Pump output = 0.1000 bps Fluid Pumped = 0.7 bbl 3,200 psi 3,100 psi 3,000 pst 2,900 pst 2,800 pst 2,700 pst ;;: 6('0 t.\1 :!.oj,jO P\' 2,400 pst 2.300 psi 2,200 psi 2,100 psi 2,000 psi W 1,900 psi a: 1,800 psI ~ 1.700 psi. tIJ 1,600 psi W 1,500 psi a: 1,400 psi Q. 1.300 psi 1.200 psi 1.100 psi 1,000 psi 900 psi 800 psi 700 psi ~gg~:/ ' 400 psi 300 psi 200 psi 100 psi 0 psi ~~~~~~~~~~~~~~~~$m~~~mi~~2Šia~~~~e~E~i~~~äi~~~m STROKES " 111111 III III III III 111111 III 111111111 III "' 111111 "' 11111111 ,.\,. .......,. ..... LEAK-OFF TEST ---CASING TEST -if/- LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME -+- TIME LINE / !TIME LINE ~E MINUTE TICKS f , J ~. .... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE '--------------"T--------------T----------------,r--------------,---------------r--------------- ~__m______------~_!!~~---~---__Q_~!L___~ l_-------------~---~-~!~!_--~----~P~-~---i '._----------------~_!!..~!_-----_!~~_p.!.LJ L_-----______l__~_!!~.!___L_~~r..~st.J ._-------------~--:-¡1~}--i--~~~-::}--1 ~--------------1---~-¡~~---t---:~-~~f--t C:::::::::::~I~:ž:!~!~~]~~:[~~~p-~C] ~~~:~~~~~~~:~~~j~~~!~~~!~~:[!~~~~~:P-!1~i ~--------------+--------------J----------------~ ~-------------_. ___1~_!!~!_-i-~!~!.P-!~-i ~--------------+--------------~----------------~ ~--------------~-_!!_!!~!_-~_!~!.~~J!s~ -I L______-----_J._------_____--L______--------J ~-------------_J.__1..'!_!!~~__L!t~_~~J!!~J L____-mm_+____----------L-------------..lL-------------.J-_!!_!!~~--L~t~~~-P.!L ~--------------.1.-______m_---L------_m___-! l-------------.J-_!!_!!I5!_-l.~~~_Q~_P.!.L1 I I I r J . ~--------------.,.-------------------------------~ ~--------------~---------------~----------------i . J . . I L______-------..;.--------------+----------------+ "--------------1'---------------.----------------" r I I I J t---------------'---------------i----:------------i L_-------------i---------------t----------------: L______--------.....--------______l______---------J ---------______l______---______L______---______f I ' I ' . I I t-----------------------------i----------------: .--------------. ---------------t--------------! ~--------------..,...------_._-----~--------_.._._---~ r---..---------_.I_--------------J.---------------I I I I , f f I I I I . . ~--------------+--------------~---------------_. -------------------------------I----------------_. , 1'- I 'I t I J . I . 1 }---------------¡.--------------~---------------,,~------------------------------t--------------- J I ,. f : I I I r t~~~~:::::::::~I:::::::::::::[::::::::~:::::~1 r-------------_. ---------------t----------------! ¡ I ¡ , SHUT IN TIME ¡ SHUT IN PRESSURE "-----"--------"'-------------------------------4 ~-------------_. ---------------,.---------------. 1 1 00. , '2500. I [1______--------.1.--------------..---------------..1 ¡.--_.:_-_!!!~I]--.!---------------L---.l-----.E!'--i I --------------i""""""'''.'.'..'.'''.''~...''..'.."."'.'.'..."'....'.i t--~~~-*}~--~---------------t-~;;~ ~::-! I ~------~------_. ---------------t~- ~- --- - -----1 ~!~!!l~_!~!!!~':'____m______~~~.!!~-~~!~~~!,E~--~.:_Q.!!!~I]-_J_--------------~-~t~~-P.!.~-I L__Q:.9_n~!~__..._-------______L__g?_~_.E~LJ ~--~.:g_!!!~I]_.1_--------______L~t~~~_P-!~.J L_!:.9_!!}!~__--------------.L--~.!~-p.~_t.l L-_?.:.Q_!!!~I]--;---------------L~t~~~-P.!.U l-_?.:.9__~!~--L------------J---~_?~_p.!.L-l ~-_?.:g_!!!~I]--J.-------------J-~~~~~_P.!.U ~__?:.9__~!~_-.,.--------------!---~_~!.p.!.L_~ ~-_?.:_q_!!1.!I]--J---------------~-~t~~~_p.!LI }__1:.9__~~~__+____m_------4---~-~~-P.!.~--i ~--~.:g_!!!~I]--~---------------i-~t~~~_P.!.LI ~--~:.9__~!~_-+--------------l---~-~~_P.!.~__~L_~:g_!!!~I]--~---------------~-;'~~~_p.!LI L_?.:.9__~!~_~1______--______L__~_~~.p-!.LJL2_Q.:.Q_!!!'~I}_J._------------_L~t~~~J!~l.J tl__?:.9__~!~_L_----------_.L--~_~!.P.!L.l Ll_?.:.Q_!!!'~I}-J.--------------L~t~~!.p.!U 8.0 min ¡ ¡ 810 psi I r 20.0 min ¡ ¡ 2,450 psi i p--------------.,..--------------.,-----------_...---" ..--------------,------------..--..-------..-----. ~__g:.9_~!~-!--------------!---~_Q~.P.!L_J ~_?"?.:.Q_!!!'~I}-~-----------_._-~-';~~~_p.!Li Ll9.:.q_~!I]_l.._-----______L__~_~~_p.!L.J L~Q.:.Q_r!.1j-I}.J_--------______L~!~~~_p.!.U '.'~ 'h~' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) Casing Detail 7" 26# Production Casing ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN Nabors 19E RKB to LOS = 29.60 Nabors 19E Rotary Table to LOS = 31.00 7" Landing Joint (above table 5.80) 7" Landing Joint (below table 31.00) 7" FMC GEN V, fluted mandrel hanger with 7", 26#, L~80 pup jts 16-230 7",26#, J-55, BTC-MOD (215 jts) Marker A 7",26#, L-80, STC-MOD Marker, top jt. = 19.63 Bottom jt. = 19.52 jts.3-15 7",26#, J-55, STC-MOD (13 jts) Davis Lynch Double Valve Float Collar 7", 26#, J-55, STC-MOD (1 jt.) Davis Lynch Double Valve Float Shoe jts 1 8TM OF SHOE @ TD at 9400' 204' of cased rat hole RA Marker @ 8736, Marker Joint Collars @8777.31 and 8796.94 Joint #2 and joints 231-242 will not be run on this well Total Solid Centralizers=16-- Total Bow Spring Cents.=63 7x8 3I8x8 Gemeco Solid Spiral Centralizers Floating on Joints Joints #4 through #14 (11 total) Gemeco Bow Spring Centralizers Run over Stop Rings Joint #1 10' above shoe and 10' below collar (2 total) Joint #3 in center of joint (1 total) ) WELL: Palm #1A DATE: 03/07/01 1 OF 1 PAGES LENGTH DEPTH TOPS 5.80 31.00 2.54 8743.77 39.15 526.37 2.02 41.85 2.38 -5.80 31.00 33.54 8777.31 8816.46 9342.83 9344.85 9386.70 . 9389.08 Gemeco Bow Spring Centralizers Run over Casing Collars On Every 3rd joint---- Joints #15,18,21,24,27,30,33,36 (8 total) On Every Joint--- Joints #37,38,39,40,41,42,43,44,45,46,47,48,49, 50 and 51 (15 total) . On Every 3rd Joint---- Joints #54, 57, 60, 63, 66, 69, 72, 75, 78, 81, 84 87,90,93,96,99,102 (17 total) On Every 3rd Joint--- Joints #105,108,111,114,117,120,123,126, 129, 13~ 135,138,141,144 and 147 (15 total) On Every 3rd joint----jointS#150, 153, 156, 159 and 162 (5total) 7x83/8x12 Gemeco Solid Straigt Blade Centering Guides Floating on Joints On every 2nd Joint---- Joints #165,167,169,171 and 173 (5 total) Remarks: String Weights with Blocks: 170k Up, 85k On, 25k Blocks. Ran 230 joints of casing. Drifted casing with 6. 151" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Nabors 19E Drilling Supervisor: R. Morrison c,. ..JING I TUBING I LINER DETAIL 7"96# Produc.tion Casing ) " ::.- ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN WELL: Palm # 1 A DATE: 03/07/01 2 OF 2 PAGES LENGTH DEPTH TOPS Remarks: String Weights with Blocks: 300k Up, 150k On, 70k Blocks. Ran 262 joints of casing. Drifted casing with 6.15P plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. } Phillips Alaska Drilling Well Name:.-žLI~~ ç(\.\M ,\\ Rig Name: Nabors 19E . ) Cementing Details Report Number: WJ1 Idcat I Field: Casing Size 7" Angle thru KRU: 68 Report Date: 0310912001 AFC No.: AX2143 Shoe Depth: 9389 LC Depth: 9342 % washout: Hole Diameter: 8.5" Centralizers Comments: Staltll}pe used, Intervals covered and spacIng See casing detail for details on centralizers. Ran 63 bow springs, 11 solid spiral 7 x 8 318 x 8, 5 solid straight 7 x 8 318 x 12 Mud Commenls: Weight: 12.7/12.2 PV(pnor cond): Gels before: Gels after: 619 Wash 'Comments: Type: CW 100 0 Spacer Comments: 0 Type: MUDPUSHXL Lead Cement 0 Comments: Ught weight blend Type: G Mix wtr temp: 80 PV(after cond) 22 YP(prior cond). YP(after cond): 13 Total Volume Circulated' 942 Volume: Weight: 8.3 ppg 40 bbls Volume: 40 bbls Weight 12.5 No. of Sacks. 282 Weigh; 13.0 ppg Yield' 1.99 Tall Cement 0 CQmmenls: MIX Wlr temp: 80 Additives: 8.0%0020,0.60"':'0800,0.60%0167,0.20%0046,0.30%0065 Yield' 1.2 Type: G No. of Sacks: 398 We'ghl. 15.8 Displacement 0 Commen!s: Rale(before tail at shoe)' 4.9 BPM Additives. 3.0%0053, 0.60"';'0065, 0.120~o08oo, 2.0 gal/sk 0600, 0.150 gal/sk D135, 0.20 gal/sk 0047 Str.WI.Up: 170 CP: Date:03l09/01 Time:11:31 am Remarks:Ran casing to bottom at 9389' and landed on hanger. Made up Dowell cementing head. Attempted to pull off hanger, pipe was stuck. Broke circulation and circulated 942 barrels of mud. Mud weights 12.5 to 12.7 and viscosities 80 to 102 were measured coming out of the hole. The mud was conditioned to 12.2 wt and 52 vis, in and out of the hole. Dowell batch mixed the tail cement. Dowell pressure tested lines to 3500 psi. Dowell mbced and pumped 100 barrels of lead at 13.0 ppg followed by 85 barrels of tail at 15.8 ppg. Flushed lines prior to dip/acing with 357.4 barrels of 12.2 ppg mud. The cement was preceeded with 40 barrels of CW100 flush at 8.3 ppg and 40 barrels of mud push XL spacer at 12.5 ppg. , The bottom plug was dropped between the flush and spacer. The top plug was dropped after pumping the tail cement. We had full returns to surface throughout the Job. The plugs did not bump and ltae floats did not hold (slight flow back). The casing was shut In with 0 psi for 4 hours. Reciprocation length: pipe stuck Theoretical Displacement. 357.16 Calculated top of cement: 4100' Cement Company: Dowell Rig Contractor: NABORS, Rale(lail around 5hoél: 4.9 BPM Reciprocation speed. 0 Sir. WI. Down. 85 Actual Displacemenl. 357.4 Bumped plug: no Sir. WI. In mud Floats held: no Approved By: R. L Morrison! R. Bowie ) Phillips Alaska Drilling AFC No. I Date Rpt No I Rig Accept. hrs AX2143 03lO9l2OO1 3 0310712001 Well: Palm #lA Depth (MDlTVD) 94OOf5946 Contractor: NABORS Daily Cost $183688 Rig Name: Nabors 19E Intermediate Csg; 9.625"02616' Operation At 0600 Drlg emt A 9105', taged .. 9063. Upcoming Operations: Drill to float collar at 9342' change over to sea water, test caslnr , pooh laying down. .:'FLUID DATA' 'FLUID LOSS ,. .. . . BIT DATA' .. , , EH&S MUD TYPE DAILY LOSS (bbls) SIT NO. SIT NO. ACCIDENT (non-spilO LSND 3 N WEIGHT 12.2ppg VISCOSITY 55sqc PVNP 23/17 GELS 5/91 APIWL 3.4 HTHP WL 10.4ml/3Omin SOLIDS 1" HOLE VOLUME 321 bbl MBT 27.5 ppb pl\ 10.5 LGS 8.4% PIT VOL 446 bbl DAILY MUD $850 TOTAL MUD $8770 COMPANY BAROID ,TIME: lEND I 12:00 04:30 AM AM 04:30 AM 05:00 AM 09:00 AM 06:00 AM 09:00 AM 11:30 AM 11:30 AM 12:00 PM 03:30 PM 04:30 PM 06:00 PM 07:30 PM 08:00 PM 12:00 PM oa:30 PM 04:30 PM 06:00 PM 07:30 PM 08:00 PM 12:00 AM TOTAL LOSS (bbls) PERFORATED INTERVALS PUMP PRES III PUMP NO I I I LINER SZ I I I SPM1 III GPM2 III SPS1 III SPP1 III MUDWT III SIZE 6.125 MAKE HTC TYPE '. ATJ4 SERIAL NO F83JF DEPTH OUT DEPTH IN 9095 FOOTAGE 305 ADT/A5r 1 WOB2 RPM1 TFA .9204 JETS 181181181 I I BIT C05r 2861 DULL III GRADE III SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADTIAST I WOB2 RPM1 TFA JETS 11111 BIT COST DULL III GRADE III HOURS lops CODE I HOLE SECT. UO CASG PROD 0.60 4.00 2.60 0.60 3.60 1.00 1.60 1.60 0.60 4.00 24.00 CASG CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD Daily CompletionMlorkover Report: Palm #1A 03/09/2001 ) Daily CompletionlWorkover Report Days Since AcceptlEst: 191 Rig Relase . hrs: PBTD (MD) 9339.93' Top of Fill CompletlonIWorkover Cost Total Well Cost $ 2165020 $494914 Production Liner: 7.0".386' . I PHASE OPS Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Cuing and Cementing EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 03lO9l2OO1 INJECTION INJECTION WELL 1R18 SOURCE WELL RATE (bpm) PRESSURE (PSi) INJECTION FLUIDS Water Base Muds 990 0 0 0 0 TOTAL VOL (bbO 990 TOT FOR WELL (bbl) 8600 Total Estimated Cost $ ,ORILLSlBOP DATA' LAST BOPIDIVERT LAST BOPIDRILL TST 0310312001 03101/2001 LAST H2S DRILL LAST FIRE DRILL 02107/2001 LAST SPILL DRILL 03lO2I2001 'FUEL & WATER LAST CONFINED SPACE FUEL USED 3140 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 150 100 WEATHER & , PERSONNEL DATA TEMPERATURE of -22° WIND SPEED 17 WIND DIRECTION 60° CHILL FACTOR OF -64.77° ARCO PERSONNel 2 CONTRACTOR PERSONNEL 29 MISC PERSONNEL SERVICE PERSONNEL TOTAL I"OPERATIONS FROM 0000 - 0000 Completed running 7" esg to 9389'. 47 Make up hanger to csg & rih on Idg jt. Install emt head. Clr f cond mud from 12.7 ppg f 87 vis out to 12.2 in f out I 64 vis, yp reduced to 13. PJSM. Cement 7" as per program, see csg f omt rpt for details. Plug did not IdS on calculated dlsp of 367 bbl - no press Increase as plug approached Idg collar. Cip 1131hrs 03092001. Floats I plug did not hold. SI for emt to gel. Wash up trucks & surface lines. WOC Open up 7", no now, observe for 30 min. Recover Idg jt. Run pack 0" .ssby & test to 5kpsl/30 min. Set wear bushing. PJSM. X-out pipe rams to 4" & test to 6k psi. Make up bha & tlh filling dp eaoh 3000'. Depth @ midnight 3000" Supervisor: . MORRISON I R. BOWIE Page 1 CASING TEST and FORMATION INTEGRITY TEST 3/10/01 Supervisor: R. Morrison Jr. Well Name: Palm #1A Date: 0 Initial Casing Shoe Test Reason(s) for test: ~ Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625",36#, J-55, BTC Casing Setting Depth: 2,616' TMD Hole Depth: 2,616' TMD 2,616' TVD 2,616' TVD Mud Weight: 12.2 ppg Length of Open Hole Section: 0' EMW= Leak-off Press. + Mud Weight = 680 psi + 12.2 ppg 0.052 x TVD 0.052 x2,616' EMW for open hole section = 17.2 ppg Pump output = 0.0840 bps Fluid Pumped = 5.5 bbl 3.200 psi 3.100psl . 3.000 psi 2,900 psi 2,800 psi 2,700 psi 2.600 psi 2.500 psi 2,400 psi 2.300 psi 2,200 psi 2.100 psi. 2.000 psi ~ ~:::= ~ 1.700psl en 1.800 psi W 1,500 psi 0::: 1,4oopsl Q. 1.300 psi 1.200 psi 1.100 psi 1,000 psi 900 psi iii5r" - 4OOp$l 300 psi 200 psi 100 psi 0 psi . -~ø~~~~~~~~~t~~~mm~~~~~a~g~i~~~~~¡~~~¡ä~~ji~~~i STROKES / TlME LINE ONE MINUTE TICKS . ...... LEAK-OFF TEST ---CASING TEST -@- LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME -+- TIME LINE III III III III 111111111111111 111111 111 111111111 III III III III III I e NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE t--------------Y-------------'--------------' r------------,------------r-- -. - -----, L._-----------+-.Q_:S.!~!_-~-____~E!L__~ ~-----------4-.!..~~~-~----~ ~L } i_-------______l__!.!~!...._L__~_C!.~-p~}-_J L---------.L----___-__L___-__---: ! ¡ 4 stks ' 400 51 ! ¡ I I ; .-------------- I -------~-. ---1-------P..-----. ..------------.- _n ------þ-------------, i I 6 stks : 400 mti ¡ I I I ¡ r--------------T--8tštkš---r--45Õ.r~r-l "-----------,-------------r-----------¡ }--------------+------------------- ~p , --1 ,.-----. ---..{--------- ""---~-------------I ~-------------+--l~-:~iï--:~~i:: -1 ~------------1------------t-------------J t---------------------------- . --.. i ------------1---------------1'-------------1 L_---------_J..__~~_!tk!_J_~_~!.P..!.~_l L_______J_------______L______-______i L------------+--~~ S~~!_-l-__~_~sL_. ~---------~-------------L----------.i l.----------___+__1~..!~~!_-! 575 p..!.L-l ~------------I---------j----------------! I I 20stks I 600 psi I I I I .---------------------- -- .~ ~ ~ - ------, "--------~-----------"---------------I ~-------------' - ~~ ~~~~-+ ~1!tp-!L_: ~---------_.:_---------~--------------I ~-------------';"~!.!~~!_-t- 625 _P..!.~-_. ~-----------J----------~---------------I ~------------_..._~!.!.~~.!_J- ~~O I!~l___, l______--_J_------______L______------~.i t--------_---_-l-~~ !~!-J--~.!~-P.!.Ll L-----------.l---------~--~------------.J t--------------+--î~ ~l~~--~- ~~~ P..¡}-~ t------------i-------------t---------------- }---------------------______1__- - P ----. "------------~--------"--------------I ~----------------~~ ~!~,!",,!__~~~_p..!.L_¡ L----------_J --------------~-------------i ~-----------------~!..!~~~--i--!2!-P.!.~--[ ,~-----------.J----------~-------------I I ' 04 stl\S I ovv pSI I I ~ I ~--------------------- ,,- -, ---- I " L_____-------t-!~ st~+--~.!~_p.!.L_~ t~.H~!J~_!JM.!~____------- ~~_~T.~,!P~_~!!~!!E l--------------.,.-_!~_!.!~~--J-~.!O ~sL_~ l-- O. Q.. min _I_-----------j----.Q..P.~J_----i I I . I I 1.0 min ' I 1 }--------------",.............................,.............._....._......,~ "------:,,~------------I--------------I ' I I 2.0 mm . I I ¡ . 1-------:,,-4 ----1-----------------1 I SHUT IN TIME SHUT IN PRESSURE I 3.0 mm I I I t-õ~Õ-ñi¡nT--------------r--šõo si --¡ ~-¡Õmrñ-1------------l-------------' .--------------...------------,,------ _£_-_._~ L-_-_-_---_J_-----------_.._---------______I '10. + I 150.' , , l----:..---~!~- ._-----------J-------------~ L--..!J11 ~-J-----------L--------------I , 20 . , I I 60 . I ' , l----:..-_.!!!!!:1_-+-----------!------------~ 1--' . !T!~~ .~--------------~---------------j I 3.0 min ' I I I 7.0 min I I I }------------------------- -~-- ------------~ 1--- -- -----~-------------"----------I I 4.0 min I ' I 8.0 min 1 1 I ~----------,:,----------------i---------------' 1-------:----1-------------1-------------' I 5.0 mm I 1 I 9.0 mm I I I ~--------,:,-------------i-------------_. ~--------:"--1--------------t--------------1 . 6.0 mm I 1 10.0 mm I I I ~~~?'~Q~~~~~~:~=~=~~~=J~~~~~~~~~~~~~=~~ :J-5. ~~~~:I~~~~==~~~=~[~=~=~~~~=J ; 8.0 min' i . : 20.0 min i j j "--------------------------1--------------": "'-------------1--------------"--------------' ~--g:..Q-_IJJ!~--!----------J---------------~ ,._?.5. q_f!!.Lfl..i-____-------!-----~---------i L1Q.._Q_~~~1._-----______L______-------_.J L~Q.:.q_!!l_~~_l______-______L______-----_.i ,~j "-~"~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ') Note to File Well 3S-18 PTO 202-206 Sundry 302-392 ConocoPhillips Alaska, Inc. requests approval for annular disposal in the subject well. This note analyzes information submitted by the applicant, affirms me- chanical integrity of the well within 3S-18's area of review (AOR), and recom- mends approving this request for annular disposal. 3S-18 9-5/8" surface casing was cemented with 486 bbls lead cement followed by 100 bbls tail cement, totaling about 2700/0 excess cement relative to gauge wellbore. 308 bbls of lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that 3S-18's surface casing is adequately cemented. The formation below the 9-5/8" casing shoe supported an 18.1 ppg EMW forma- tion integrity test. Applied pressure dropped 190 psi (from 1140 psi) during a 10 minute observation. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 15.9 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pressure reached a maximum of 490 psi. The pressure then stabilized and shut in pressure varied between 360 psi and 185 psi over 10 minutes. Cementing records indicate mechanical integrity of the well (3S-26) within 3S-18's AOR. The surface casing shoe is set in the Colville Shale below the West Sak sands in Well 3S-18. The predominate lithology at the shoe depth is mudstone. Large scale annular disposal projects at Tarn and Meltwater have shown lithologically similar and age equivalent sediments to be well suited as receiving and confining zones for annular disposal. The Palm development area is within the boundry of the Kuparuk River Unit aq- uifer exemption. Based upon information submitted, and the previous performance of similar op- erations AOGCC recommends approval of ConocoPhillips's request for annular disposal in Well 3S-18 (PTO 202-206). ~6A- 1Z-/2"~/°7- Winton Aubert Sr. Petroleum Engineer AOGCC //c; 103~ 2- Robert Crandall Sr. Petroleum Geologist AOGCC Scblullbepgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description Date 2G-12 3J-19 3B-02 3C-02 3S-18 3S-18 3M-07 31-16 1 <:l4- Jd) X" SBHP SURVEY (~~/i/9 LDL I ~'5 - () 5:J INJECTION PROFILE i 5 - I X" 8" INJECTION PROFILE ~Dd -d04> SBHP w PRESSURE & TEMP SURVEY J ~ 7,. oa Î INJECTION PROFILE I g1- 0 d ~ SBHP SURVEY 12/09/02 12/07/02 12/11/02 12/12/02 12/08/02 12/08/02 12/06/02 12/05/02 12/19/02 ?k?-1 NO.~ Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Sepia CD Color 1 1 1 1 1 1 1 1 ~ . RECE\\ED s~ (~o~p<.--.J DATE: DEe Zo 2.002 Oi~ & Gas Cons. eommiS$ÎOf\ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.A\as\{a ~ Anchorage ) \, \ TONY KNOWLES, GOVERNOR AIASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk River Unit ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Unit 3S-18 ConocoPhillips Alaska Permit No: 202-206 Surface Location: 2538' FNL, 1149' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 1615' FNL, 880' FWL, Sec. 18, TI2N, R8E, UM Dear Mr. Thomas: " . il ~ ~(~ ~v Enclosed is the approveçi,..application for permit to re " III the above development well. ..\.1\1,;(- ~Q¡1f' )~ This permit to redtÍll does not exempt you from obtaining additional permits or approvals required by law ftom other governmental agencies, and does not authorize conducting drilling operations until' all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please ,provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, 0~~~~ Chair BY ORDER OF THE COMMISSION DATED this1 day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) COhoeO .billips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com September 26, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 38-18 Dear Commissioner Taylor: / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 38-18, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). / If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, .~\~ Randy Thomas GKA Drilling Team Leader I ""- RECEIVED OCT 0 1.2002 AlasKaOlIt Gas Qøns. GomøItISIøn - - Anchomge 6. Property Designation ADL 380107 ALK 4624 7. Unit or property Name Kuparuk River Unit 8. Well numbo/ 3S-18 / 9. Approximate spud date / November 15, 2002 14. Number of acres in property 2448 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Maximum surface 2993 psig / At total depth (TVD) 3638 psig Setting Depth ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB = 28' 1 a. Type of work: Drill ~ Redrill U Re..entry ODeepen 0 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2538' FNL, 1149' FEL, Sec. 18, T12N, R8E, UM At top of productive interval 1625' FNL, 910' FWL, Sec. 18, T12N, R8E, UM At total depth 1615' FNL, 880' FWL, Sec. 18, T12N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 880 @ TD880 @ TD 3S-26A @ 86' / 16. To be completed for deviated wells Kickoff depth: 260 MD 18. Casing program size feet Maximum hole angle 33° \;V6.A- 1/ I çJ Oz- 'J Development Oil ~ Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 11. Type Bond (see 20 MC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 6879' MD / 6094' TVD Hole Casing Weight 42" 16" x 30" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling H-40 Weld L -80 BTC L -80 BTCM Top Bottom Quantity of Cement Length MD TVD MD TVD (include stage data) 80' 28' 28' 108' 108' 9 cy High Early 2838' 28' 28' 2866' 2585' 530 sx AS Lite & 230 sx LiteCrete 6851' 28' 28' 6879' 6094' 210 sx Class G OCT 0 1.2002 _all a. Ions. commtsslon AncI1oJag8 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 0 Size Cemented Measured depth Length Perforation depth: measured true vertical True Vertical depth RI€EIVED 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis OSeabed 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 "T<-~ ~~ Title: Kuparuk Drilling Team Leader Date 4 ('50 10'<- R. Thomas \ PrAnArArl hv ShAron AlIslln-nrAkA Commission Use Only Permit Number I API number tj I Approval date 20.2..-20h 50-/cr3- 2.0733 Conditions of approval Samples required 0 Yes ~ No Mud log required Hydrogen sulfide measures 0 Yes KJ No Directional survey required Required working pressure for BOPE 02M; 0 3M; 0 5M; 0 10M; 0 Other: Te.st- 'goPE ~ 5"°o'c.?o .Q!¿edBy . 'ngma~gn Cammy Qechsli Ta;ø \~\\)~ -¡g¡ Yes 0 Approved by Commissioner by order of the commission Form 10-401 Rev. 12/1/85. CR~ ~:'" ""I' ,,~~ ~ '¡ ,:. 'iA 1 W.II i ',. Isee cover letter for other requirements U Yes ~ No 0 No Date \\\~\()~ Submit in triplicate ') Ar"~ation for Permit to Drill, We1l3S-18 / Revision No.O Saved: 19-5ep-02 Permit It - Kuparuk Well 35-18 Application for Permit to Drill Document Mi)ximizE We-II VgIUE; 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 Iii ng Hazards Information .. ....... ............ ..... .... ........... ..... ..... ... ....... ..... ..... .... ........ 3 Requirements of 20 AAC 25.005 (c)( 4) ... ............ ........................................ ........................................... 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and 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 u id Program. ..... ........ ... ... ...... ..... ....... ....... ...... ... .... ..... ..... ....... ..... ............. 4 Requirements of 20 AAC 25.005(c)(B) .... ............... ........... ............ ........ .......................... ..... ...... ............ 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........ ......... ... .................... ......... .................................... .............5 10. Seism ic Analysis... ....... ...... ................... ... ......... .... .......... ...... ..... ... .... ..... ........ .......... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bondi n9 ............... .... .......... ........ ....... ... ...... ........ ....... ....... ..... ....... ........ 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program .....................................................................................6 0 IIó ......., " L 3S-18 PERMIT IT.DOC Page 1 of 7 Printed: 19-5ep-02 ) A"--cž\cation for Permit to Drill, We1l3S-18 } Revision No.O , Saved: 19-5ep-02 Requirements of 20 AAC 25.005 (c)(13) .. ..................... ...... .............. ...... ............. ......... """''''' ........ ...... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15 . Attach m e nts ............................................................................................................. 7 Attachment 1 Directional Plan............. ..... ...... ............ ............ .......................... ......... .... ...... .................. 7 Attachment 2 Drilling Hazards............................................................................................. 6 Attachment 3 Well Schematic................... ....... ...... ..................... .............. ...... ......... .......... ..6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 2.5.040(b). For a well with multiple well branche::,~ each branch must similarly be Identified by a unique name and API number by adding a suffix to the name designated for the wel! by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 35-18. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fo!lowing item0 except for an item already on file wIth the commission and Identíf!ed lì7 the application: (2) a plat IdentifyfÌìg the property and the property's owners and showing (Ajthe coordinates of the plvposed location of the well at the swface¡ at the top of eaä7 ol?jective formation and at total depth referenced to governmental section lines. (B) the coordinates of the proposed location of the !ivell at the slJrfac~, referenced to the state plane C()o((jinate system f../)r this state as maintained by the National Geodetic Survey li7 the National Oceanic and Atmospheric Administration/ (C) the proposed depth of the we!! at the top of eaäì objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,993,879 Eastings: 476,111 12538' FNL, 1149' FEL, Sec 18, T12N, R8E, UM RKB Elevation Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "c" Sand) NGS Coordinates Northings: 5,994,800 1625' FNL, 910' FWL, Sec 18, T12N, R8E, UM Eastings: 473,367 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6651' 5868' 5812' Location at Total Depth 11615' FNL, 880' FWL, NGS Coordinates Northings: 5,994,810 Eastings: 473,337 Sec 18, T12N, R8E, UM Measured Depth, RKB: Total Vertical Depth, RKB.' Total Vertical Depth, 55: 6879' 6094' 6038' and (D) other infomìðtion required by 20 AAC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentíonally deviated, the application for a Permit to Dn!1 (Form 10-401) must (1) include a plat., drawn to a sUItable scale, showing Nle path of the proposed weflbore, including all adjacent wellbores within 200 feet of any portion of the proposed we//,' Please see Attachment 1: Directional Plan ORit;¡;a ,1~ 3$-18 PERMIT IT. DOC Page 2 of 7 Printed: 19-$ep-02 ') ,A~'1pation for Permit to Drill, We1l3S-18 } Revision No.O Saved: 19-5ep-02 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that thos--e names are knov'/f1 or discoverable in public record..~ and show that each named operator has been furnished a copy of the application by certilìed mall:. 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 f'or a Permit to Dríll must be accompanied by each of the follov'/ing Items, except for an Item already on fHe with the commission and identified in the application: (3) a diagram and description of the blovrlout prevention equipment (BOPE) as required by 20 AAC 25.03~ 20 AAC 25.036, or 20 AAC 25.037/ as app/icable/ Please reference BOP schematics on file for Nabors 7E5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dríll must be aCL"Ompanied by each of the {allowing ¡tem5~ except fÓr an item already on file with the commis.sion and identified in the application: (4) information on dil/ing hazards/ including (A) the maximum downhole pressure that may be encounterert cnter/a used to dete/mine i~ and maximum potential surface pressure based on a methane gradient/ A pressure build-up test performed on Palm lA (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 35-18 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5868' tvd: MP5P =(5868 ft)*(7° 62 - 0.11 psi/ft) = 2993 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. /' and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata/ lost circulation zone~ and zones that 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) An application for a Permit to Drí// must be accompanied by each of the f'ol/owing items, except for an item already on file w¡th the commission and ¡dentitied in the application: (5) a descríptioj] oft/7e procedure for conducting formation integrity tests, as required under 20 MC 25.030{f); A procedure is on file with the commission for performing LOT's. For 35-18 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) 0 ¡ II ,,"," j ¡ ¡ t &. 3S-18 PERMIT IT. DOC Page 3 of 7 Printed: 19-5ep-02 ) Ar-", ,ation for Permit to Drill, We1l3S-18 J Revision No.O Saved: 19-5ep-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applicatIon for a Permit to Drill mu~t be accompanied by each of the follov'¡lng item~ except tor an item already on file with the commIssion and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 03~ and a descríption of any slotted liner, pre- petforated liner, or screen to be installeft. Casing and Cementing Program Hole /' / Top Btm CsgfTbg Size Weight Length MDfTVD MDfTVD 00 (in) (irO (/b/ft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 2838' 28'/28' 2866'/2585' Lead: 530 sx 10.7 ppg / AS Lite /' Tail: 230 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface / 7 8-1/2 26 L-80 BTC-Mod 6851' 28'/28' 6879'/6094' 210 sx 15.8 ppg 'G' wI 3-1/2 EUE 8rd 6520' 28' / 28' 6548'/5767' ~~~ned Toc6,;) 9.3 L-80 SAB- 3 packer set at Mod 6548' MD. An open-hole leak-off test will be performed on the 8 112" open hole interval after reaching the contingent casing point. If the leak-off test indicates insufficient formation integrity, 7" casing will be top-set above the Kuparuk C sand. In this case, 6 1/8" hole would be drilled to total depth and a 3 112" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information / Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fol/owing item~ except for an item already on file ¡"11th the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25, 03!ý¡ unless this requirement is waived by the commls..<;io!l under 20 MC 25,035(h)(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 Petroff to Drill must be accompanied by each of the following Item~ exæpt for an item already on file with the commission and identified in the application: (8) a drilkng fluid program, including a diagram and desalption of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done using mud systems having the following properties: 0 .1 'G' /.?J ~ ,/..¡'iVÞu.. 3S-18 PERMIT IT. DOC Page 4 of 7 Printed: 19-5ep-02 ') Ar~'\:ation for Permit to Drill, We1l3S-18 J Revision No.O } Saved: 19-5ep-02 Suface Hole mud properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value / Density (ppg) 9.4 9.4* 9.4* 9.4* Funnel Viscosity 120-130 120-100 1 00-120 1 00-75 (seconds) Yield Point 35-45 27 -40 25-35 20-30 (cP) Plastic Viscostiy 8-15 11-22 15-30 15-30 (/b11 00 sf) 10 second Gel 1 0-30 10-25 10-25 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 20-40 15-35 Strength (/b1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 12-15 7-8 7-8 7-8 Solids (%) 6-9 6-12 6-12 6-12 * 9.8 if hydrates are encountered Production Hole mud properties initial C40 Top Morraine Top HRZ ¡¡; Density (ppg) 9.5 10.2 10.6 10.8 27 / Funnel Viscosity 40-55 42-55 42-58 42-58 -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 (lbl1 00 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (/b1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (/b1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 15-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Drill must be accompanied by each of the following ¡tem~ exæpt for an Item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(t); N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Perrnit to Drill must be accompanied by each of the following ¡tem~ except for an Item already on file wit!] the commission and identified in the application: (10) for an exploratory or stratigraphic test ¡"¡ell a seismic refraction or reflection analysis as required by 20 MC 25.061(a); N/ A - Application is not for an exploratory or stratigraphic test well. c ¡ " "". 3S-18 PERMIT IT. DOC Page 5 of 7 Printed: 19-5ep-02 ') Ap"'''iation for Permit to Drill, We1l3S..18 J Revision No.O " Saved: 19-5ep-02 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applIcatIon for a Perm¡t to Drill must be accompanIed by each of the fol/owing Item5~ except for an item already on file wIth the commIssIon and Identified in the application: (11) for a well drilled tram an offshore platform/ mobile bottom-founded structure/ jack-up lig/ or floating drilling vesse¿ an analysis of seabed conc!Jtlons as requIred by 20 AAC 25.061(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 Perm¡t to Drill must be accompanied by eadï of tile following Items~ except for an Item already on file with the commissIon and Identified in the application: (12) evidence showing that 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 for a Permit to Dnll must be aœompanied by each of tile followIng ítem~ except for an Item already on ffle with the (:ûmmission and identified in the applícation: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. )/<' 1. MIRU Nabors 7ES. - / 2. Install diverter system.! 3. Drill 12-1/4" hole to 9-5/S" surface casing point according to directional plan. Run LWD logging equipment with GR tool only. 4. Run and cement 9-5/S" 40#, L-SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surfa<;t 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 cementynd 20' of new hole. Perform LOT. 6. Drill S-1/2" hole to contingent top-set casing point according to directional plan. Run LWD / logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. POOH and P/U neutron density tool, drill well to total depth according to directional plan, and run 7" 26# L -SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sa,99' sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . 7./Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 '12" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. ( Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L-SO BTCM 1 casing will be run and cemented above the Kuparuk C sand. 6 l/S" hole will be drilled to total depth /' / according to the directional plan and a 3 '12" 9.3# L-SO SLHT liner will be ran and cemented across the l productive intelVal. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applicatIon for a Pem7it to Drill mustc be accompanied by each of the following items/ except for an ¡tern already on file with the commIssion and Identified in the application: (14) a general description of how the operator plans to dispose of drillIng mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25,080 for an annular disposal operation In the well.; C" J ~ £ 35-18 PERMIT IT. DOC Page 6 of 7 Printed: 19-5ep-02 ~~ \~ 4 J ) Ap...I:.~tion for Permit to Drill, We1l3S-18 J Revision No.O , Saved: 19-5ep-02 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 35-18 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. Ol;¡u¡, i L 38-18 PERMIT IT. DOC Page 7 of 7 Printed: 19-8ep-02 ) ) 35-18 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" CasinCj Interval Event Broach of Conductor I Risk Level I Low Gas Hydrates Low Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Moderate Moderate Low Lost Circulation Low 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Risk Level Low Moderate Barite Sag Differential Sticking Low Moderate Abnormal Reservoir Pressure Moderate Lost Circulation Moderate Mitigation Strategy Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Miti~ation Strate~y Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. / 3S-18 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 OR',,::,~,." ;Y .j . .1 ,pa,g",.,',e"", ,1,l,Of.,J" 1 " /,1 1 I " ~ 7!-~ KRU - 38-18 Pro~J1cer Proposed Completion Schematic Single Completion wI Jet Pump Contingency 16"x30" . II Insulated Ji: I conductor @ I I +1- 10:~~ I T. Mi-sf,W," Po <! ~ Collar Gra C reads (+/- ~ 1000'~D/TVD) ~ I I Surface csg. I 9-5/8"40# L-80 I BTC (2866' MD I .....II&.Z 2585' TVD) Casing point 100' above the C80 sand C Sand Perfs )1 (to be done after rig moves off) r ~ Ii r ~ . ~ ~ I ~ ~ ~ I ~ ~ I fS! ~ ~ I I ~ ~I I ~ 1"1 .... ~ ~ II I I tBl' ~ ~ e2 ~ ~p ~ ~ I I I I ~ ~ ~ I ~ I ~ ~ I I I I ~ ~ ~ ~ ~ I I ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ . ~ ~ I ~ ~ ~ ~ I I ~ ~ ~ ~ ~ ~ ~ t ~ ~ ~ ~ ~ ~ ~ ~ I I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ I I ~ ~ ~ I I I ~ ~ ~ I ~ ~ ~ ~ I ~ ~ ~ I I ~ ~ ~ ~ ~~-----I ~. I ./ I ' , ~ I -,dn .. ..., I I ~ I ~ ~ ~ .J t_-- J r- - (00" Y:"¡' .."-- ---"-~ r- ~ ~ ~ ~ ~ ~ '- ~ ~ ~ I J j::~:ftmHr:.:.L Production csg. 7" 26# L -80 BTCM (+1- 6879' MO) ~p'..."'......'...'...'.h.>.I~" ,!ilIIIPi 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# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Cameo OS Landing Nipple with 2.875" ID No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Placement TBD. Valves #1-4: 3-%" x 1" KBUG Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wI DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Cameo No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RO handling pups installed above 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' perm~~cker set +/-100' MO above top planned perf. Minimum 10 through the pack~{3.0(."..O"Oï: 1 ,,( 6' Pup Joint 3-1/2", L-80, 9.3# EDÉ 8rd Mod Tubing. 3-1/2" Camco '0' nipple wI 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 wI shear out sub. Tubing tail 50' above top planned perforation. TO @ 6,879' MD /6094' TVO (200' MO below Miluveach) Scott L Lowry 9/5/02 0 L (4 Sperry-Sun Drilling Services ConocoPhillip~j@A' Western North Slope Ku~ t(,1;c 3S Pad '(,:,,03) '~ oposal Report 26 September, 2002 C) ::0 ---- !;:) ---..... """,,-.,,,.. <'ill c:.:::. ':t~ r--- Surface Coordinates: 5993878.51 N, 476110.57 E (70023'39.8581" N, 150011'39.7374" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 56. 10ft above Mean Sea Level ~' :~':[CJ;]~~~~;r:~ Á fflftfbu44H) b3i\t.~¡t Proposal Ref: pro9974 Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-18 Plan - 3S-18 (wp03) ConocoPhil/ips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical. Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section. (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -56.10 0.00 0.00 N 0.00 E 5993878.51 N 476110.57 E I..,.,...w'" 0.00 SHL (2538' FNL & 1149' FEL, SEC 18- T12N - R8E) 100.00 0.000 0.000 43.90 100.00 O.OON 0.00 E \1r"llf~ .000 0.00 200.00 0.000 0.000 143.90 200.00 O.OON 0.00 E . .000 0.00 260.00 0.000 0.000 203.90 260.00 O.OON 0.00 E 0.000 0.00 Begin Dir @ 2.5°/100ft (in 12-114" Hole): 260.00ft MD, 260.00ft TVD 300.00 1.000 288.383 243.90 300.00 0.11 N 0.33W 2.500 0.35 400.00 3.500 288.383 343.81 399.91 4.06W 5993879.87 N 476106.52 E 2.500 4.27 .-...-" 500.00 6.000 288.383 443.46 499.56 11 .91 W 5993882.51 N 476098.67 E 2.500 12.55 600.00 8.500 288.383 542.65 598.75 23.89 W 5993886.53 N 476086.71 E 2.500 25.17 700.00 11.000 288.383 641 .20 697.30 39.96 W 5993891.92 N 476070.65 E 2.500 42.11 800.00 13.500 288.383 738.92 795.02 60.09 W 5993898.67 N 476050.54 E 2.500 63.32 900.00 16.000 288.383 835.61 891.71 84.25 W 5993906.78 N 476026.41 E 2.500 88.78 1000.00 18.500 288.383 931.11 987.21 112.39 W 5993916.22 N 475998.30 E 2.500 11 8.43 1100.00 21.000 288.383 1025.22 1 081.32 144.45 W 5993926.98 N 475966.27 E 2.500 1 52.22 1200.00 23.500 288.383 1117.77 1173.87 180.38 W 5993939.03 N 475930.38 E 2.500 190.08 1300.00 26.000 288.383 1208.57" 1264.67 220.11 W 5993952.36 N 475890.69 E 2.500 231.95 '~fHf::ma 1400.00 28.500 288.383 1297.47 1353:57 87.59 N 263.56 W 5993966.94 N 475847.29 E 2.500 277.73 1500.00 31.000 288.383 1384.28 1440.38 103.23 N 310.64 W 5993982.74 N 475800.26 E 2.500 327.35 1 586.63 33.166 288.383 '(1;11,457.6'7"':' 1513.77 117.74N 354.31 W 5993997.38 N 475756.64 E 2.500 373.36 End Dir, Start Sail @ 33.17° : 1586.63ft MD, 1513.78ft TVD 1600.00 33.166 288.383 1468.87 1524.97 120.05 N 361 .25 W 5993999.71 N 475749.71 E 0.000 380.67 1625.24 33.166 288.383 1490.00 1546.10 124.40 N 374.35 W 5994004.11 N 475736.62 E 0.000 394.48 Base Permafrost C) 1700.00 33.166 288.383 1552.58 1608.68 137.30 N 413.16 W 5994017.13 N 475697.85 E 0.000 435.38 ~, 1800.0 33~,1:ß6{:<;288.383 1636.29 1692.39 154.55 N 465.08 W 5994034.55 N 475645.99 E 0.000 490.09 -",e.c- 1900.0 33.166' .'288.383 1720.00 1776.10 171.81 N 516.99 W 5994051.97 N 475594.13 E 0.000 544.79 ~ ~=~ 2000.0 33.166 288.383 1803.70 1859.80 189.06 N 568.91 W 5994069.39 N 475542.27 E 0.000 599.50 'J: ~» 2100.00 33.166 288.383 1887.41 1943.51 206.31 N 620.82 W 5994086.80 N 475490.41 E 0.000 654.20 ~,~~¡;:"'~ 2180.74 33.166 288.383 1955.00 2011.10 220.24 N 662.74 W 5994100.87 N 475448.54 E 0.000 698.37 Top West Sak :t~'20 2200.00 33.166 288.383 1971 .12 2027.22 223.56 N 672.74 W 5994104.22 N 475438.55 E 0.000 708.91 i--- 2300.00 33.166 288.383 2054.83 2110.93 240.82 N 724.65 W 5994121.64 N 475386.69 E 0.000 763.62 2400.00 33.166 288.383 2138.54 2194.64 258.07 N 776.56 W 5994139.06 N 475334.83 E 0.000 818.32 2500.00 33.166 288.383 2222.25 2278.35 275.32 N 828.48 W 5994156.48 N 475282.97 E 0.000 873.03 26 September, 2002 -10:50 Page 2 of8 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-18 Plan - 35-18 (wp03) ConocoPhiJlips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft 2600.00 33.166 288.383 2305.96 2362.06 292.57 N 880.39 W 0.000"" 927.74 2700.00 33.166 288.383 2389.67 2445.77 309.82 N 932.31 W 0.000 982.44 2712.34 33.166 288.383 2400.00 2456.10 311.95 N 938.72 W 0.000 989.19 Base West Sak 2800.00 33.166 288.383 2473.38 2529.48 327.08 N 984.22 W .000 1037.15 2866.00 33.166 288.383 2528.63 2584.73 338.46 N 1018.49W 0.000 1073.25 9..5/8" Csg Pt ... Drill out 8-1/2" Hole 2866.00ft MD, 2500.98ft TVD 9 5/8" Casing 288.383 2557.09 2613.19 1036.14 W 5994226.1'5 N 475075.54 E '~ 2900.00 33.166 0.000 1091 .85 2965.60 33.166 288.383 2612.00 2668.10 1070.t9 W 5994237.58 N 475041.52 E 0.000 1127.74 C-80 (K-10) 3000.00 33.166 288.383 2640.80 2696.90 1088.05 W 5994243.57 N 475023.68 E 0.000 1146.56 3100.00 33.166 288.383 2724.51 2780.61 1139.97 W 5994260.99 N 474971.82 E 0.000 1201 .27 3200.00 33.166 288.383 2808.21 2864.31 11 91 .88 W 5994278.40 N 474919.96 E 0.000 1255.97 3300.00 33.166 288.383 2891 .92 2948.02 1243.80 W 5994295.82 N 474868.10 E 0.000 1310.68 3400.00 33.166 288.383 2975.63 3031.73 1295.71 W 5994313.24 N 474816.24 E 0.000 1365.38 3500.00 33.166 288.383 3059.34 3115.44 1347.63 W 5994330.66 N 474764.38 E 0.000 1420.09 3600.00 33.166 288.383 3143.05 3199.15 1399.54 W 5994348.08 N 474712.52 E 0.000 1474.80 3700.00 33.166 288.383 3226.76. 3282.86 1451.46 W 5994365.49 N 474660.66 E 0.000 1529.50 ""::~::;:%m::::~:ili 3800.00 33.166 288.383 3310.47 336'éi:57 499.60 N 1503.37 W 5994382.91 N 474608.80 E 0.000 1584.21 3900.00 33.166 288.383 3394.18 3450.28 516.85 N 1555.28 W 5994400.33 N 474556.95 E 0.000 1638.92 4000.00 33.166 288.383 77.89,)1<" 3533.99 534.10 N 1607.20 W 5994417.75 N 474505.09 E 0.000 1693.62 4100.00 33.166 288.383 1.60 3617.70 551.36 N 1659.11 W 5994435.17 N 474453.23 E 0.000 1748.33 4200.00 33.166 288.383 45.31 3701.41 568.61 N 1711 .03 W 5994452.58 N 474401.37 E 0.000 1803.03 4300. 288.383 3729.02 3785.12 585.86 N 1762.94 W 5994470.00 N 474349.51 E 0.000 1857.74 C) 4400. 288.383 3812.73 3868.83 603.11 N 1814.86 W 5994487.42 N 474297.65 E 0.000 1912.45 4500. 288.383 3896.43 3952.53 620.37 N 1866.77 W 5994504.84 N 474245.79 E 0.000 1967.15 =t:l 4600.0 288.383 3980.14 4036.24 637.62 N 1918.69 W 5994522.26 N 474193.93 E 0.000 2021.86 ~. ~-li.>,.., 4650.0 288.383 4022.00 4078.10 646.24 N 1944.65 W 5994530.97 N 474168.00 E 0.000 2049.21 C-40 (K-3) !:;.. '; 4700.00 33.166 288.383 4063.85 4119.95 654.87 N 1970.60 W 5994539.67 N 474142.07 E 0.000 2076.57 --- 4800.00 33.166 288.383 4147.56 4203.66 672.12 N 2022.52 W 5994557.09 N 474090.21 E 0.000 2131.27 4900.00 33.166 288.383 4231.27 4287.37 689.38 N 2074.43 W 5994574.51 N 474038.35 E 0.000 2185.98 5000.00 33.166 288.383 4314.98 4371.08 706.63 N 2126.35 W 5994591 .93 N 473986.49 E 0.000 2240.68 5100.00 33.166 288.383 4398.69 4454.79 723.88 N 2178.26 W 5994609.35 N 473934.63 E 0.000 2295.39 r-- 5200.00 33.166 288.383 4482.40 4538.50 741.13N 2230.17 W 5994626.77 N 473882.78 E 0.000 2350.10 5300.00 33.166 288.383 4566.11 4622.21 758.38 N 2282.09 W 5994644.18 N 473830.92 E 0.000 2404.80 5392.43 33.166 288.383 4643.48 4699.58 774.33 N 2330.08 W 5994660.28 N 473782.98 E 0.000 2455.37 Begin Drop @ 2.00/100ft : 5392.43 MD, 4699.58ft TVD 5400.00 33.014 288.383 4649.82 4705.92 775.63 N 2334.00 W 5994661 .60 N 473779.06 E ./ 2.000 2459.50 5500.00 31 .014 288.383 4734.61 4790.71 792.35 N 2384.30 W 5994678.48 N 473728.81 E 2.000 2512.51 26 September, 2002 -10:50 Page 3 of8 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-18 Plan - 35-18 (wp03) ConocoPhi/lips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5600.00 29.014 288.383 4821 .20 4877.30 808.13 N 2431.77 W 2 .000¡tt¡ìt!:fr~¡~62 .53 5700.00 27.014 288.383 4909.47 4965.57 822.94 N 2476.34 W 2.000 2609.50 5800.00 25.014 288.383 4999.34 5055.44 836.77 N 2517.96 W 2.000 2653.35 5900.00 23.014 288.383 5090.68 5146.78 849.60 N 2556.58 W .000 2694.05 5953.38 21.947 288.383 5140.00 5196.10 856.04 N 2575.94 W 2.000 2714.46 Top Morraine 6000.00 21.014 288.383 5183.38 5239.48 861.42 N 2592.15 W 5994748.21 N 2.000 2731.53 6100.00 19.014 288.383 5277.34 5333.44 872.21 N 2624.62 W 5994759.11 N 2.000 2765.76 6200.00 17.014 288.383 5372.43 5428.53 881.97 N 2653.97 W 5994768.95 N 2.000 2796.68 ~ 6254.82 15.918 288.383 5425.00 5481.10 886.87 N 2668.71 W 5994773.90 N 2.000 2812.22 Top H RZ 6300.00 15.014 288.383 5468.55 5524.65 890.67 N 2680.15 W 5994777.74 N 2.000 2824.27 6400.00 13.014 288.383 2703.13W 5994785.45 N 473410.33 E 2.000 2848.48 6466.99 11.675 288.383 716.72 W 5994790.01 N 473396.75 E 2.000 2862.80 Base H RZ 6500.00 11.014 288.383 2722.88 W 5994792.07 N 473390.60 E 2.000 2869.30 6576.86 9.477 288.383 2735.85 W 5994796.43 N 473377.64 E 2.000 2882.97 K-1 6600.00 9.014 288.383 2739.38 W 5994797.61 N 473374.11 E 2.000 2886.68 --- 6647.69 8.061 288.383 912.58 N 2746.10 W 5994799.87 N 473367.40 E 2.000 2893.76 Kuparuk 6650.72 8.000 288.383 912.72 N 2746.50 W 5994800.00 N 473367.00 E 2.000 2894.19 TARGET: Start Sail @ 8.0° : 6650.72ft MD, 5868.1 Oft TVD (162! FNL & 910' FWL, Sec 18-T12N-R8 Target - 3S-18 (Geo), 150.00 Radiu Geological 5840.00 5896.10 913.96 N 2750.24 W 5994801 .25 N 473363.27 E 0.000 2898.12 Miluveach 5860.80 5916.90 914.88 N 2753.01 W 5994802.18 N 473360.50 E 0.000 2901.05 5959.83 6015.93 919.27 N 2766.22 W 5994806.61 N 473347.31 E 0.000 2914.96 c:::> 6038.06 6094.16 922.74 N 2776.65 W 5994810.12 N 473336.88 E 0.000 2925.96 Total Depth: 6879.00ft MD, 6094.16ft TVD (1615' FNL & 8~ FWL, Sec 18-T12N-R8E) 7" Casing ( All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.1' MSL. Northings and Eastings are relative to 2538' FNL, 1149' FEL. ""¿. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. .... ~- The Dogleg Severity is in Degrees per 100 feet (US). i"'""-' Vertical Section is from 2538' FNL, 1149' FEL and calculated along an Azimuth of 288.383° (True). Magnetic Declination at Surface is 25.4600(05-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 6879.00ft., The Bottom Hole Displacement is 2925.96ft., in the Direction of 288.383° (True). 26 September, 2002 - 10:50 Page 4 of8 DrillQuest 3.03.02.002 Western North Slope Comments Measured Depth (ft) 0.00 260.00 1586.63 2866.00 5392.43 6650.72 6879.00 Sperry-Sun Drilling Services Proposal Report tor Kuparuk 35 Pad - 35-18 Plan - 35-18 (wp03) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 O.OON 0.00 E 260.00 0.00 N 0.00 E 1513.78 117.74 N 354.31 W 2584.73 338.46 N 1018.49 W 4699.58 774.33 N 2330.07 W 5868.10 912.72 N 2746.50 W 6094.16 922.74 N 2776.65 W Comment ConocoPhillips SHL (2538' FNL & 1149' FEL, SEC.*,1.8- T12 Begin Dir @ 2.5'/100ft (in 12..1/4" Hole): 260.oõllh1p, 260.00ftTVD End Dir. Start Sail @ 33.11' : 1586.63ft MD. 1513:'6ftTVD 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 2866.00ft MD, 2500.98ftTVD Begin Drop @ 2.0"/100ft : 5392.43ft MD. 4699.58ft TVD TARGET: Start Sail @ 8.0~: 6650.72ft MD. 5868.10ftTVD (1625' FNL & 910' FWL, See 18-T12N-R8E) .Total Dé_ilf.t6879.00trMD, 6094.16ft TVD (1615' FNL & 880' FWL, See 18-T12N-R8E) ~ Formation TODS Measured Vertical Depth Depth Northings Eastings Dip Up-Dip Formation Name (ft) (ft) (ft) (ft) Angle Dirn. 1625.24 1546.10 ,,424.40 N 374.35 W 0.000 359.817 Base Permafrost 2180.74 2011.10 220.24 N 662.74 W 0.000 359.817 Top West Sak 2712.34 2456.10 311.95 N 938.72 W 0.000 359.817 Base West Sak 2965.60 2668.10 355.65 N 1070.19 W 0.000 359.817 C-80 (K-10) 4650.00 4078.10 646.24 N 1944.65 W 0.000 359.817 C-40 (K-3) a 5953.38 5196.10 5140.00 856.04 N 2575.94 W 0.000 359.817 Top Morraine 6254.8 5481.10':>' 5425.00 886.87 N 2668.71 W 0.000 359.817 Top HRZ :I">j 6466.9 5687.10 5631.00 902.82 N 2716.72 W 0.000 359.817 Base H RZ 6576.86 5795.10 5739.00 909.18 N 2735.85 W 0.000 359.817 K-1 -.'''' 6647.69 5865.10 5809.00 912.58 N 2746.10 W 0.000 359.817 Kuparuk ~. ~'. 6678.99 5896.10 5840.00 913.96 N 2750.24 W 0.000 359.817 Miluveaeh ~':I;~~ f..~- r--- 26 September, 2002 -10:50 Page 50t8 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-18 Plan - 3S-18 (wp03) Western North Slope Casina details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> 6879.00 2866.00 6094.16 2584.73 Taraets associated with this weJ/lJath Target Name 3S-18 (DD) CJ '""" i"--"'-> 26 September, 2002 -10:50 ConocoPhiJ/ips Casing Detail 7" Casing 9 5/8" Casing --- Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 5868.10 912.72 N 2746.50 W Polygon Drillers ea Level/Global Coordinates: 5812.00 5994800.00 N 473367.00 E Geographical Coordinates: 700 23' 48.8305" N 150013'00.1939" W Target Boundary Point #1 5868.1 0 1039.85 N 2742.61 W #2 5868.10 1036.42 N 2718.10 W #3 5868.10 1028.93 N 2694.61 W #4 5868.10 1017.49 N 2672.61 W #5 5868.10 1002.25 N 2652.52 W #6 5868.10 983.25 N 2634.94 W #7 5868.10 960.66 N 2620.65 W #8 5868.10 934.82 N 2610.93 W #9 5868.10 906.89 N 2608.48 W #10 5868.1 0 879.24 N 2613.85 W #11 5868.10 853.54 N 2625.38 W #12 5868.1 0 832.13 N 2643.36 W #13 5868.10 816.63 N 2666.12 W #14 5868.10 806.37 N 2690.84 W #15 5868.1 0 801.00 N 2716.34 W #16 5868.1 0 800.17 N 2741.84 W #17 5868.10 803.70 N 2766.77 W #18 5868.1 0 811.41 N 2790.60 W #19 5868.10 823.14 N 2812.82 W #20 5868.10 838.70 N 2832.94 W #21 5868.10 857.92 N 2850.38 W #22 5868.10 880.58 N 2864.39 W #23 5868.1 0 906.33 N 2873.79 W Page 6 of8 DrillQuest 3.03.02.002 ~' Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-18 Plan - 35-18 (wp03) ConocoPhillips Western North Slope #24 5868.10 2875.90 #25 5868.10 2870.32 #26 5868.10 2858.62 #27 5868.10 2840.45 W #28 5868.10 2817.61 W #29 5868.10 2792.97 W #30 5868.10 2767.73 W #31 5868.10 2742.61 W Mean Sea Level/Global Coordinates #1 581 .12 N 473371.30 E #2 5 5 .61 N 473395.80 E #3 5812.00 5994916.05 N 473419.26 E #4 5812.00 5994904.54 N 473441.23 E '-.-" 5 5812.00 5994889.23 N 473461 .27 E "wiP,~5812.00 5994870.18 N 473478.79 E 5812.00 5994847.54 N 473493.00 E #8 5812.00 5994821.67 N 473502.64 E #9 5812.00 5994793.73 N 473505.00 E #10 5812.00 5994766.10 N 473499.54 E #11 5812.00 5994740.44 N 473487.93 E #12 5812.00 5994719.08 N 473469.88 E #13 5812.00 5994703.66 N 473447.07 E #14 5812.00 5994693.48 N 473422.32 E #15 5812.00 5994688.19 N 473396.80 E #16 5812.00 5994687.44 N 473371 .30 E #17 5812.00 5994691 .05 N 473346.38 E #18 5812.00 5994698.83 N 473322.58 E #19 5812.00 5994710.63 N 473300.39 E #20 5812.00 5994726.26 N 473280.32 E #21 5812.00 5994745.53 N 473262.95 E #22 5812.00 5994768.24 N 473249.01 E #23 5812.00 5994794.02 N 473239.69 E #24 5812.00 5994821.83 N 473237.67 E #25 5812.00 5994849.36 N 473243.34 E ~~ #26 5812.00 5994874.87 N 473255.12 E a #27 5812.00 5994896.05 N 473273.36 E #28 5812.00 5994911 .30 N 473296.25 E ~,-.>- #29 5812.00 5994921.28 N 473320.92 E -t.. _. #30 5812.00 5994926.42 N 473346.17 E !:: #31 5812.00 5994927.12 N 473371.30 E - Geographical Coordinates #1 700 23' 50.0809" N 1500 13' 00.0812" W """'. #2 700 23' 50.0473" N 1500 12' 59.3631" W #3 700 23' 49.9737" N 1500 12' 58.6751" W r--- #4 70023' 49.8613" N 1500 12' 58.0303" W #5 70023' 49.7114" N 150012' 57.4417" W #6 700 23' 49.5247" N 1500 12' 56.9264" W #7 700 23' 49.3025" N 1500 12' 56.5078" W 26 September, 2002 - 10:50 Page 70f8 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-18 Plan - 35-18 (wp03) #24 #25 #26 #27 #28 #29 #30 #31 70° 23' 49.0484" N 150° 12' 56.2227" 70° 23'48.7736" N 150<' 12'56.1507" 70° 23' 48.5017" N 150° 12' 56.3078u 70° 23' 48.2489" N 150° 12' 56.6452" W 70° 23' 48.0382 150° 12' 57.1717" W 70° 150° 12' 57.8383" W 70 1 ' 2' 58.5623" W 70 l' 59.3093" W 70° "N 150° 13' 00.0562" W 70° 81" N 150° 13' 00.7866" W 70° 23 38" N 150° 13' 01.4846" W 0° 23' 47. 491" N 150° 13' 02.1358" W 70° 23' 48.1021" N 1500 13' 02.7254" W 70° 23' 48.2911" N 150° 13' 03.2363" W 70° 23' 48.5139" N 150° 13' 03.6470" W 70° 23' 48.7672" N 150° 13' 03.9227" W 70° 23' 49.0406" N 150° 13' 03.9848" W 70° 23' 49.3116" N 150° 13' 03.8216" W 70° 23' 49.5629" N 150° 13' 03.4792" W 70° 23'49.7719" N 150° 13' 02.9471" W 70° 23' 49.9227" N 150° 13' 02.2781" W 70° 23' 50.0217" N 150° 13' 01.5565" W 70° 23' 50.0732" N 150° 13' 00.8173" W 70° 23' 50.0809" N 150° 13' 00.0812" W ConocoPhillips Western North Slope 3S-18 (Geo) .~ Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 5868.1 0 5812.00 912.72 N 2746.50 W 5994800.00 N 473367.00 E 700 23' 48.8305" N 1500 13' 00.1939" W Circle Geological 150.00ft '~. c::r f "",. """ 26 September, 2002 - 10:50 Page 8 of8 DrillQuest 3.03.02.002 ~. ~-F;' ~..< .....,; r ~.,>,ç-¡ un ... spell..,\!- DR'L L iN G 5 E R V J. c' E 5 ^ lt~Mí~ ';;~P1JA)' 0-'" . ----SHL (2538' FNL & 1149' FEL, SEC. 18- T12N - R8E) ~ Begin Dir @ 2.5"/10Oft (in 12-1/4" Hole): ¡,¡;>'f' 260.0011 MD, 260.0011 TVD ~ 1000 - End Dir, Start Sail @ 33.17": 1586.6311 MD, 1513.7811 TVD 2000 -h;ï;'iF;~.:ï .~':~Á'. ::J (J) :iE ~~ -3000 I -2500 I Total Depth: 6879.000 MD, 6094.16ft TVD (1615' FNL & 880' FWL, See 18-T12N-R8E) Scale: 1 inch = 500ft 1000 - 500 - .L".iS iDrílkr's 586'1. ¡ [I TVD, 0-......... -2000 I -1500 I -1000 I -500 I Eastings 0 I i I I I ¡ I - 1000 rn C> c :c 1:: 0 Z - 500 . . . I Begin Dlr @ 2.5"/10Oft (In 12-1f4" Hole): 260.00ft MD, 260.00ft TVD I .u~...u ""', ................--" ...................' ..... ~......m""'m .... "''''''''''''''''''''' ...." .......m.......... ..... """'''''''''''''' .........w........ ..... ..................... .... '.""""""""" , -3000 I -2500 9-5/8' Csg 2866.00' MD 2584.73' TVD ~~ ~~ 9'5/:CS9 pt ... Drill out 8-1/2" Hole : 2866.00ft MD, 2500.98ft TVD :"';r¡i(¡¡:-¡ u7; ""Yo'o~"""""""""""~"""" <Ö It) II CD ~ f£ ~ õ.. OJ 0 «i 0 'e Q) > 3000 - 4000 - ""''^''''''--~-~'''''^'"''^''~~~'''''^ 5000 - ~ § II .!: ~ i:';i;7ïi{~:. ~- ~~ ~-.....-..~ ""'^' ~ -. -~~..,. ~ ^""" ~,.~ ~ Q; 13 rn ~~~~~~~~~~-~~~ ...,."............. .... ..................,. ".. ".,,,.............. .... .....,............. ..., ...............,.... ..., ....m.m......... n... . 6000 - , 0 , 1000 , 2000 I 3000 Total Depth: 6879.0011 MD, 6094.16ftTVD (1615' FNL & 880' FWL, See 18-T12N.R8E) RKB Elevation: North Reference: Units: 56.10ft above Mean Sea Level True North Feet (US) Scale: 1 inch = 1000f! Drill Quest 3.03.02.002 7' Csg 6879.00' MD 6094.16' TVD , -2000 I -1500 I -1000 SHL (2538' FNL & 1149' FEL, SEC. 18- T12N - R8E) I -500 I 1"''''''''''''''''''-0 I 0 ~ ConocoPhi II ips Western North Slope, Alaska Kuparuk River Unit 35 Pad 35-18 (wp03) Reference is True North Well: Current Well Properties 3S-18 Plan , I I I I I ! i ! ï~'I>.\I<;;:"f;¡;;", S¡,,,;Ti;- --- - - - - - - - - - -- - ~ ~ TAF":)P: ~;!,,~j,;,,¡' Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 5993878.51 N, 476110.57 E 34.41 N, 344.54 W 70023' 39.8581" N, 1500 11' 39.7374"W 2538' FNL & 1149' FEL, SEC. 18- T12N - R8E Approved Plan ( 03) -~ Phillips Alaska, Inc. 3S-18 MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment (It) (Deg) (Deg) (It) (It) (ft) (ft) (ft) (ft) e/100ft) (ft) 0.00 0.00 0,00 -56.10 0,00 0.00 N 0.00 E E}[j93878.51 N 47611057 E 0,00 0.00 SHL \~ 260.00 0.00 0.00 203.90 260.00 0.00 N 0.00 E 5993878.51 N 476110.57 E 0.00 0.00 Begin Dir in 12-1/411 Ho!e 1586.63 33.17 288.38 1457.67 1513.77 117.74 N 354.31 W 5993997.39 N 475756.64 E 2.50 373.36 End Dír; Start Sail 1625.24 33.17 288.38 1490.00 1546.1 0 124.40 N 374.35 W 5994004.11 N 475736.62 E 0.00 394.48 Base Permafrost 2180.74 33.17 288.38 1955.00 2011.10 220.24 N 662.74 W 5994100.87 N 475448.54 E 0.00 698.37 Top West Sak 2712.34 33.17 288.38 2400.00 2456.10 311.95 N 938.72 W 5994193.46 N 475172.86 E 0.00 989.19 Base West Sak 2866.00 33.17 288.38 2528.63 2584.73 338.46 N 1018.49 W 5994220.23 N 475093.17 E 0.00 1073.25 9-5/811 Csg Pt ... Drill 8-1/211 Ho!e 2965.60 33.17 288.38 2612.00 2668.10 355.65 N 1070.19 W 5994237.58 N 475041.52 E 0.00 1127.74 C-80 (K-1 0) 4650.00 33.17 288.38 4022.00 4078.10 646.24 N 1944.64 W 5994530.97 N 474168.00 E 0.00 2049.21 C-40 (K-3) 5392.43 33.17 288.38 4643.48 4699.58 774.33 N 2330.08 W 5994660.28 N 473782.98 E 0.00 2455.37 Begin Drop @ 2.0°/1 OOft 5953.38 21.95 288.38 5140.00 5196.1 0 856.04 N 2575.95 W 5994742.78 N 473537.37 E 2.00 2714.46 Top Morraine 6254.82 15.92 288.38 5425.00 5481 .1 0 886.87 N 2668.71 W 5994773.90 N 473444.70 E 2.00 2812.22 Top HRZ 6466.99 11.68 288.38 5631.00 5687.10 902.82 N 2716.72 W 5994790.01 N 473396.75 E 2.00 2862.80 Base HRZ 6576.86 9.48 288.38 5739.00 5795.10 909.18 N 2735.85 W 5994796.43 N 473377.64 E 2.00 2882.97 K-1 6647.69 8.06 288.38 5809.00 5865.10 912.58 N 2746.10 W 5994799.87 N 473367.40 E 2.00 2893.76 Kuparuk / 6650.72 8.00 288.38 5812.00 5868. '1 0 912.72 N 274650 \^J 5994800.00 N .00 E 2.00 2894.'1 9 TARGET: Start Sail @ 8.00 ~I 6678.99 8.00 288.38 5840.00 5896.10 913.96 N 2750.24 W 5994801.25 N 473363.27 E 0.00 2898.12 Miluveach 6879.00 8.00 288.38 6038.06 6094.16 922.74 N 2776.65 W 5994810.12 N 473336.88 E 0.00 2925.96 Total Depth a =r:"~' -. r:' ~ ~;;.., .&.:..,; - '.' r-- ') Sperry-SUD Anticollision Report ) qnripäÏlY: Field: RêfërenceSite: RefërënceWeU: R~féTenceWellpalh: PhillipsAlaskalnç; KIJPélrukF\iYerUnit Kupa,ruk~$ pad Plan:3S~18 Plâh:3S~18 9/26/2002 W~II:BI;1n:3S"18; Grid Nórth 56J56~ 1 (Jo~ördin~~e(NE).Ret;~fêricê: y ertiCal (TYI»Ref~ITèl)ée: GLOBAL SCAN APPLIED: All wellpaths within 200'+ 10011000 of reference Interpolation Method: MD Interval: 50.000 ft Depth Range: 28.100 to 6879.000 ft Maximum Radius: 885.090 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 5/15/2002 Validated: No Planned From To Survey ft ft 28.100 500.000 500.000 6879.000 Version: Toolcode 3 Tool Name Planned: 3S-18 (wp03) V7 Planned: 3S-18 (wp03) V7 CB-GYRO-SS MWD Camera based gyro single shot MW D - Standard Casing Points MD TVD ft ft 2866.000 2584.682 6879.000 6094.004 Diameter in 9.625 7.000 12.250 8.500 9-5/8" 7" Summary <.~..;.:._~---~~----~--..;.:..:.~ Offset Wellpath . ---_':'':'':'':'':'.._--.-____m> Réfërerice Offset Ctr~Ctr No-Go Allowable Sitë Well Wellpäth MD MD Distance Area Dêviätiön Warning ft ft ft ft ft Exploration 2001 Palm 1 Palm 1 WP01 V1 Plan: P 1065.290 1050.000 83.274 No Offset Errors Kuparuk 3S Pad 3S-26 3S-26 V1 1011.616 1000.000 85.766 16.689 69.080 Pass: Major Risk Kuparuk 3S Pad 3S-26 3S-26a V1 1011.616 1000.000 85.766 16.689 69.080 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-07 Plan: 3S-07 V3 Plan: 3 296.972 300.000 220.284 5.580 214.704 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-08 Plan: 3S-08 V2 Plan: 3 249.996 250.000 200.440 5.233 195.207 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-08 Plan: 3S-08F V2 Plan: 249.996 250.000 200.440 5.233 195.207 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-09 Plan: 3S-09 V1 Plan: 3 249.997 250.000 180.355 5.388 174.967 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-10 Plan: 3S-10 V1 Plan: 3 249.997 250.000 160.250 5.409 154.841 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-10 Plan: 3S-1 OF V3 Plan: 249.997 250.000 160.250 5.409 154.841 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-14 Plan: 3S-14 V1 Plan: 3 298.835 300.000 80.406 6.298 74.107 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-15 Plan: 3S-15 V1 Plan: 3 348.042 350.000 60.152 7.297 52.856 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-16 Plan: 3S-16 V1 Plan: 3 397.975 400.000 40.628 8.045 32.588 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-17 Plan: 3S-17 VO Plan: 3 498.404 500.000 19.990 9.918 10.097 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-17 Plan: 3S-17F V1 Plan: 498.404 500.000 19.990 9.856 10.160 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-19 Plan 3S-19F V2 Plan: 3 804.410 800.000 23.821 14.664 9.824 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-19 Plan: 3S-19 V1 Plan: 3 804.410 800.000 23.821 14.664 9.824 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-20 Plan: 3S-20 V1 Plan: 3 249.997 250.000 40.366 5.021 35.345 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-21 Plan: 3S-21 V1 Plan: 3 861.603 850.000 56.184 15.674 41.244 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-21 Plan: 3S-21 F V2 Plan: 861.603 850.000 56.184 15.674 41.244 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-22 Plan: 3S-22 V2 Plan: 3 557.591 550.000 82.514 9.599 72.988 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-23 Plan: 3S-23 V1 Plan: 3 664.625 650.000 96.136 12.107 84.255 Pass: Major Risk Kuparuk 3S Pad Plan: 3S-24 Plan: 3S-24 V1 Plan: 3 616.119 600.000 123.576 11.346 112.371 Pass: Major Risk OR¡(;ud L a ::0 ~~ ~.~ ~ ...,ø ~:""-'-~~~ ~,. L-~t~ r--- WHJ. DETAILS ANTI-COLLISION 5ETI1NGS InterpoJation Method:MD Interval: 50.O<X) Depth Range From: 28.10<) To: 6879.000 Maximum Range: 885.090 Reference: Plan: 35-18 (wp03) Origin +FJ-W Starting From TVD From Colour ToMD Tool 0 ~ 200 200 ~ 400 CB-GYRO-SS 400 - 600 600 800 MWD 800 - 1000 1000 ~~ 1200 1200 - 1400 1400 - 1600 1600 1800 1800 - 2000 2000 2500 2500 - 3000 -36 3000 3500 3500 - 4000 4000 - 5000 5000 - 6000 -30 6000 ~ 7000 7000 ~ 8000 8000 - 9000 """20 Name +NI.S Northing Eusting wngiludc Sk)t Latitude +E/.W Plan: 3S.IH 3~.514 .344.464 ~993H7H.51 4761 ().~7 70"23'39.H~HN 1~(J"11'39.737W N/A SURVEY PROGRAM Depth Fm Depth To Survey/Plan 28.100 500.000 Planned: 3S-18 (wp03) V7 500.000 6879.000 Planned: 3S-18 (wp03) V7 -174 -150 """100 -50 - 0 270 -50 ''''''100 -150 -174 38-18 (wp03) Approved Plan TravelIing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] COMPANY DETAILS WELLPATH DErAILS Plan: 3S-18 Phillips Alaska Inc. Engineering Kuparuk Cakulation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Waming MctI"d: Rulos Based Rjg: Ref. Datum: N7ES 56.1 ~6.1()()ft V,Section Angle 288.57" Origin +NI.S O.noo O.(J(X) O.(J()() Colour 0 Jo6 .~' -10 90 .~ -30 -36 18<16 SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee Target I 28.100 0.00 288.57 28.100 0.000 0.000 0.00 0.00 0.000 2 260.000 0.00 288.57 260.000 0.000 0.000 0.00 288.57 0.000 3 1586.773 33.17 288.57 1513.895 118.899 -354.003 2.50 0.00 373.437 4 5392.410 33.17 288.57 4699.432 781.828 -2327.770 0.00 0.00 2455.559 5 6650.876 8.00 288.57 5868.1 00 921.582 -2743.843 2.00 180.00 2894.475 3S (18) 6 6879.000 8.00 288.57 6094.004 931.692 -2773.938 0.00 0.00 2926.224 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ft/in] ) Target: 3S (18) ) Well:Plan: 3S-18 Based on: Plan: 3S-18 (wp03) Vertical Depth: 5812.00 ft below Mean Sea Level Local +N/-S: 921.58 ft Local +E/-W: -2743.84 ft Longitude: 150013'00.194W Radius: 150 ft Site: Kuparuk 3S Pad Drilling Target Conf.: 75% Description: Map Northing: 5994800.00 ft Map Easting : 473367.00 ft Latitude: 70023'48.830N Shape: Circle , " III! tlllll, "llllll,t,I, 1III,l!II:!I~I!I, 111'1 21QOh:21ztO-2720 -21Gq -2~8~-2~QO - -,1"...1.1 '1-; ;--'--'I-¡:;:I;' :i:lk~~1¡' OF;;; .ri¡tt;!¡ j , T,',"""" ,: ""', ,,',"',., ,," , "",..,'-""" ,,:'iL ," :I:f:: I I J I 1111l!11 III, ,1,1, -2~8Q -2~fiQ 'I'r:,:"'" ì ' . ~ ' . .I. 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" ., ., ., i, '" .", ..."""..."." .., ."'. ."",.,.,..,...",.,.,.'".." ."" .., " í """'°- cp ~5-18'i< i-. .'... ...... ...; i~~~~~~i'---l-.4- .: 0 3 ¡, ,Q 0 ¡, It It. :¡¡¡'BOOQO 1t¡¡'¡'2!ï?'Y"'¡'fjOi:l ~ d i' RECEIVED OCT 0 1.2002 __Ie.Gons. GommtssiOn . Anchorage ') i TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~)fL1 - ~,r-/~ PTD# .2 02 - ;:;> ~ c::: CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 ajody\templates "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. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiatêd 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). : 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 COMPANy.f//j¡/,þr WELLNAME!<£4. .?S....J~ PROGRAM: Exp- DevX Redrll- Re-Enter- Serv- Wellboreseg- FIELD & POOL 0/ 'OÐ,Ç ÞJ Q:3 INIT CLASS /'),.JV l'ð~1 GEOL AREA ? 1 r:) UNIT# II I b (S ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Œ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N .:t £1/- ¿ rr /J J I - r 3. Unique well name and number. . . . . . . . . . . . . . . . . Y tJ.. >1 / ~ -? /j' ~Þ1'.I /.//li-'f/e-:t"A.Jp.....Þ' J£b;7dÒ.., ^) 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . ~ ...tJ . )./ /) / ï I 5. Well located proper distance from drilling unit boundary.. . . ('!, ~ /PJr'i /::/ U k4j:)e:/þ, fJ:. /'\ l2JP/ a ¡;~ 6. Well located proper distance from other wells.. . . . . . . . . . Y N r-) / _1) J J/ . ) / I J 7. Sufficient acreage available in drilling unit.. . . . . . , . . . . Y N /Ã-c.. ~~)I /..) ,"'" - "1fl~~'" ,i1' (-£/ITI/) t.)7ð 7'Þ- u...Ä c.l~ YPiJ 5. 1... ),/.. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N bn I /f>r- ~Z- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N /f r.¿, 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N l' 2. Permit can be issued without administrative appr,oval.. . . . . , ~\!í, , N ,', LÎ (Service Well Only) 13. Well located w/in area & strata authorized by injection order#~ Y /V" '7. (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. Y. N ' ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y 16. Surface casing protects all known USDWs. . . . . . . . . . . . N ~}.~ .L- 17. CMT vol ádeqUa, te, to C, ircu late on conductor & surf csg. . . ,. . ì!12, N,' f\Q.£t 1\ ~ e,t.œ~ ( , 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . V 19. CMT will cover all known productive horizons. . . . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . .. . . . N t 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .. N ^', ()yC; '1 GS 22. If a re-drill, has a 10-403 for abandonment been approved. . . "¥--N"- '" ¡. 23. Adequate wellbore separation proposed.. . . . . . . .. . . . lf2 N 24. If diverter required, does it meet regulations.. . . . . . . . . N /1/J t, I, 1 25. Drilling fluid program schematic & equip list adequate. . . . . N ¡1J1ß..1t " t IAÃ I I '5. f P'1 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N, D ~ APPR DATE 27. BOPE press rating appropriate; test to 5"00<.9 psig. N /US, 1,ß¡C¡<;, fSv, . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \¡J4P;- 015/0 L- 29. Work will occur without operation S,h,utdown. . . . . . . . . . . ' ~ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . (b!! . 31. Mechanical condition of wells within AOR verified. . . . . . . . .¥-N At/It- @N ~A t<J.~. Y N Y. N APPR DATE (Service Well Only) GEOLOGY APPR DATE #y. /Ö¡jþ7 ,p (Exploratory Only) 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . \ r GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP~/r ~ TEM JDH JBR COT DTS ¡I/'? It') <- / MJW M. r..ï!J o/.r/o z.. SFD WGA Rev: 07/12/02 - G:\geoJogy\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically., . organize this category of information. 7 ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLìb $Revìsìon: 4 $ Mon Jun 02 13:47:11 2003 Reel Header Service name.............LISTPE Date. . . .. . . . . .. . . . . . . . .. . 03/ 06/ 02 Or i gin. . . . . . .. . . . . . . . . . . . . ST S Reel Name................ UNKNOTfJN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name.............LISTPE Date.....................03/06/02 Origin...................STS Tape Name................ UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS # NELL NAME: API NUMBER: OPERATOR: LOGGING COMP.ANY: TAPE CREATION DATE: # ,JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22183 P. ROGER M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FÍ'>JL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD ~O~-:<Ofo 1 \ lPL.3 Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 3S-18 501032043300 Conoco Phillips Sperry Sun 15-APR-03 MWD RUN 2 AK-MW-22183 P. ROGER M. THORNTON MWD RUN 3 AK-MW-22183 P. ROGER M. THORNTON 18 12N 8E 2538 1149 .00 56.27 27.70 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 108.0 8.500 9.625 2840.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. Mt^JD RUN 1 í^JÞ.S DIRECTIONÞ.L í^JITH DUl\.L GÞJv11.Æ.]J. RP\.Y (DGR) ') ) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUNS 2-3 WERE DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4); STABILIZED LITHO-DENSITY (SLD); COMPENSATED NEUTRON POROSITY (CNP); AND PRESSURE WHILE DRILLING (P~-m). 5. DATA FOR MWD RUN 2 ,ARE PULSED (REAL-TIME) DATA DUE TO A TOOL FAILURE. 6. MWD DATA ARE CONSIDERED PDC PER GKPA GEOSCIENCE GROUP. 7. WflD RUNS 1-3 REPRESENT WELL 3S-18 i'nTH API # 50-103-20433-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6900' MD I 611 9' TVD. SROP = SMOOTHED R~TE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SEDP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SPSF = SMOOTHED NEUTRON POROSITY (S.~DSTONE MATRIX, FIXED HOLE SIZE) PARAMETERS USED IN NEUTRON I POROSITY LOG CALCULATIONS: HOLE SIZE: 8.5ft MUD WEIGHT: 9.5 - 12.2 PPG MUD FILTRATE SALINITY: 200 - 350 PPM CHLORIDE FORMATION WATER SALINITY: 22000 PPM CHLORIDE FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/06/02 Maximum Physical Record..65535 Fi I e T~'Pe................ 1,0 Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE Sillv~~RY PBU TOOL CODE GR ROP clipped curves; all bit runs merged. .5000 START DEPTH 52.0 109.5 STOP DEPTH 6862.0 6900.0 ) ) NPHI 2769.5 6809.0 NCNT 2769.5 6809.0 FCNT 2769.5 6809.0 RPS 2784.0 6854. 0 RPD 2784.0 6854.0 FET 2784.0 6854.0 RHOB 2843.0 6818.5 DRHO 3505.5 6818.5 PEF 3505.5 6818.5 RPX 3540.5 6854.0 RPM 3540.5 6854.0 $ # BÞ.SELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ if HERGED PBU lVl1ii1D MWD Ivß~D $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 52.0 2 2769.5 3 3495.5 MERGE BASE 2855.0 3586.0 6900.0 # REMARKS: MERGED MAIN PASS. $ if Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log dept,h unit,s........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record..............Undefined Absent value...................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP HWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHHM 4 1 68 12 4 RPS MWD om-1M 4 1 68 16 5 RPM ]\1í''JD OHMM 4 1 68 20 6 RPD HWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 N PHI !v1V'JD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB IvßIiJD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF Ivß"lD BARN 4 1 68 52 14 First Last Name Service Unit Hin Hax Hean Nsam Reading Reading DEPT FT 52 6900 3476 13697 52 6900 ROP MWD FT/H 0.81 1161.75 166.605 13582 109.5 6900 GR MWD API 18.26 410.81 97.9457 13621 52 6862 RPX MI'JD 0 Hl'1M 0.52 281.2 3.90861 6628 3540.5 6854 RPS HV'JD OHMM 0.54 2000 4.77672 8141 2784 6854 RPH ì'-'IWD OHMM 0.49 172.9 3.79101 6628 3540.5 6854 RPD MI^JD OHMM 0.43 2000 23.1384 8141 2784 6854 FET MWD HOUR 0.1167 53.4814 1.98574 8141 2784 6854 NPHI MwD PU-S 14.68 89.68 49.4762 8080 2769.5 6809 FCNT MV'm CNTS 412 1187 585.722 8080 2769.5 6809 NCNT MWD CNTS 2118 3962 2589.1 8080 2769.5 6809 RHOB l\ÆT...7T"\ G/CN 1.627 2.86 2.31628 7928 2843 6818.5 .i.l~.~ L' DRHO MWD G/CH -0.084 0.348 0.0741808 6627 3505.5 6818..5 PEF IvfviID BARN 2.15 16.64 4.64131 6627 3505.5 OöJ..t\.::J ) First Reading For Entire File..........52 Last Reading For Entire File...........6900 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 File T:ype............... .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number .... . . . . . . .1.0.0 Date of Generation.......03/06!02 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUI-1MARY VENDOR TOOL CODE START DEPTH GR 52.0 ROP 109.5 $ 2 ) header data for each bit run in separate files. 1 .5000 STOP DEPTH 2'797 .5 2855.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MFI...XIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S Cl-\SING DEPTH (FT): # BOREHOLE CONDITIONS HUD TYPE: HUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: HUD CHLORIDES (PPH): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEHPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT Ml-\.i'Z CIRCUL.P.TING TERlV1PERl\TURE: 24-NOV-02 Insite 4.3 Memory 2855.0 52.0 2855.0 .0 35.7 TOOL NUMBER 077114 12.250 108.0 SPUD MUD 9.50 123.0 9.4 325 5.1 .000 .000 .0 77.0 ) MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .0 .0 If. NEUTRON TOOL I'1ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): If. TOOL STANDOFF (IN): EWR FREQUENCY (HZ): If. REM.I\RKS : $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Ty~e.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefìned Absent value...................... -999 Depth Uni "ts . . . . . . .. . . .. .. . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOIO FTIH 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 52 2855 14 53.5 5607 52 2855 ROP MWD010 FT/H 13.12 1161. 75 172.838 5492 109.5 2855 GR MWD010 API 18.26 123.65 70.9226 5492 52 2797.5 First Reading For Entire File..........S2 Last Reading For Entire File...........2855 File Trailer Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name...............STSLIB.OO3 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit ruû iû separate BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUNHARY 3 files. ) VENDOR NCNT FCNT NPHI RPS RPD FET GR RHOB ROP $ TOOL CODE START DEPTH 2769.5 2769.5 2769.5 2784.0 2784.0 2784.0 2792.0 2843.0 2855.5 STOP DEPTH 3495.5 3495.5 3495.5 3540.5 3540.0 3540.0 3548.0 3505.0 3586.0 If LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOJÆ SOFT1ivARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: IvlJ0CIMUM ANGLE: If TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 GNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA MY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPEMTURE (DEGF) MUD AT MEASURED TEMPEMTURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTMTE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MA.TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EIATR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record T1~e..................0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing......................60 .1IN Max frames per record.............Undefined .;;bsent value...................... -999 Depth Units......................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code ) 27-NOV-02 Insite 66.37 Memory 3586.0 2855.0 3586.0 30.5 34.9 TOOL NUMBER 124724 151812 066017 126970 8.500 2840.0 LSND 9.50 53.0 9.0 300 5.4 2.800 3.120 2.300 3.100 72.0 64.0 72.0 72.0 Offset Channel ') ) DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 GR Míi>JD020 }\PI 4 1 68 8 '" -, RPS MWD020 OHMM 4 1 68 12 4 RPD MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 NPHI MWD020 PU-S 4 1 68 24 7 FCNT MWD020 CNTS 4 1 68 28 8 NCNT MWD020 CNTS 4 1 68 32 9 RHOB MVm020 G/CM 4 1 68 36 10 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2769.5 3586 3177.75 1634 2769.5 3586 ROP MWD020 FT/H 14.9 470.56 264. 296 1462 2855..5 3586 GR Mí'fD020 API 54.34 128.61 101. 343 1513 2792 3548 RPS lVfiìiID020 OHMlVl 2.44 2000 9.14491 1514 2784 3540.5 RPD M'Vm020 OHMM 0.79 2000 106.568 1513 2784 3540 FET MWD020 HOUR 0.1167 53.4814 5.3514 1513 2784 3540 NPHI MWD020 PU-S 37.11 65.86 49.3932 1453 2769.5 3495.5 FCNT ¡vn;"fD020 CNTS 412 743 558.788 1453 2769.5 3495.5 NCNT MWD020 CNTS 2216 2792 2544.69 1453 2769.5 3495.5 RHOB MViJDO 20 G/CM 1. 627 2.226 2.09911 1301 2843 3505 First Reading For Entire File..........2769.5 Last Reading For Entire File...........3586 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 File Type.............. ..LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.................STSLIB.OO4 Service Sub Level Name... Version Number-.......... .1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ST~~T DEPTH RPM 3495.5 GR 3495.5 RPS RPD 4 header data for each bit run in separate files. 3 .5000 3495.5 3495.5 STOP DEPTH 6854.0 6862.0 6854.0 6854.0 6854.0 6809.0 6809.0 6818.5 6854.0 6809.0 6818.5 FET FCNT 3495.5 3495.5 NCNT RHOB DRHO 3495.5 3495.5 3495.5 3496.0 3505.5 3505.5 6818.::' RPX NPHI PEF ) ROP $ 3586.5 6900.0 # LOG HEADER DATÞ. DATE LOGGED: SOFTìì'iARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMJ\1A RAY ELECTRO~~G.. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER~TURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Tìlpe.................. 0 Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Þbsent value...................... -999 Depth Units....................... Datum Specification Block sub-t"1'Pe...O ) 30-NOV-02 Insite 66.37 Memory 6900.0 3586.0 6900.0 7.4 34.5 TOOL NUMBER 155790 134760 120156 067985 8.500 2840.0 LSND 12.30 48.0 9.5 600 3.8 2.900 2.040 3.200 5.000 90.0 131. 0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX H'VW030 OHl'1M 4 1 68 12 RPS M'i^TD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD M1^1D030 OHMM 4 1 68 24 7 FET l'-1í~D030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 ') )i \ f E'CNT MV'W030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB HWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3495.5 6900 5197.75 6810 3495.5 6900 ROP Mlim030 FT/H 0.81 326.56 139.892 6628 3586.5 6900 GR MWD030 API 38.04 410.81 119.353 6734 3495.5 6862 RPX Hli\7D030 OHMM 0.52 281. 2 3.89998 6718 3495.5 6854 RPS MWD030 OHl'1M 0.54 189.64 3.7713 6718 3495.5 6854 RPM MWD030 OHMM 0.49 172.9 3.7836 6718 3495.5 6854 RPD MWD030 OHMM 0.43 248.01 4.08407 6718 3495.5 6854 FET MWD030 HOUR 0.221 26.2132 1. 53711 6718 3495.5 6854 NPHI MWD030 PU-S 14.68 89.68 49.4944 6627 3496 6809 FCNT t<1WD030 CNTS 434 1187 591. 622 6628 3495.5 6809 NCNT MWD030 CNTS 2118 3962 2598.82 6628 3495.5 6809 RHOB MW"D030 G/CM 2.13 2.86 2.35847 6647 3495.5 6818.5 DRHO Iv1WD030 G/CM -0.084 0.348 0.0741808 6627 3505.5 6818.5 PEF Mí^JD030 BARN 2.15 16.64 4.64131 6627 3505.5 6818.5 First Reading For Entire File..........3495.5 Last Reading For Entire File...........6900 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/06/02 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name........ - -.. .LISTPE Date.....................03/06/02 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name_-_.__-_.__._LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/06/ 02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNO~rn Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File