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Home My WebLink About202-221 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 202-221/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 202-221/ 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: 23. BOTTOM 16" H-40 108' 9.625" L-80 2556' 7" l-80 6161' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 30.7 bbl , 15.8 ppg Class G, above cmnt retainer, 1 bbl above retainer Flow Tubing 6106'-6245' (Tubing) 6245'-6700' (PC) PLUGGED AND ABANDONED 4477-4501' MD and 4016-4037' TVD (cemented) 4503-4543' MD and 4039-4074' TVD (cemented) 4545-4585' MD and 4076-4112' TVD (cemented) 4587-4627' MD and 4114-4149' TVD (cemented) 6560-6600' MD and 5868-5905' TVD (cemented) Gas-Oil Ratio:Choke Size: 30.7 bbl, 15.8 ppg Class G below cmnt retainer, 1 bbl above retainer Per 20 AAC 25.283 (i)(2) attach electronic information If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 4477-4627' (PWC) 71 bbl 15.8 ppg Cement (milled) Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 6880' SIZE DEPTH SET (MD) 26'26' 1626' MD/ 1541' TVD N/A 6214' MD/ 5554' TVD PACKER SET (MD/TVD) 42" 12-1/4" 9 cu yds High Early 29'570 sx AS & 250 sx LiteCrete 30' 2809'29' 30' ALK 4623 50-103-20439-00-00 KRU 3S-14 December 18, 2002 December 23, 2002 9. Ref Elevations: KB: 28' Kuparuk River Field/ Kuparuk River Oil Pool (Plugged and Abandoned) WT. PER FT.GRADE CEMENTING RECORD 5996637 SETTING DEPTH TVD 5996769 TOP HOLE SIZE AMOUNT PULLED 475704 475674 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 6246' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 1/18/2024 202-221/323-238 2519' FNL, 1071' FEL, Sec. 18, T12N, R8E, UM 351' FSL, 1595' FEL, Sec. 7, T12N, R8E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476188 5993897 220' FSL, 1555' FEL, Sec. 7, T12N, R8E, UM Surface/Surface 6895' MD/ 6175' TVD ADL0380106, ADL0380107 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 246 sx Class G w/ GasBlok8-1/2" 62.5# 40# 108' 3514-4569' (PC) 40 bbl 15.8 ppg Class G, above fish 38-3514' (PC) 160 bbl 15.8 ppg Class G cement to surface 38-2809' (OA) 104 bbls 15.8 ppg Permafrost cement w/ Bridgemaker in 1st 52 bbls OA Cement Top Job 6.5 bbl Cement ACID, FRACTURE, CEMENT SQUEEZE, ETC. Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment USIT/DSLT 8/9/2023; IBC/DSLT 12/20/2023 By James Brooks at 3:12 pm, Feb 05, 2024 Abandoned 1/18/2024 JSB RBDMS JSB 020824 xG Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1626' 1541' 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. TPI (Top of Producing Interval). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Formation Name at TD: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Plugged and Abandoned Authorized Name and INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Plugged and Abandoned Authorized Title: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2024.02.05 14:51:11 -09'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 3,481.0 3S-14 12/26/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason:P&Ad with 30" marker plate 9' below Original ground (Tundra) AOGCC WITNES BOB NOBLE 3S-14 1/18/2024 mouser Notes: General & Safety Annotation End Date Last Mod By NOTE:P&Ad with 30" marker plate 9' below Original ground (Tundra) AOGCC WITNESSED BOB NOBLE 1/18/2024 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 38.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 38.0 2,808.6 2,556.1 40.00 L-80 BTC PRODUCTION 7 6.28 38.0 6,879.8 6,161.4 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.0 Set Depth … 6,245.7 Set Depth … 5,583.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD 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) 496.0 495.4 6.56 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 6,113.0 5,464.4 26.90 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.992 6,158.9 5,505.4 26.59 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 6,197.2 5,539.6 26.30 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT) 3.500 6,199.2 5,541.4 26.28 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.970 6,212.9 5,553.7 26.14 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,213.8 5,554.5 26.13 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 6,218.7 5,558.9 26.08 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.730 6,237.8 5,576.1 25.89 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,244.8 5,582.4 25.82 WLEG 4.520 WLEG w/ SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 38.0 38.0 0.06 MARKER PLATE 30" 1/4" thick P&A marker plate 1/18/2024 0.000 4,596.0 4,121.6 26.94 FISH COIL TUBING UNDERREAM ASSEMBLY 24.95' OAL. 12/18/2023 0.000 4,652.3 4,171.8 26.95 PLUG 7" CAST IRON BRIDGE PLUG MID-ELEMENT AT 4653', OAL 1.95' BAKER HUGHE S 3BB / 7" 20# - 38# ACT2 2- 2212 8/25/2023 0.000 6,234.0 5,572.7 25.93 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER, W/ 2.79 NG RING 5/9/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,113.0 5,464.4 26.90 1 GAS LIFT DMY RK 1 1/2 0.0 1/30/2003 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,477.0 4,501.0 4,015.7 4,037.0 8/26/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 4,503.0 4,543.0 4,038.8 4,074.4 8/26/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 4,545.0 4,585.0 4,076.2 4,111.8 8/26/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 4,587.0 4,627.0 4,113.6 4,149.2 8/26/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 6,560.0 6,570.0 5,868.4 5,877.5 C-4, 3S-14 2/1/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph 6,570.0 6,600.0 5,877.5 5,904.9 C-4, 3S-14 1/31/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,245.0 6,700.0 5,582.6 5,996.2 Cement Plug PC Plug: 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 30.7 below retainer, 1 BBL ABOVE RETAINER 5/9/2023 6,106.0 6,244.8 5,458.1 5,582.4 Cement Plug Tubing Plug: 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 30.7bbl below retainer, 1 BBL ABOVE RETAINER 5/9/2023 4,477.0 4,627.0 4,015.7 4,149.2 Plug – Perf- Wash-Cement PWC Plug: 71bbl 15.8 PPG CEMENT JOB. Cement in PC milled out 12/18/23 9/9/2023 38.0 2,809.0 38.0 2,556.5 Plug – Plug Back / Abandonment Plug OA Downsqueeze: 104 BBLS OF 15.8 PPG PERMAFROST CEMENT w/ BRIDGEMAKER IN 1ST 52 BBLS 9/15/2023 38.0 3,514.0 38.0 3,171.1 Primary – Full Bore PC Plug: 160 BBL, 15.8 PPG, CLASS G, CEMENT TO SURFACE 12/28/2023 3S-14, 2/5/2024 1:12:23 PM Vertical schematic (actual) PRODUCTION; 38.0-6,879.8 IPERF; 6,570.0-6,600.0 IPERF; 6,560.0-6,570.0 Cement Plug; 6,245.0 ftKB CEMENT RETAINER; 6,234.0 PACKER; 6,213.8 GAS LIFT; 6,113.0 Cement Plug; 6,106.0 ftKB CUT; 6,092.0 PLUG; 4,652.3 APERF; 4,587.0-4,627.0 FISH; 4,596.0 APERF; 4,545.0-4,585.0 Plug – Perf-Wash-Cement; 4,477.0 ftKB APERF; 4,503.0-4,543.0 APERF; 4,477.0-4,501.0 Cement Plug; 3,514.0 ftKB SURFACE; 38.0-2,808.6 Plug – Plug Back / Abandonment Plug; 38.0 ftKB CONDUCTOR; 38.0-108.0 MARKER PLATE; 38.0 Primary – Full Bore; 38.0 ftKB KUP INJ KB-Grd (ft) 32.90 RR Date 12/27/200 2 Other Elev… 3S-14 ... TD Act Btm (ftKB) 6,879.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043900 Wellbore Status INJ Max Angle & MD Incl (°) 33.62 MD (ftKB) 2,355.09 WELLNAME WELLBORE3S-14 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 3,514.0 4,596.0 3,171.1 4,121.6 Cement Plug PC Plug: 40 BBL, 15.8 PPG, CLASS G, ABOVE FISH 12/24/2023 3S-14, 2/5/2024 1:12:23 PM Vertical schematic (actual) PRODUCTION; 38.0-6,879.8 IPERF; 6,570.0-6,600.0 IPERF; 6,560.0-6,570.0 Cement Plug; 6,245.0 ftKB CEMENT RETAINER; 6,234.0 PACKER; 6,213.8 GAS LIFT; 6,113.0 Cement Plug; 6,106.0 ftKB CUT; 6,092.0 PLUG; 4,652.3 APERF; 4,587.0-4,627.0 FISH; 4,596.0 APERF; 4,545.0-4,585.0 Plug – Perf-Wash-Cement; 4,477.0 ftKB APERF; 4,503.0-4,543.0 APERF; 4,477.0-4,501.0 Cement Plug; 3,514.0 ftKB SURFACE; 38.0-2,808.6 Plug – Plug Back / Abandonment Plug; 38.0 ftKB CONDUCTOR; 38.0-108.0 MARKER PLATE; 38.0 Primary – Full Bore; 38.0 ftKB KUP INJ 3S-14 ... WELLNAME WELLBORE3S-14 DTTMSTART JOBTYP SUMMARYOPS 4/29/2023 CHANGE WELL TYPE (P&A) FUNCTION TEST ALL T & IC LDS/GN'S , T POT PASSED , T PPPOT PASSED , IC POT PASSED , IC PPPOT PASSED 4/30/2023 CHANGE WELL TYPE LRS PERFORM STEP RATE INJECTIVITY TEST FROM .5 BPM TO 3 BPM (SEE BODY); DRIFT W/ 8' x 2.125'' & 2.75'' DMY CA-2 PLUG DRIFT (DMY CEMENT RETAINER ASSEMBLY) TO D-NIP @ 6238' RKB (NO WEIGHT SWINGS OR OBSTRUCTIONS OBSERVED); LRS OBTAIN OA LLR OF 2 BPM @ 1240 PSI. READY FOR COIL. 5/9/2023 CHANGE WELL TYPE MIRU RIH W / CEMENT RETAINER AND TAGGED NIPPLE @ 6238' PUH AND SET RETAINER @ 6234' PUMPED 31.7 BBLS OF CLASS G 15.8 PPG CEMENT 30.7 BBLS BELOW RETAINER & 1 BBL ON TOP DRESSED OFF CEMENT TOP TO 6117' CEMENT IN PLACE @ 01:00 POOH RDMO 5/16/2023 CHANGE WELL TYPE PRE-STATE WITNESS TAG & MITT. TAG TOC @ 6086', MITT TO 1500 PSI (PASS), ATTEMPTED TO LOCATE THE MANDREL @ 6113' RKB W/ KICKOVER TOOL (UNABLE TO LOCATE). READY FOR STATE WITNESS TAG & TEST, IN PROGRESS. 5/17/2023 CHANGE WELL TYPE STATE WITNESS(GUY COOK) TAG TOC @ 6082' SLM. PERFORM PASSING MIT-T TO 1500 PSI. READY FOR TBG CUT. 5/27/2023 CHANGE WELL TYPE TAG TOP OF CEMENT AT 6106'. CUT TUBING WITH WELLTEC MECHANICAL CUTTER AT 6092'. TATTLETALE AT SURFACE INDICATES BLADES EXTENDED PAST 3.50" TBG OD. JOB COMPLETE 5/29/2023 CHANGE WELL TYPE CMIT TxIA TO 1500 PSI. RIGGED UP TO IA WITH A JUMPER TO TBG AND PUMPED 3.4 BBLS DIESEL TO TEST 1500 PSI. 15 MIN TBG LOST 50 PSI, IA LOST 50 PSI; 30 MIN TBG AND IA LOST 0 PSI. PASSED JOB COMPLETE 6/1/2023 ACQUIRE DATA (P&A) T X IA DDT (IN PROGRESS) 6/2/2023 ACQUIRE DATA (P&A) T X IA DDT (IN PROGRESS) 6/4/2023 ACQUIRE DATA (P&A) T X IA DDT (IN PROGRESS) 6/21/2023 ACQUIRE DATA (P&A) T X IA DDT (PASS) 7/14/2023 ACQUIRE DATA (P & A) BLEED IA x T TO 0 PSI (COMPLETE), BLEED OA to 0 PSI (COMPLETE). 7/30/2023 RECOMPLETION Lay rig mats for sub base to move to 3S-14, pull pits away from sub base, pull subbase off 3S-03 7/31/2023 RECOMPLETION Spot sub base over 3S-14, spot pits, hook up lines berm around rig. Bring on fluid to pits. Rig up to circulate thru squeeze manifold, test lines. Attempt to cicrulate down tubing and IA. Unable to circulate. Rig up Eline to drift tubing. RIH with Eline with tubing punch, punch holes confirm flow path, POOH and R/D Eline, displace well to 9.6 ppg, set and test BPV, Nipple down tree 7/31/2023 CHANGE WELL TYPE RIG UP FULL PRESSURE GEAR ON RIG (N7ES). PERFORM 1.69" CCL DRIFT TO 6100' WITH NO ISSUES (LOG OVER AND SEE CUT WITH CCL AT 6092'). PERFORM 2", 3' TUBING PUNCH (6 SPF) FROM 6078' - 6081'. RIG ABLE TO CIRCULATE AFTER SHOOTING HOLES. JOB COMPLETE 8/1/2023 RECOMPLETION Continued to nipple down tree nipple up stack, flood and test BOPs 250/5000 Ann 250/3500, pull hanger off seat 75K, lay down 3.5" completion, fill well with diesel, nipple down stack nipple up production tree, Rig released @ 00:00 on 8/2/23 KRU 3S-14 Plug and Abandon Summary of Operations 8/9/2023 ACQUIRE DATA DRIFT W/ 5.90" GAUGE RING DOWN TO TD @ 6093.9' RKB; RAN USIT-DSLT DOWN TO 6093'' & LOGGED MAIN PASS UP TO 3500' RKB W/ REPEAT PASS FROM 6093' UP TO 5700' RKB (BOTH LOGGED @ 30 FPM @ 5DEG 3IN RESOLUTION (OBTAINED GOOD DATA). IN PROGRESS (CIBP NEXT PENDING REVIEW OF LOGS) 8/25/2023 ACQUIRE DATA SET BAKER CIBP @ 4653', PREPARE FOR PERFORATION RUNS SET DEPTH: 4653' CCL TO CE: 10.3' CCL STOP DEPTH: 4642.7' 8/26/2023 ACQUIRE DATA PERFORM BELOW PERFORATION INTERVALS WITH HSD 4.72" HSD POWERFLOW, 21 SPF: 4587' - 4627', 4545' - 4585', 4503' - 4543', 4477' - 4501', 144' TOTAL 8/27/2023 ACQUIRE DATA PERFORM BELOW PERFORATION INTERVALS WITH HSD 4.72" HSD POWERFLOW, 21 SPF: 4587' - 4627', 4545' - 4585', 4503' - 4543', 4477' - 4501', 144' TOTAL PERFORM GAUGE RING / JUNK BASKET RUN TO DOWN TO PLUG, TAGGED AT 4639' JOB COMPLETE 9/9/2023 ACQUIRE DATA MIRU, FUNCTION TEST BOP'S. TAG AT 4620' CTMD, CORRECT DEPTH TO 4638' RKB. WASH PERFORATIONS W/ HYDRAWELL WASH TOOL, PER TOOL REP ON LOCATION, F/ 4638' T/ 4467' RKB. LAY IN 71 BBLS OF 15.8 PPG CEMENT FROM BOTTOM PERF @ 4627 TO 150' ABOVE TOP PERF 4327' DRESS OFF TOP OF CEMENT TO 4327' POOH CHASING CEMENT OOH FREEZE PROTECT WELL FROM 2500' W / 96 BBLS OF DIESEL JET BOP'S RDMO 9/15/2023 ACQUIRE DATA LRS PUMPED 5 BBLS DIESEL @ 2 BPM / ~1500 PSI TO VERIFY INJECTIVITY DOWN THE OA. HAL CEMENTERS - PUMPED OA CEMENT DOWN SQUEEZE PUMPED 5 BBLS SPACER FOLLOWED BY 104 BBLS OF 15.8 PPG PERMAFROST CEMENT. CONSISTING OF 250 SKS 52 BBL 15.8 PPG 1.167 ft3 5.027 Gal/Sk Cement with LCM 2.7 BPM 900 PSI. FOLLOWED BY 250 SKS 52 BBL 15.8 PPG 1.159 FT3 5.03 Gal/SK Cement 2.7 BPM 500 PSI. READY FOR NEXT STEP OF P&A PROCEDURE. 9/16/2023 ACQUIRE DATA TAG TOC W/ 3" BAILER @ 4293' SLM. MIT 1500 IN PROGRESS BY LRS. 9/16/2023 ACQUIRE DATA PRE WITNESS MIT T (7") TO 1500 PSI **FAILED TO 1500 PSI** SEE LOG SLICKLINE WSR UNTIL 12:00/LRS WSR FROM 12:00 TO FINISHED. JOB COMPLETE 9/22/2023 CHANGE WELL TYPE (P&A) OA DDT (PASSED) OA TOC (>470') 9/26/2023 CHANGE WELL TYPE (P&A) OA CEMENT TOP JOB (COMPLETE ~6.5 BBL OF CEMENT) 9/29/2023 CHANGE WELL TYPE (P&A) OA TOC @ SF. 12/17/2023 CHANGE WELL TYPE RIG UP COIL UNIT. MAKE UP 6.0" BEAR CLAW MILL. TAGGED TOP OF CEMENT AT 4296' CTMD RE-GEN TRACTOR. AT 4318' MILLING AHEAD 12/18/2023 CHANGE WELL TYPE MILL FROM 4,318' CTMD TO 4,598' CTMD. AT 4,598' MILL STARTS STACKING WEIGHT ( ACTING LIKE CIBP). MAKE CALL TO ENGINEER AND DECIDE DEPTH SHOULD BE GOOD. RIH W/ UNDERREAMER AND DRY TAG AT 4,603' CTMD MAKE 2X 5FPM UNDERREAMING PASSES FROM 4,200' TO 4,603' CTMD. PUMP 50 BBL GEL PILL, DROP CIRC BALL AND CHASE RETURNS TO SURFACE AT 4+ BPM.. FREEZE PROTECT WELL. AT SURFACE UNABLE TO GET PAST LOWER VALVE OR CLOSE APPEARS UPPER UNDERREAMER ARMS WILL NOT CLOSE CONFIRMED IT'S NOT ICE AND YOU CAN HEAR METAL TO METAL IN THE TREE RIH AND DISCONNECT TOOLS 12/19/2023 CHANGE WELL TYPE RIH AND DISCONNECT TOOLS LEFT 24.95' FISH IN HOLE RDMO MOVE OVER TO 3S-18 12/19/2023 SUPPORT OTHER OPERATIONS RIG UP ELINE FOR IBC/CBL LOG POST PERF/CEMENT. DRIFT W/ JUNK BASKET AND 5.9" GAUGE RING TO FISH ON TOP OF CIBP. TAG TOP OF FISH AT 4595.5'. ***JOB IN PROGRESS*** 12/20/2023 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 19-DEC-23*** LOG CBL-IBC DATA FROM 4590' TO 4200' AT 5 DEG 6", 5 DEG 3", AND 5 DEG 1.5" RESOLUTIONS. SEND DATA TO INTERACT FOR RUSH PROCESSING. JOB IN PROGRESS - more cement next after AOGCC reviews USIT 12/23/2023 CHANGE WELL TYPE MIRU. STANDBY FOR CEMENT CREW TO RETURN AFTER COMPLETION OF DRILLING RIG CEMENT JOB. 12/24/2023 CHANGE WELL TYPE LAY IN 1044' CEMENT PLUG PUMPING 40 BBL OF 15.8 PPG, CLASS G, NEAT FROM 4590' RKB TOP OF FISH TO 3546' RKB TOP OF CEMENT. PUMP S. DIESEL WHILE POOH TO CIRCULATE/CONTAMINATE ABOVE CEMENT PLUG & FREEZE PROTECTING 7" PRODUCTION CASING. WAIT MINIMUM 24 HOURS FOR WITNESSED TAG & TEST. JOB IN PROGRESS. 12/26/2023 SUPPORT OTHER OPERATIONS STATE WITNESSED (ADAM EARL) TAG TOP OF CEMENT @ 3514' RKB (GOOD) , OBTAINED PASSING MIT AGAINST CEMENT PLUG TO 1720 PSI. READY FOR CTU 12/26/2023 SUPPORT OTHER OPERATIONS (P&A) TxIA DDT TO 0 PSI (PASS). 12/29/2023 CHANGE WELL TYPE TAGGED CEMENT TOP @ 3463' CTMD. LAY IN 160 BBLS (27 BBLS EXCESS) 15.8 PPG CEMENT (LET 3 BBLS GET AROUND COIL) WHILE PUMPING @ 1.2 BPM & POOH @ 22 FPM TO SURFACE. WASHED BOP'S & TREE (CYCLED MASTER). READY FOR DHD IN 48 HRS. 1/1/2024 SUPPORT OTHER OPERATIONS (P&A) DDT T X IA TO 0 PSI (PASS) OA DDT TO 0 PSI (PASS) TOC @ SF WET/HARD 1/6/2024 SUPPORT OTHER OPERATIONS (P&A) POST STORM CLEAN UP BY NES. VERIFIED ZERO PSI ON WELL ANNULUSES, & CHECKED FOR LELS (0% LELS, 20.9% O2,, 0 PPM H2S, 0 PPM CO). NEXT STEP: CUT/REMOVE WELLHEAD AND CELLAR BOX, BEGIN EXCAVATION. 1/7/2024 SUPPORT OTHER OPERATIONS (P&A) NES ASSISTED WITH PAD UPKEEP DURING PHASE 3 CONDITIONS. 1/8/2024 SUPPORT OTHER OPERATIONS (P&A) POST PHASE 3 CLEAN UP- REMOVED WATER AND ICE FROM CELLAR. CUT CONDUCTOR WINDOWS. CLEANING OUT RG2401 AND FILLER. RETURN IN THE AM TO FINISH WELLHEAD AND CELLAR REMOVAL. 1/9/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- CUT AND REMOVED WELLHEAD AND STEEL CELLAR. WILL VERIFY LENGTH IN THE AM. NEXT STEP : INSTALL SHORE CAN 1/10/2024 SUPPORT OTHER OPERATIONS (P&A PREP) MEASURED FROM 3' SURVEYED REFERENCE MARK (ON WELLHEAD) 8' OF WELLHEAD REMOVED. CHANGED HAMMER ATTACHMENT OUT FOR INSTALLING 10'DX16'H SHORE CAN. 1/11/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS- VIBRATED 10'DX16'H SHORE CAN TO 14'. COVERED WITH STOMPER MAT TO PREVENT SNOW ACCUMLATION INSIDE OF SHORE CAN. NEXT STEPS; POST STORM CLEAN UP, EXCAVATE WITH IN SHORE CAN TO ~13' FROM TOP OF CAN. 1/14/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- EXCAVATED TO 7' OUT OF TARGET DEPTH OF 13'. NEXT STEP : CONTINUE TO EXCAVATE TO 13', CUT/REMOVE WELL STUB AND PREP FOR MARKER PLATE. 1/15/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- EXCAVATED TO 11' OUT OF TARGET DEPTH OF 13'. NEXT STEP : CONTINUE TO EXCAVATE TO 13', CUT/REMOVE WELL STUB AND PREP FOR MARKER PLATE. 1/16/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- EXCAVATED TO 13' OUT OF TARGET DEPTH OF 13'. CUT/REMOVE ADDITIONAL 4' OF WELL STUB . OVERALL LENGTH OF WELL REMOVED FROM SURVEYED REFERENCE MARK TO TUNDRA (3') = 12' , OR 9' BELOW ORIGINAL GROUND. NEXT STEP : PREP CAN FOR INSPECTION AND REMOVAL, FOLLOWING DAY AOGCC VERIFICATION OF MARKER PLATE. 1/17/2024 SUPPORT OTHER OPERATIONS (P&A) PREP & INSPECTED 10' SHORE CAN FOR STRESS CRACK OR METAL FATIGUE. MINOR REPAIRS MADE TO SHORE CAN. NEXT STEP: AOGCC VERIFICATION OF MARKER PLATE INFORMATION & TOP OF CEMENT. BACKFILL. 1/18/2024 SUPPORT OTHER OPERATIONS (P&A) COMPLETE AOGCC INSPECTOR BOB NOBLE VERIFIED MARKER PLATE INFORMATION & TOP OF CEMENT. NES WELDER WELDED 30" DIAMETER 1/4" THICK MARKER PLATE TO WELL STUB 9' BELOW ORIGINAL GROUND. BACKILLED SHORE CAN & VIBRATED OUT OF THE GROUND. COMPLETED BACKFILL OPERATIONS. NEXT STEP ; DEMOB EQUIPMENT AND FINAL SITE CLEARANCE. SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-14 Plug and Abandonment January 18, 2024 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-14, commencing operations on August 9, 2023 and completing the Plug and Abandonment on January 18, 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 4,653ft KB, the production casing was perforated from 4,477 to 4,627ft 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. 2024-0118_Surface_Abandon_KRU_3S-14_bn Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/19/2024 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-14 ConocoPhillips Alaska, Inc. PTD 2022210; Sundry 323-409 1/18/2024: I traveled to KRU 3S-14 to witness the cut-off on this P&A. When I arrived I met with CPA representative Roger Mouser. I looked at the cut-off and all strings of pipe were full of good hard cement. The well was cut off 9 feet below tundra grade. I inspected the marker plate and found it to have all the correct names and numbers on it. The plate is 30 inches in diameter by ¼-inch thick. Everything looked good so I told Roger he could weld it on and cover it up. I ask Roger for a picture of the plate welded onto the casing which he sent me later in the day. Attachments: Photos (4)    2024-0118_Surface_Abandon_KRU_3S-14_bn Page 2 of 3 Surface Abandonment – KRU 3S-14 (PTD 2022210) Photos by AOGCC Inspector B. Noble (except as noted) 1/18/2024 2024-0118_Surface_Abandon_KRU_3S-14_bn Page 3 of 3 Marker Plate welded to conductor; Photo courtesy of CPAI 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:6,895 ft MD Lease No.:ADL0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 2809 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6880 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 6,245 Feet Tbg Cut@ 6,092 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 4,652 ft 3514 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1720 1610 1585 IA OA 5 5 5 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled out to KRU 3S-14 for P&A operations consisting of a wire-line tag and pressure test. Brent Rogers was the CPAI representative on location. The wire-line tool string was made up with 10 feet of 2" WB, oil jars, spanges, and a 5 foot long 2 1/4" ball bailer. The string weighed 200lbs hanging just below the lubricater. Tagged top of cement @ 3514 ft MD (3481 SLM). Tubing pressure test passed. December 26, 2023 Adam Earl Well Bore Plug & Abandonment KRU 3S-14 CPAI PTD 2022210; Sundry 323-409 none Test Data: P Casing Removal: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-1226_Plug_Verification_KRU_3S-14_ae           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. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 11/30/2023 Transmitted: North Slope, Kuparuk River Unit Via SFTP data drop 3S-06A 50-103-20454-01 203088_3S-06_ USIT_13Sep22 203088_3S-06_IBC-CBL_09Sep2023 203088_3S-06_IBC-CBL_8Jun23 203088_3S-06_MechCut_01Sept2022 203088_3S-06_Perf_04Oct2022 203088_3S-06_PERF_06Aug2023 203088_3S-06_Perf_29Aug23 203088_3S-06_USIT DSLT_13Sep2022 203088_3S-06_USITDSLT_16Nov2022 3S-10 50-103-20440-00 202232_3S-10_IBC-CBL_31Aug23 202232_3S-10_IBC_23Apr23 202232_3S-10_Perf_08May23 202232_3S-10_Perf_18Jun23 202232_3S-10_Perf_26May23 202232_3S-10_Plug_26May23 3S-14 50-103-20439-00 202221_3S-14_IBCDSLT Pre_08Aug2023 202221_3S-14_PlugPerfRecord_25Aug23 3S-17A 50-103-20448-01 203080_3S-17A_IBC-CBL_23Jul2023 203080_3S-17A_IBC-CBL_25Apr2023 203080_3S-17A_Perf_07May2023 10 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38405 T38406 PTD: 203-057 T38407 T38408 T38409 2/29/2024 3S-14 50-103-20439-00 202221_3S-14_IBCDSLT Pre_08Aug2023 202221_3S-14_PlugPerfRecord_25Aug23 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:17:36 -09'00' 1a. Well Status:Other Abandoned SuspendedSPLUGOil 1b. Well Class: 20AAC 25.105 20AAC 25.110 ExploratoryDevelopment WDSPLGINJ WINJ No. of Completions: __________________Stratigraphic TestService 14. Permit to Drill Number / Sundry:2. Operator Name: 15. API Number:7. Date Spudded:3. Address: 16. Well Name and Number:8. Date TD Reached:4a. Location of Well (Governmental Section): Surface: 9. Ref Elevations: KB:Top of Productive Interval: 220' FSL, 1555' FEL S7 T12N R8E GL: BF: 18. Property Designation:10. Plug Back Depth MD/TVD:Total Depth: 19. DNR Approval Number:11. Total Depth MD/TVD:4b. Location of Well (State Base Plane Coordinates, NAD 27): Zone- 4y-x-Surface: 20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4y-x-TPI: Zone- 4y-x-Total Depth: 5. Directional or Inclination Survey: Yes (attached) No 21. Re-drill/Lateral Top Window MD/TVD:13. Water Depth, if Offshore: N/A (ft MSL)Submit electronic information per 20 AAC 25.050 22. Logs Obtained: 23. BOTTOM 108'H-4016"9 cubic yards 2556'L-809.625" 6161'L-807" 25.24. Open to production or injection? Yes No 26. NoWas hydraulic fracturing used during completion? Yes AMOUNT AND KIND OF MATERIAL USEDDEPTH INTERVAL (MD) 27. Method of Operation (Flowing, gas lift, etc.):Date First Production: Gas-MCF:Production forHours Tested: Test Period Oil Gravity - API (corr):Gas-MCF:CalculatedCasing Press: Press. 24-Hour Rate DEPTH SET (MD) Sr Res EngSr Pet GeoSr Pet Eng N/A Water-Bbl:Oil-Bbl: Water-Bbl: PRODUCTION TEST N/A Oil-Bbl:Date of Test: Flow Tubing 1bbl of 15.8ppg Class G above cmnt retainer 5996637 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A N/A 29' 30' Per 20 AAC 25.283 (i)(2) attach electronic information 26'26# 62.5# 40# 108' 6880'26' SIZE SETTING DEPTH MD PACKER SET (MD/TVD) 42" 5993897 ADL0380106, ADL0380107 ALK4623 29' 30' 2809' 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 475704 475674 CEMENTING RECORD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 202-221/323-234 570 sx AS, 250 sx LiteCrete12-1/4" CASING 50-103-20439-00-00 KRU 3S-14 12/18/2002 6879'MD/6175'TVD 6106'MD/5458'TVD 28' P.O.Box 100360, Anchorage, AK 99510-0360 476188 2519' FNL, 1071' FEL S18 T12N R8E 351' FSL, 1595' FEL S7 T12N R8E 12/23/2002 1626'MD/1541'TVD SETTING DEPTH TVD 5996769 TOP HOLE SIZE AMOUNT PULLEDTOP 6106'-6234' 30.7bbls of 15.8 Class G below cmnt retainer6234'-6700' 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 246 sx Class G w/GasBlok8-1/2" 6246' 6214'MD/5554'TVD3.5" BOTTOM Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022 6. Date Comp., Susp., or Aband.: 8/2/2023 17. Field / Pool(s): Kuparuk River Field/ Kuparuk River Oil Pool (Suspended) By Grace Christianson at 2:24 pm, Aug 21, 2023 Suspended 8/2/2023 JSB RBDMS JSB 083023 xGDSR-10/25/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1626' 1541' 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: Shane Germann Digital Signature with Date: 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: 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. 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: shane.germann@conocophillips.com Authorized Title: RWO/CTD Engineer 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: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Contact Phone:907-263-4597 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.comReason: I have reviewed this document Location: Date: 2023.08.21 09:39:51-08'00'Foxit PDF Editor Version: 12.1.2 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,654.0 3S-14 9/30/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 3S-14 5/27/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/20/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.1 2,808.6 2,556.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.4 6,879.8 6,161.4 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.3 Set Depth … 6,245.7 Set Depth … 5,583.2 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.3 24.3 0.00 HANGER 8.000 FMC GEN TUBING HANGER 3.500 496.0 495.4 6.56 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 6,113.0 5,464.4 26.90 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.992 6,158.9 5,505.4 26.59 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 6,197.2 5,539.6 26.30 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT) 3.500 6,199.2 5,541.4 26.28 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.970 6,212.9 5,553.7 26.14 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,213.8 5,554.5 26.13 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 6,218.7 5,558.9 26.08 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.730 6,237.8 5,576.1 25.89 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,244.8 5,582.4 25.82 WLEG 4.520 WLEG w/ SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,234.0 5,572.7 25.93 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER, W/ 2.79 NG RING 5/9/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,113.0 5,464.4 26.90 1 GAS LIFT DMY RK 1 1/2 0.0 1/30/2003 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,560.0 6,570.0 5,868.4 5,877.5 C-4, 3S-14 2/1/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph 6,570.0 6,600.0 5,877.5 5,904.9 C-4, 3S-14 1/31/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,234.0 6,700.0 5,572.7 5,996.2 Cement Plug 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 1 BBL ABOVE RETAINER 5/9/2023 6,106.0 6,234.0 5,458.1 5,572.7 Cement Plug 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 1 BBL ABOVE RETAINER 5/9/2023 3S-14, 8/15/2023 12:40:46 PM Vertical schematic (actual) PRODUCTION; 26.4-6,879.8 IPERF; 6,570.0-6,600.0 IPERF; 6,560.0-6,570.0 CEMENT RETAINER; 6,234.0 Cement Plug; 6,234.0 ftKB PACKER; 6,213.8 GAS LIFT; 6,113.0 Cement Plug; 6,106.0 ftKB CUT; 6,092.0 SURFACE; 29.1-2,808.6 CONDUCTOR; 30.0-108.0 KUP INJ KB-Grd (ft) 32.90 RR Date 12/27/200 2 Other Elev… 3S-14 ... TD Act Btm (ftKB) 6,879.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043900 Wellbore Status INJ Max Angle & MD Incl (°) 33.62 MD (ftKB) 2,355.09 WELLNAME WELLBORE3S-14 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Page 1/2 3S-14 Report Printed: 8/15/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 7/30/2023 18:00 7/31/2023 00:00 6.0 0 0.0 0.0 MIRU, MOVE DEMOB MOB P Pull pits away from sub module, lay matting boards for sub to move to 3S-14, pull subbase off 3S-03, keep Sub module on mats up to well, clean up around 3S- 03 cellar area and move mats over to 3S- 18, lay herculite around 3S-14 cellar area, move subbase over in line with 3S-14 7/31/2023 00:00 7/31/2023 01:00 1.0 0 0.0 0.0 MIRU, MOVE DEMOB MOB P Spot support equipment and cuttings tank R/U pits to Sub Module KDTH on location move kill tank down pad & rig up kill tank line *** Note: Rig Accepted @ 01:00 am 7/31/2023 01:00 7/31/2023 04:30 3.5 0 0.0 0.0 MIRU, WELCTL DEMOB RURD P Bring on 9.6 ppg NaCI into pits, R/U cellar to displace well Air test kill tank line 7/31/2023 04:30 7/31/2023 05:30 1.0 0 0.0 0.0 MIRU, WELCTL DEMOB CIRC T Fluid pack and test surface lines 300 psi/3,500 psi, good test, line up to circulate well to 9.6 ppg Bring pump online, pressure up to 3,700 psi Bleed pressure off Unable to pump down the well Check valve alignment (good) Attempt to pump down well Unable to pump 7/31/2023 05:30 7/31/2023 08:30 3.0 0 0.0 0.0 MIRU, WELCTL DEMOB OTHR T Discuss plan forward with town Call out Eline unit 7/31/2023 08:30 7/31/2023 10:30 2.0 0 0.0 0.0 MIRU, WELCTL DEMOB ELNE T Eline on location re head line, bring up tools to floor and load lubricator in pipe shed 7/31/2023 10:30 7/31/2023 20:15 9.7 5 0.0 0.0 MIRU, WELCTL DEMOB ELNE T PJSM rig up Eline. Drifted to pre-rig tubing cut at 6,092'. RU and RIH with tubing punchs to 6,078' (5' below collar in same joint as cut). Pressure up to 400 PSI on tubing, punch 18 - 3/8" holes from 6,078' to 6,081', after tubing puch pressure to 150 PSI on tubing and IA Circulate 2 BBLS at 1 BPM 100 PSI to confirm flow path POOH with Eline, R/D Eline 7/31/2023 20:15 7/31/2023 22:15 2.0 0 0.0 0.0 MIRU, WELCTL DEMOB CIRC P Line up to diplace well to 9.6 ppg NaCI Confirm no pressure on Well head Bring pump online 5.0 bpm/910 psi/IA 430 psi/Choke 200 psi 3,830 stks away. 244 bbl away, shut down pump, bleed pressure off 7/31/2023 22:15 7/31/2023 22:45 0.5 0 0.0 0.0 MIRU, WELCTL DEMOB OWFF P Observe well for flow 30 mins (no flow) 7/31/2023 22:45 7/31/2023 23:15 0.5 0 0.0 0.0 MIRU, WELCTL DEMOB RURD P Set BPV, P/T 1,000 psi for 10 mins (good), 7/31/2023 23:15 8/1/2023 00:00 0.7 5 0.0 0.0 MIRU, WELCTL DEMOB RURD P N/D tree 8/1/2023 00:00 8/1/2023 00:45 0.7 5 0.0 0.0 MIRU, WELCTL DEMOB RURD P Continue N/D tree 8/1/2023 00:45 8/1/2023 03:45 3.0 0 0.0 0.0 MIRU, WELCTL DEMOB RURD P N/U BOP stack Tighten up kill and choke lines Retrieve RKB's 8/1/2023 03:45 8/1/2023 06:00 2.2 5 0.0 0.0 MIRU, WELCTL DEMOB RURD P Prep rig for BOP Testing, Grease crew on location, Service all valves, Bring Test Joint to RF and confirm measurements and fluid pack BOPE. Rig Name: NABORS 7ES Rig Accept : 7/31/2023 Rig Release : 8/2/2023 Well Name: 3S-14 Page 2/2 3S-14 Report Printed: 8/15/2023 Time Log & Summary Report AOGCC Job type: RECOMPLETION Time Log Start Time End Time Dur (hr) Start Depth (ftKB) End Depth (ftKB) Phase Phase Op Code Activity Code Time P-T-X Operation 8/1/2023 06:00 8/1/2023 07:30 1.5 0 0.0 0.0 MIRU, WHDBOP DEMOB RURD P Shell test BOP. 8/1/2023 07:30 8/1/2023 12:00 4.5 0 0.0 0.0 MIRU, WHDBOP DEMOB BOPE P Test BOP Test annular with 3 1/2" test joint to 250/3500 PSI F/5 min. All other test to 250/5000 PSI 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 = 1600 PSI, 200 PSI attained = 15 sec, full recovery attained = 216 sec. UVBR = 5 sec, LVBR = 5 sec, Annular = 29 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 1900 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Adam Earl witness waived 8/1/2023 12:00 8/1/2023 12:30 0.5 0 0.0 0.0 MIRU, WHDBOP DEMOB RURD P Rig down test equipment 8/1/2023 12:30 8/1/2023 13:00 0.5 0 0.0 0.0 MIRU, WHDBOP DEMOB SVRG P Service TD and rig 8/1/2023 13:00 8/1/2023 13:30 0.5 0 0.0 0.0 MIRU, WHDBOP DEMOB MPSP P Pull test dart and BPV 8/1/2023 13:30 8/1/2023 15:00 1.5 0 0.0 0.0 MIRU, WHDBOP DEMOB THGR P At 14:30 Pull 60K to release hanger, Pull 95K to release cut, PU wt 75K/SO wt 65K. 8/1/2023 15:00 8/1/2023 22:15 7.2 5 6,095.0 0.0 COMPZN, RPCOMP DEMOB PULL P Pull and lay down 3.5" tubing from 6095' 8/1/2023 22:15 8/1/2023 23:00 0.7 5 0.0 0.0 COMPZN, WHDBOP DEMOB FRZP P Freeze protect well with 5.5 bbls Diesel 8/1/2023 23:00 8/2/2023 00:00 1.0 0 0.0 0.0 DEMOB, MOVE DEMOB NUND P Suck out stack and nipple down BOPs Rig Name: NABORS 7ES Rig Accept : 7/31/2023 Rig Release : 8/2/2023 Well Name: 3S-14 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): 6895'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 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-14 6175' 6106' 5458' 1440 psi 6106' 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): 6214' MD and 5554' TVD N/A Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 202-221 P.O. Box 100360, Anchorage, AK 99510 50-103-20439-00-00 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 6246' MD 108' 2556' 108' 2809' 6161'6880' 16" 9-5/8" 79' 2780' 6560-6600' (cemented) 6854' 5868-5905' (cemented) 7" Perforation Depth TVD (ft): 3-1/2" Packer: Baker SAB-3 Packer SSSV: None 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 8/1/2023 By Grace Christianson at 12:01 pm, Jul 19, 2023 323-409 Jill Simek Digitally signed by Jill Simek Date: 2023.07.18 16:37:07 -08'00' X MDG 7/24/2023 ADL0380106, ADL0380107 AOGCC inspection is required after cutoff and before any remedial cementing. DSR-7/19/23 X VTL 7/24/2023 X 10-407 GCW 07/24/2023JLC 7/24/2023 07/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.07.25 09:26:11 -08'00' RBDMS JSB 072523 3S-14 Plug and Abandon Procedure PTD #202-221 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 6,092ft KB. Well Type: Injector Scope of Work: Perform Plug and Abandonment of 3S-14: 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 IBC/DSLT and log 7” 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 4,653ft 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 ~68bbls cement, including excess. 10. Leave Top of Cement in production casing ~150ft above top perforation at ~4,327ft 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-14 Plug and Abandon Procedure PTD #202-221 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 166 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 2,809ft KB. Job is planned for 99 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-14 PTD #: 202-221 API #: 50-103-20439-00 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-14 P&A PTD #: 202-221 16” 62.5# H-40 Conductor @ 108' KB JS 7-17-2023 7" 26# L-80 Production Casing @ 6,880' KB 3-½” 9.3# L-80 Tubing @ 6,246' KB 9 5/8" 40# L-80 Surface Casing @ 2,809' KB Perfs: 6,560' – 6,600' KB Tubing cut at 6,092' KB TOC (tubing) at 6,106' KB Calculated Top of Cement (7" x Open Hole) = 5,510' KB Kuparuk HRZ/Kalubik Shales Moraine 5,801' – 5,980' KB Coyote 4,577' – 5,303' KB Packer depth = 6,214' KB Cement retainer at 6,234' KB Cement Plug (Production Casing x Open Hole Annulus) Approx. 4,477' – 4,627' KB CIBP @ ~4,653' KB Cement Plug (Production Casing) Approx. 4,653' KB to Surface Cement Plug (Production Casing x Surface Casing Annulus) 2,809' KB to Surface Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 3S-14 5/27/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/20/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.1 2,808.6 2,556.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.4 6,879.8 6,161.4 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.3 Set Depth … 6,245.7 Set Depth … 5,583.2 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.3 24.3 0.00 HANGER 8.000 FMC GEN TUBING HANGER 3.500 496.0 495.4 6.56 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 6,113.0 5,464.4 26.90 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.992 6,158.9 5,505.4 26.59 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 6,197.2 5,539.6 26.30 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT) 3.500 6,199.2 5,541.4 26.28 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.970 6,212.9 5,553.7 26.14 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,213.8 5,554.5 26.13 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 6,218.7 5,558.9 26.08 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.730 6,237.8 5,576.1 25.89 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,244.8 5,582.4 25.82 WLEG 4.520 WLEG w/ SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,092.0 5,445.6 27.05 CUT 238 WELLTEC MECHANICAL TUBING CUT AT 6092' RKB 5/27/2023 2.992 6,234.0 5,572.7 25.93 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER, W/ 2.79 NG RING 5/9/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,113.0 5,464.4 26.90 1 GAS LIFT DMY RK 1 1/2 0.0 1/30/2003 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,560.0 6,570.0 5,868.4 5,877.5 C-4, 3S-14 2/1/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph 6,570.0 6,600.0 5,877.5 5,904.9 C-4, 3S-14 1/31/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,234.0 6,700.0 5,572.7 5,996.2 Cement Plug 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 1 BBL ABOVE RETAINER 5/9/2023 6,106.0 6,234.0 5,458.1 5,572.7 Cement Plug 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 1 BBL ABOVE RETAINER 5/9/2023 IPERF; 6,570.0-6,600.0 IPERF; 6,560.0-6,570.0 CEMENT RETAINER; 6,234.0 Cement Plug; 6,234.0 ftKB PACKER; 6,213.8 GAS LIFT; 6,113.0 Cement Plug; 6,106.0 ftKB CUT; 6,092.0 SURFACE; 29.1-2,808.6 CONDUCTOR; 30.0-108.0 1a. Well Status:Other Abandoned SuspendedSPLUGOil 1b. Well Class: 20AAC 25.105 20AAC 25.110 ExploratoryDevelopment GINJ WINJ WDSPL No. of Completions: ___________________Service Stratigraphic Test 14. Permit to Drill Number / Sundry:6. Date Comp., Susp., or2. Operator Name: Aband.: 15. API Number:7. Date Spudded:3. Address: 16. Well Name and Number:8. Date TD Reached: 17. Field / Pool(s): GL: BF: 18. Property Designation: 19. DNR Approval Number:11. Total Depth MD/TVD:4b. Location of Well (State Base Plane Coordinates, NAD 27): Zone- 4y-x-Surface: 20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4y-x-TPI: Zone- 4y-x-Total Depth: 5. Directional or Inclination Survey: Yes (attached) No 21. Re-drill/Lateral Top Window MD/TVD:13. Water Depth, if Offshore: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 108'H-4016" 2556'L-809.625" 6161'l-807" 25.24. Open to production or injection? Yes No 26. NoWas hydraulic fracturing used during completion? Yes AMOUNT AND KIND OF MATERIAL USEDDEPTH INTERVAL (MD) 27. Method of Operation (Flowing, gas lift, etc.):Date First Production: Gas-MCF:Production forHours Tested: Test Period Oil Gravity - API (corr):Gas-MCF:CalculatedCasing Press: Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 246 sx Class G w/ GasBlok8-1/2" 6246' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 202-221/323-2385/17/2023 P.O. Box 100360, Anchorage, AK 99510-0360 5993897476188 6895' MD/ 6175' TVD ADL0380106, ADL0380107 ALK 4623 50-103-20439-00-00 KRU 3S-14 December 18, 2002 December 23, 2002 9. Ref Elevations: KB: 28' Kuparuk River Field/ Kuparuk River Oil Pool (Suspended) WT. PER FT.CEMENTING RECORDGRADE 5996637 SETTING DEPTH TVD 5996769 TOP HOLE SIZE AMOUNT PULLED 475704 475674 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 1626' MD/ 1541' TVDN/A N/A 6214' MD/ 5554' TVD PACKER SET (MD/TVD) 42" 12-1/4" 9 cu yds High Early 29'570 sx AS & 250 sx LiteCrete 30' 2809'29' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 1 bbl , 15.8 ppg Class G, above cmnt retainer Water-Bbl: PRODUCTION TEST N/A Oil-Bbl:Date of Test: Flow Tubing 6234-6700' SUSPENDED 6560-6600' MD and 5868-5905' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Water-Bbl:Oil-Bbl: 30.7 bbl, 15.8 ppg Class G below cmnt retainer 6880' DEPTH SET (MD)SIZE 26' 62.5# 40# 108' 26' Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022 6106'-6234' 10. Plug Back Depth MD/TVD: 6106' MD/ 5458' TVD 4a. Location of Well (Governmental Section): Surface: 2519' FNL, 1071' FEL, Sec. 18, T12N, R8E, UM Top of Productive Interval: 220' FSL, 1555' FEL, Sec. 7, T12N, R8E, UM Total Depth: 352' FSL, 1585' FEL, Sec. 7, T12N, R8E, UM Suspended 5/17/2023 JSB RBDMS JSB 060923 Received 6/8/2023 xGDSR-6/28/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1626' 1541' 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: 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 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 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: 2023.06.08 16:13:26 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,654.0 3S-14 9/30/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 3S-14 5/27/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/20/2010 ninam General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / WKM / GEN 5 / 5M TREE CONNECTION: TOP 5.75"" ACME WITH 3.5"" EUE8RD THREAD 1/8/2003 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.1 2,808.6 2,556.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.4 6,879.8 6,161.4 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.3 Set Depth … 6,245.7 Set Depth … 5,583.2 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.3 24.3 0.00 HANGER 8.000 FMC GEN TUBING HANGER 3.500 496.0 495.4 6.56 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 6,113.0 5,464.4 26.90 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.992 6,158.9 5,505.4 26.59 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 6,197.2 5,539.6 26.30 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT) 3.500 6,199.2 5,541.4 26.28 PBR 5.870 BAKER 80-40 PBR BAKER 80-40 2.970 6,212.9 5,553.7 26.14 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.993 6,213.8 5,554.5 26.13 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 6,218.7 5,558.9 26.08 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.730 6,237.8 5,576.1 25.89 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 6,244.8 5,582.4 25.82 WLEG 4.520 WLEG w/ SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,092.0 5,445.6 27.05 CUT 238 WELLTEC MECHANICAL TUBING CUT AT 6092' RKB 5/27/2023 2.992 6,234.0 5,572.7 25.93 CEMENT RETAINER 2.75" FH1 CEMENT RETAINER, W/ 2.79 NG RING 5/9/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 6,113.0 5,464.4 26.90 1 GAS LIFT DMY RK 1 1/2 0.0 1/30/2003 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,560.0 6,570.0 5,868.4 5,877.5 C-4, 3S-14 2/1/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph 6,570.0 6,600.0 5,877.5 5,904.9 C-4, 3S-14 1/31/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,234.0 6,700.0 5,572.7 5,996.2 Cement Plug 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 1 BBL ABOVE RETAINER 5/9/2023 6,106.0 6,234.0 5,458.1 5,572.7 Cement Plug 31.7 BBL, 15.8 PPG, CLASS G CEMENT, 1 BBL ABOVE RETAINER 5/9/2023 3S-14, 6/8/2023 3:38:59 PM Vertical schematic (actual) PRODUCTION; 26.4-6,879.8 IPERF; 6,570.0-6,600.0 IPERF; 6,560.0-6,570.0 CEMENT RETAINER; 6,234.0 Cement Plug; 6,234.0 ftKB PACKER; 6,213.8 GAS LIFT; 6,113.0 Cement Plug; 6,106.0 ftKB CUT; 6,092.0 SURFACE; 29.1-2,808.6 CONDUCTOR; 30.0-108.0 KUP INJ KB-Grd (ft) 32.90 RR Date 12/27/200 2 Other Elev… 3S-14 ... TD Act Btm (ftKB) 6,879.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043900 Wellbore Status INJ Max Angle & MD Incl (°) 33.62 MD (ftKB) 2,355.09 WELLNAME WELLBORE3S-14 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 4/29/2023 CHANGE WELL TYPE (P&A) FUNCTION TEST ALL T & IC LDS/GN'S , T POT PASSED , T PPPOT PASSED , IC POT PASSED , IC PPPOT PASSED 4/30/2023 CHANGE WELL TYPE LRS PERFORM STEP RATE INJECTIVITY TEST FROM .5 BPM TO 3 BPM (SEE BODY); DRIFT W/ 8' x 2.125'' & 2.75'' DMY CA-2 PLUG DRIFT (DMY CEMENT RETAINER ASSEMBLY) TO D-NIP @ 6238' RKB (NO WEIGHT SWINGS OR OBSTRUCTIONS OBSERVED); LRS OBTAIN OA LLR OF 2 BPM @ 1240 PSI. READY FOR COIL. 5/9/2023 CHANGE WELL TYPE MIRU RIH W / CEMENT RETAINER AND TAGGED NIPPLE @ 6238' PUH AND SET RETAINER @ 6234' PUMPED 31.7 BBLS OF CLASS G 15.8 PPG CEMENT 30.7 BBLS BELOW RETAINER & 1 BBL ON TOP DRESSED OFF CEMENT TOP TO 6117' CEMENT IN PLACE @ 01:00 POOH RDMO 5/16/2023 CHANGE WELL TYPE PRE-STATE WITNESS TAG & MITT. TAG TOC @ 6086', MITT TO 1500 PSI (PASS), ATTEMPTED TO LOCATE THE MANDREL @ 6113' RKB W/ KICKOVER TOOL (UNABLE TO LOCATE). READY FOR STATE WITNESS TAG & TEST, IN PROGRESS. 5/17/2023 CHANGE WELL TYPE STATE WITNESS(GUY COOK) TAG TOC @ 6082' SLM. PERFORM PASSING MIT-T TO 1500 PSI. READY FOR TBG CUT. 5/27/2023 CHANGE WELL TYPE TAG TOP OF CEMENT AT 6106'. CUT TUBING WITH WELLTEC MECHANICAL CUTTER AT 6092'. TATTLE-TAIL AT SURFACE INDICATES BLADES EXTENDED PAST 3.50" TBG OD. JOB COMPLETE 5/29/2023 CHANGE WELL TYPE CMIT TxIA TO 1500 PSI. RIGGED UP TO IA WITH A JUMPER TO TBG AND PUMPED 3.4 BBLS DIESEL TO TEST 1500 PSI. 15 MIN TBG LOST 50 PSI, IA LOST 50 PSI; 30 MIN TBG AND IA LOST 0 PSI. PASSED JOB COMPLETE 3S-17 Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:6895 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@ 2809 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6880 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3.5"O.D. Tail@ 6246 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Retainer 6232 ft 6081 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1525 1475 1450 IA 40 40 40 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Halliburton Slickline was used for the cement tag. They used a 1-7/8 inch toolstring with a 2 inch drive down bailer. The bailer had a mule-shoe end with a flapper valve. The tag was at 6082 ft MD wireline. The sample was dirty diesel with cement chunks. During the MIT-T, 0.34 bbls were pumped in and 0.27 bbls were returned after the test. Little Red Services pump truck and calibrated gauges were used for the MIT. May 17, 2023 Guy Cook Well Bore Plug & Abandonment KRU 3S-14 ConocoPhillips Alaska Inc PTD 2022210; Sundry 323-238 none Test Data: P Casing Removal: rev. 11-28-18 2023-0517_Plug_Verification_KRU_3S-14_gc             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): 6879'None Casing Collapse Structural Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6560-6600' 6854' 5868-5905' 3-1/2" 7" 16" 9-5/8" 79' 2780' Perforation Depth MD (ft): MD 108' 2556' 108' 2809' 6161'6880' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6161' 6654' 5954' 2632 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 202-221 P.O. Box 100360, Anchorage, AK 99510 50-103-20439-00-00 ConocoPhillips Alaska, Inc. KRU 3S-14 None/SuspendedKuparuk River Oil Pool Kuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: 6214' MD/5555' TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-80 6246' 5/1/2023 Packer: Baker SAB-3 Packer SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Jill Simek jill.simek@conocophillips.com (907) 263-4131 Staff Well Intervention Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-238 By Kayla Junke at 11:49 am, Apr 19, 2023 Jill Simek Digitally signed by Jill Simek Date: 2023.04.19 09:28:28 -08'00' 10-407 SFD 4/21/2023 Suspension approved through 12/31/2023. P&A, including surface abandonment must be completed by 12/31/2023 X DSR-4/20/23 SFD 10-407 6175' vTL 4/24/2023 X 6895' JLC 4/26/2023 4/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.26 11:52:55 -08'00' RBDMS JSB 042723 JS 3S-14 SUSPEND Permit to Drill #: 202-221 Injector 3S-14 (PTD: 202-221) was drilled and completed in the Kuparuk C4 in 2003. Currently, the well is shut in for lack of offtake. It has most recently injected 4200 bwpd at 20% choke. All the producers in this well’s pattern are shut in for water and/or gas handling with low production. Subsequently, this well has been identified as a P&A candidate, to allow for slot recovery and slot optimization for Coyote Development. 3S-14 will require rig assisted P&A operations which are currently being developed. Due to 2023 rig schedule constraints and upcoming planned 3S Pad Sim-Ops, ConocoPhillips plans to perform rigless suspension operations on 3S-14 immediately, with P&A operations to follow later in the year. Suspension operations will reduce the work scope and timeline for future P&A operations, thus limiting Sim-Ops during the high pad activity planned later this year. The well is completed with 3 ½” tubing run to 6,246ft KB and a Baker SAB-3 packer set at 6,214ft KB. Perforations are at 6,560ft to 6,600ft KB. Surface casing is 9-5/8”, and production casing is 7”. Per this procedure, suspended operations will be performed by pumping 28 bbls of 15.8 ppg Class “G” cement through a cement retainer at approximately 6,232ft KB, then placing 1 bbl on top of the retainer. A tag and pressure test will confirm planned Top of Cement in tubing at ~6,117ft KB. Well Status/History: x Last MITs: MIT-T passed to 2500psi on 10/5/2015; MIT-IA passed to 1810psi on 8/13/2022; MIT-OA failed 10/18/2015 x SBHP = 3252psi @ 6,200ft SS. (10/21/2015) x Min ID = 2.75” @ 6,238ft KB (Camco D Nipple w/ 2.75” No-Go) x Last Tag: Tagged 6,654ft KB (9/30/2015) Procedure: Slickline/Little Red Services: Objective: Drift for cement retainer, perform injectivity tests to confirm adequate rates for cementing operations 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH with dummy cement retainer tool string to 6,232ft KB, or as far as possible. 4. Rig up LRS. With ~20 bbls diesel pumping down tubing, perform step rate injectivity test from 0.5 – 3 bpm, in ½ bpm increments, up to a maximum JS pressure of 3,000 psi, to ensure adequate rates for cementing operations. Record Results. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. Establish/confirm OA LLR for cement downsqueeze. 6. RDMO. Coiled Tubing / Cementing: Objective: Place a cement plug across the perforations and squeeze some cement into perforations. Cement Volume Calculations (TOC approximately 6,117ft KB in tubing): x 7” casing,100ft below perforations to bottom of tubing: (0.03826 bbl/ft) * (6,700ft – 6,246ft) = 17.4 bbls x 3 ½” tubing, bottom of tubing to TOC: (0.008696 bbl/ft) * (6,246ft – 6,117ft KB) = 1.1 bbls x Squeeze volume = 10.5 bbls x Total volume = 17.4 + 1.1 + 10.5 = 29 bbls 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Cementers a week before the scheduled Suspend date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for 29 bbls of 15.8# Class “G” cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 10/26/2015 schematic and tubing details for depth correlation. Use Camco D-nipple at 6,238ft KB for correlation. 6. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 6,232ft KB (middle of pup joint, above D- nipple), or as deep as the retainer will safely drift. 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 20 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. Pump 10 bbls freshwater spacer 11. Pump 28 bbls of 15.8 ppg Class “G” Cement through the cement retainer. If squeeze pressure is seen before pumping total cement volume, stop pumping and begin next step. 12. Shut down, un-sting from retainer 13. Lay in remaining 1.0 bbls cement above retainer (equates to ~115’ of cement above the retainer, leaving TOC ~6,117ft KB) 14. POOH above TOC. Circulate CTU clean. 15. Wash up surface equipment. RDMO. JS Slickline / Little Red Objective: State witnessed tag of TOC, MIT-T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 6,117ft KB. Record Results. TAG MUST BE AOGCC WITNESSED 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. PRESSURE TEST MUST BE AOGCC WITNESSED 7. Report issues and results to Well Interventions Engineer. 8. RDMO JS Schematic: JS Suspend Diagram: 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): 6879'None Casing Collapse Structural Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6560-6600' 6854' 5868-5905'3-1/2" 7" 16" 9-5/8" 79' 2780' Perforation Depth MD (ft): MD 108' 2556' 108' 2809' 6161'6880' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6161'6654'5954'1440 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 202-221 P.O. Box 100360, Anchorage, AK 99510 50-103-20439-00-00 ConocoPhillips Alaska, Inc. KRU 3S-14 N/AN/AKuparuk River Field N/A Tubing Grade:Tubing MD (ft): Packer: 6214' MD/5555' TVD SSSV: None Perforation Depth TVD (ft):Tubing Size: L-80 6246' 6/4/2023 Packer: Baker SAB-3 Packer SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Shane Germann shane.germann@conocophillips.com (907) 263-4597 RWO/CTD Engineer P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-234 By Kayla Junke at 3:58 pm, Apr 18, 2023 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.18 15:17:43-08'00' Foxit PDF Editor Version: 12.0.1 ADL0380106, ADL0380107 VTL 5/23/2023 SFD X 6895' KUPARUK RIVER OIL DSR-4/18/23 BOP test to 2500 psig Annular preventer test to 2500 psig SFD SFD 5/23/2023 10-407 SFD 6175' X GCW 05/24/23JLC 5/24/2023 05/24/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.24 12:33:26 -05'00' RBDMS JSB 052423 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 18, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Shane Germann Senior CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 3S-14 (PTD# 202-221). Well 3S-14 was drilled and completed as a Kuparuk Injector in December 2002. The well has been slated to be P&A'd for development of the Coyote formation. If you have any questions or require any further information, please contact me at +1406-670-1939. After a traditional Kuparuk P&A (that will have a different sundry), the tubing will be cut above tubing cement retainer/top of cement. Then a rig will come and pull the 3.5" tubing and stack two 7-1/16" valves on the wellhead. This will give eline and coiled tubing access to the 7" casing. The OA cement and final P&A details of the well will be submitted in a separate sundry. This sundry is just for the rig portion of the work that requires pulling the 3.5" tubing. Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.04.18 15:18:08-08'00' Foxit PDF Editor Version: 12.0.1 3S-14 RWO Procedure Kuparuk Injector Suspend PTD # 202-221 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Cut the tubing above tagged top of cement. 3. Prepare well for rig 48-72 hours before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3S-14. (No BPV will be install pre-rig due to internal risk assessment for N7ES for MIRU/RDMO without a BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut. a. On POOH with tubing, circulate well over to diesel freeze protect as necessary. 6. Perform 30 minute NFT. ND BOP, NU Tree 7. ND BOPE. NU two 7-1/16” tree valves and any adapter spool. 8. RDMO. Post-Rig Work - Post-rig scope will be submitted as a separate sundry for OA cement job and final P&A. 3S-14 RWO Procedure Kuparuk Injector Suspend PTD # 202-221 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 6/4/2023 Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com) Current Operations: This well is currently shut in the lower Kuparuk is P&A’d. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Stack two 7-1/16” valves for Eline and coil unit OA cement operations post-rig. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A, none recent. (Well will be P&A’d and tubing will be cut for RWO.) MIT-IA Passed to 1500 psig on 8/13/2022. MIT-OA None recent IC POT & PPPOT N/A, to be tested in pre-rig. TBG POT & PPPOT N/A, to be tested in pre-rig. MPSP: 1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Rig work should be done over P&A’d well and not exposed to formation pressure during Rig portion of work. Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 29.1 Set Depth (ftKB) 2,808.6 Set Depth (TVD) … 2,556.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 26.4 Set Depth (ftKB) 6,879.8 Set Depth (TVD) … 6,161.4 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 24.3 Set Depth (ft… 6,245.7 Set Depth (TVD) (… 5,583.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.3 24.3 0.00 HANGER FMC GEN TUBING HANGER 3.500 496.0 495.4 6.56 NIPPLE CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 6,158.9 5,505.4 26.59 NIPPLE CAMCO DS NIPPLE w/ 2.812" NO GO 2.812 6,197.2 5,539.6 26.30 SEAL ASSY LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT) 3.500 6,199.2 5,541.4 26.28 PBR BAKER 80-40 PBR 2.970 6,212.9 5,553.7 26.14 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 2.993 6,213.8 5,554.5 26.13 PACKER BAKER SAB-3 PACKER 3.250 6,218.7 5,558.9 26.08 MILL 80-40 MILL OUT EXTENSION 3.730 6,237.8 5,576.1 25.89 NIPPLE CAMCO D NIPPLE w/ 2.75" NO GO 2.750 6,244.8 5,582.4 25.82 WLEG WLEG w/ SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 6,560.0 6,570.0 5,868.4 5,877.5 C-4, 3S-14 2/1/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph 6,570.0 6,600.0 5,877.5 5,904.9 1/31/2003 6.0 IPERF 2506 PJ 2.5" HSD, 60 deg ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,113.0 5,464.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/30/2003 Notes: General & Safety End Date Annotation 12/20/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE3S-14, 10/26/2015 5:07:18 PM Vertical schematic (actual) PRODUCTION; 26.4-6,879.8 IPERF; 6,570.0-6,600.0 IPERF; 6,560.0-6,570.0 WLEG; 6,244.8 NIPPLE; 6,237.8 MILL; 6,218.7 PACKER; 6,213.8 ANCHOR; 6,212.9 PBR; 6,199.2 SEAL ASSY; 6,197.2 NIPPLE; 6,158.9 GAS LIFT; 6,113.0 SURFACE; 29.1-2,808.6 NIPPLE; 496.0 CONDUCTOR; 30.0-108.0 HANGER; 24.3 Annotation Last Tag: SLM Depth (ftKB) 6,654.0 End Date 9/30/2015 Annotation Rev Reason: TAG Last Mod By pproven End Date 10/26/2015 KUP INJ KB-Grd (ft) 32.90 Rig Release Date 12/27/2002 Annotation Last WO: End Date 3S-14 H2S (ppm) Date ... TD Act Btm (ftKB) 6,879.0 Well Attributes Wellbore API/UWI 501032043900 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 33.62 MD (ftKB) 2,355.09 3S-14 Proposed Suspended Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.06 62.5 H40 Welded Welded Surface 2808 2556 9.625 8.835 40 L80 BTC BTC Production/ Intermediate 6880 6161 7 6.28 26 L80 BTCM BTCM PROPOSED COMPLETION 3.5" Completion REMOVED Install two 7-1/16" Gate Valves (Freeze Protect when pulling 3.5" out of hole.) REMAINING COMPLETION LEFT IN HOLE P&A'd lower Kuparuk (Already done.) 3.5" Tubing Stub Top Approximately ~6120' RKB Surface Casing 7" Production Casing Conductor C and A-sand perfs ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3S-14 KUPARUK RIV UNIT 3S-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3S-14 50-103-20439-00-00 202-221-0 W SPT 5555 2022210 1500 1100 1100 1100 1100 710 890 880 875 4YRTST P Kam StJohn 8/13/2022 All good around well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3S-14 Inspection Date: Tubing OA Packer Depth 330 1810 1730 1725IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220813195401 BBL Pumped:1.4 BBL Returned:1 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:50:38 -08'00' • ✓ a2 - 22 ( ConocoPhillips 3s_ /4- Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 NOV 10 20'15 AOGCC November 7, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission SCAMED AUG 1 9 Z016 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: 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. These voids were filled with cement and corrosion inhibitor, 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ,191/1--741 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 11/7/2015 3G,3M&3S PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 3G-26 50029216960100 1990750 22" 0.4 26" 11/3/2015 2 11/6/2015 3M-03 50029216960100 2081790 SF NA 9" NA 2.6 11/6/2015 3M-04 50029216970000 1870150 12" NA 8" NA 3.7 11/6/2015 3M-25 50029224330100 1940060 12" NA 9" NA 3.2 11/6/2015 3S-14 50103204390000 2022210 64" 0.10 12" 11/3/2015 6 11/6/2015 STATE OF ALASKA ALPO OIL AND GAS CONSERVATION COMI ION • REPORT OF SUNDRY WELL OPERATIONS i 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: pAlter Casing end r Perforate r Other Stimulate � r Change Approved Program r Perforate New Pool Well Re-enter Susp Well r Other:Cond Extension V Rug for Redrill Repair 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r202-221 0 3.Address: 6.API Number: Stratigraphic r Service 50-103-20439 00 P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380106 • KRU 3S-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6895 • feet Plugs(measured) None true vertical 6175 • feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6214 true vertical 0 feet (true vertical) 5555 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 1640 630 SURFACE 2780 12 2809 2556 5750 3090 PRODUCTION 6853 10 6880 6161 7240 5410 Perforation depth: Measured depth: 6560'-6600' SCANNED MAR 0 1 -(JJ , RECEIVED True Vertical Depth: 5868'-59058 NOV 10 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 6245 MD,5582 TVD r Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PACKER @ 6214 MD and 5555 TVD �l�` NIPPLE-Camco DS Nipple w/2.875"NO GO @ 496 MD and 495.4 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F7 Exploratory r Development r Service r7i Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG p GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-430 ContactEmail n1878cop.com Printed Name MJ Loveland Titl ' Well Integrity Supervisor Signature e'✓/ 7 one:659-7043 Date 11/7/2015 VT-1- 6/6./lL /7,--7/‘ RBDMS U' 13 2015 Form 10-404 Revised 5/2015 Submit Original Only • • I ConocoPhillips RECEIVED Alaska NOV 10 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360AOG CC November 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3S-14, PTD 202-221, Sundry 315-430, conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 3S-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date 11/7/15 Event Summary 11/03/15 Welded a 12"conductor extension onto existing conductor due to rising wellhead. STATE OF ALASKA ALI.OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Rug Perforations r Fracture Stimulate n Pull Tubing 1— Operations shutdown r Performed: Suspend ri Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill Perforate New Pool Repair Well r Re-enter Susp Well 14 r Other:Starter hea repair w" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fl Exploratory r 202-221 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20439-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380106 KRU 3S-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6895 feet Plugs(measured) None true vertical 6175 feet Junk(measured) None Effective Depth measured 6707 feet Packer(measured) 6214 true vertical 6003 feet (true vertical) 5555 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108 SURFACE 2780 12 2809 2565 PRODUCTION 6853 10 6880 6161 etzivED Perforation depth: Measured depth: 6560'-6570', 6570-6600' OC I 2 0 2015 True Vertical Depth: 5868'-5878', 5878'-5905' SCANNED 1'4O V 2 3 2,0i5 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,6245 MD, 5582 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PACKER @ 6214 MD and 5555 TVD NIPPLE-Type Not Found(Manual Entry Required)@ 0 MD and 0 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P Exploratory r Development r Service PI Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data E GSTOR r VVINJ r WAG GINJ r SUSP fl SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland mail N1878CconocoPhillips.com Printed Name MJ Loveland Title WI Project Supervisor Signature i // Phone:659-7043 Date / /l6 I/TL In/ Zl/t5 P le (D/z , RBDMS OCT 212015 Form 10-404 Revised 5/2015 Submit Original Only • • ConocoPhillipsRECEIVED Alaska OCT 2 0 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 18, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7t'Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc.'s well 3S-14 (PTD #202-221) for seal welding starter head. Please call me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • S 35-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/10/15 Prep starter head for welding & install cooper heat. 10/15/15 Seal weld starter head. ! • 3S-14 DESCRIPTION OF WORK COMPLETED SUMMARY a R n. k"; .. .o*. N 5$ 'M..0 V ' 't '''' ' ' A yy S a" { 411 ' ,. 1 t Pf i - 4, -,,- , .-, 1 • of T�0, 1//7;',v?.. THE STATE Alaska Oil and Gas • 1 o T sKA ///ice` Conservation Commission • x _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �;. Main 907.279.1433 OF ALAS I. Fax: 907.276 7542 www.aogcc alaska gov SCANNED ' Martin Walters Well Integrity Supervisor 0 •)•i— aal ConocoPhillips Alaska, Inc. v P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-14 Sundry Number: 315-430 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat y P. oerster Chair DATED this 2#cfaT of July, 2015 Encl. WED STATE OF ALASKA q E C'"" ,SKA OIL AND GAS CONSERVATION COMMISSION U. 1 5 2015 APPLICATION FOR SUNDRY APPROVALS ods 7 / iS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Ferforations r Fracture Stimulate r Pull Tubing r Operations shutdown 1— Suspend Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well p Re-enter Susp Well r Other Gond Extension 1W. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc.' Exploratory r Development r 202-221 4 3.Address: Stratigraphic r Service r- 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20439-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 KRU 3S-14 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380106 - Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effectiv De th MD(ft) Effective Depth TVD ft)_ Plugs(measured): Junk(measured): 6895 • 6175 - (P7G�1' (e bpi K� Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' 1640 630 SURFACE 2780 9-5/8 2809' 2556' 5750 3090 PRODUCTION 6853 7 6880' 6161' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): 6560'-6600' _ 5868'-59058 3.5 L-80 6245 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER= BAKER SAB-3 PACKER MD=6214 TVD=5555 - SSSV=CAMCO"DS" NIPPLE MD=496 TVD=495 - 12.Attachments Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r` 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work. 9/15/2015 OIL �' WINJ r WDSPL E Suspended r 16.Verbal Approval: Date: GAS r WAG r ' GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters/MJ Loveland Email n1878@cop.com Printed Name Martin Walter, Title: Well Integrity Supervisor Signature /17(:?:4f1. Z/✓_r. / Phone:659-7043 Date 07/11/15 Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 3 /5- 1/30 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0 - 4 9 4 APPROVED BY Approved by: •11 •_'ove• application is vARYNI. DmPnths from the Z]JStMl�S vai. Date: 2-5-1 S �� ' ORIGINAL `71, 7-11S- 7f S'-- Submit Form and Form 10-403 Revised 5/2015 �� TI,� 1� AC c ments in Duplicate vrL 7/2_6// 5 r/ ,--- RBDMS' AUG - 2 2015 . . RECEIVED I` °ED ConocoPhillips X111 1 5 2015 Alaska P.O. BOX 100360 A O G C C ANCHORAGE,ALASKA 99510-0360 July 11, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3S-14, PTD 202-221 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 3S-14 (PTD 202-221) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 11, 2015 This application for Sundry approval for Kuparuk well 3S-14 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 12". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP INJ 3S-14 Conoc Phillips ; Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status Inc'(°) MD(EKE) Act Btm(ftKB) Crvrx,.7,,p+ 501032043900 KUPARUK RIVER UNIT 153 33.62 2.355.09 6,879.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-14,1220/20138:30.39AM SSSV:NIPPLE Last WO: 32.901 12/27/2002 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last 1 ag.SLM 6,657.0 12/19/2013 Rev Reason.TAG hipshkf 12/20/2013 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WI/Len(I...Grade Top Thread 1pi = CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED HANGER;24.3 :MI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread I_ SURFACE 95/8 8.835 29.1 2,808.6 2,556.1 40.00 L-80 BTC r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 26.4 6,879.8 6,161.4 26.00 L-80 BTCM Tubing Strings _ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 24.3 6,245.7 5,583.2 9.30 L-80 EUE8RD if Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top'noir) Item DesCom (in) • 24.3 24.3 0.00 HANGER FMC GEN TUBING HANGER 3.500 496.0 495.4 6.56 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 „ .. T►. .nnn.J. 6,158.9 5,505.4 26.59 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 CONDUCTOR;30.0-108.0 ' A 6,197.2 5,539.6 26.30 SEAL ASSY LOCATOR SUB&PBR SEAL ASSEMBLY(SPACED 3.500 OUT) • • 6,199.2 5,541.4 26.28 PBR -BAKER 80-40 PBR 2.970 NIPPLE;496.0 1 6,212.9 5,553.7 26.14 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 2.993 11111 • 6,213.8 5,554.5 26.13 PACKER BAKER SAB-3 PACKER 3.250 6218.7 5,558.9 26.08 MILL 80-40 MILL OUT EXTENSION 3.730 6,237.8 5,576.1 25.89 NIPPLE CAMCO D NIPPLE w/2.75"NO GO 2.750 6.244.8 5,582.4 25.82 WLEG WLEG w/SHEAR OUT SUB 2.992 Perforations&Slots • Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 1) Type Com 6,560.0 6,570.0 5,868.4 5,877.5 C-4,3S-14 2/1/2003 6.0 IPERF 2506 PJ 2.5"HSD,60 SURFACE;29.1-2,808.6 deg ph 6,570.0 6,600.0 5,877.5 5,904.9 1/31/2003 6.0 (PERF 2506 PJ 2.5"HSD,60 deg ph Mandrel Inserts - St ati C AA Top(NO) Valve Latch Part Sire TRO Ran o - No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m • GAS LIFT.6,1130 1 6,113.0 5,464.4 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 1/30/2003 Notes:General&Safety End Date Annotation 12/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;6,158.9 SEAL ASSY;6,197.2 PBR 6.199.2 - ANCHOR:6,212.9 'I-' r; - I: i- PACKER:6,213.8 MILL;6.216.7 Iuh NIPPLE;6,237.8 WLEG;6,244.8 IPERF;6,560.0-6,570.0- I IPERF;6,570.S-6.600.0 . PRODUCTION;26.4.6,879.8 Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Thursday,July 23, 2015 5:43 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3S-14: Sundry Application Total Depth 6895 RKB, 6175 TVD Effective Depth 6707' RKB, 6003 TVD MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday,July 17, 2015 12:28 PM To: NSK Well Integrity Proj Subject: [EXTERNAL]RE: KRU 3S-14:Sundry Application MJ, The information can be emailed to me. Thank you, Patricia From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent:Thursday,July 16, 2015 6:42 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 3S-14: Sundry Application Hi Patricia, Thank you for the notices. Martin is off slope on R&R but I will make sure he is made aware of all of the issues. Do you need us to re submit? I'm on vacation this week so it would be next week before I get to it. Thanks MJ MJ Loveland/Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 1 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, July 16, 2015 9:29 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]KRU 3S-14: Sundry Application Good morning Martin, Please advise what the current plug back depth is for the KRU 35-14 well, both MD and TVD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 Bettis, Patricia K (DOA) 'P I J 2u —22 From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Sunday,July 19, 2015 10:04 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3S-14: Sundry Application Ok Thank you. I'll get it to you late this coming week as It is difficult to access our information from home. Thanks again. MJ From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, July 17, 2015 12:28 PM To: NSK Well Integrity Proj Subject: [EXTERNAL]RE: KRU 3S-14: Sundry Application MJ, The information can be emailed to me. Thank you, Patricia From: NSK Well Integrity Proj mailto:N1878@conocophillips.com g Y [ ] Sent:Thursday,July 16, 2015 6:42 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 35-14: Sundry Application Hi Patricia, Thank you for the notices. Martin is off slope on R&R but I will make sure he is made aware of all of the issues. Do you need us to re submit? I'm on vacation this week so it would be next week before I get to it. Thanks MJ MJ Loveland/Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis©alaska.gov] Sent: Thursday, July 16, 2015 9:29 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]KRU 3S-14: Sundry Application 1 Good morning Martin, Please advise what the current plug back depth is for the KRU 3S-14 well, both MD and TVD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,July 16, 2015 9:29 AM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 3S-14: Sundry Application Good morning Martin, Please advise what the current plug back depth is for the KRU 35-14 well, both MD and TVD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday,July 04, 2015 10:22 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Kuparuk Injector 3S-14 (PTD #202-221) Surface casing thread weep Attachments: 3S-14.pdf; 3S-14 90 Day TIO plot.JPG Follow Up Flag: Follow up Flag Status: Completed Chris- Kuparuk Injector 35-14 (PTD#202-221) was identified to have a surface casing thread weep. Operations reported a "diesel" odor and upon inspection the threads just below the flues of the surface casing had a very minor weep. The threads were cleaned and after several minutes were damp again. The OA was bled to—50 psi to minimize the weeping from the threads until the repair can be completed. An MIT-IA is scheduled today to prove the integrity of the tubing and production casing. If tubing and production casing integrity is proven CPAI will initiate a welding package to repair the weeping threads. Because the leak is just a minor thread weep it is CPAI's intention to leave the well on water injection only until the welding package and repair can be completed. Does CPAI need to submit an AA request for water injection with OAxAtmosphere until the repair can be completed or can CPAI request a grace period in which would allow the repair to be completed without having to submit and cancel the AA after the repair? Attached are the well bore schematic and a 90 day TIO plot. Cheers, Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM conocoPhinips s04ED AUG 0 4 2016 w U ccw u, C7 in Q U V) W cc CL u_ 0 o en Vo ce a p o a al W m h `cue CL CY H </7 W w.N ca i J J A6op • f• ,- .- G U V CJ ^� cn .T 1 u, w C C t0 ru u, v1.... i , , i , c I -_� a, C co0 , ! {C C E Q W W U i z 1m I CU o C z Q r. f-- •y `Q Lei inr V7 C-.4 Q7 N 1 i # '- agar ( u,cu — w j 01) {9 c 23 cJ o o . o 0 0 0 , .'_ O CS o 0 0 0 o o Fi ` Ci ll 0 CD 411 t N r, r, N [Y 1- clam 10i0Y1 >,-. !sd > `n o w MEMORANDUM To: gg Jim Re i P.I. Supervisor ~~~~ ~ll ~1 ~~ FROM: BOb Noble Petroleum Inspector Mate of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3S-14 KUPARUK RIV iJNIT 35-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv g~' Comm Well Name: KUPARUK RIV UNIT 3S-14 Insp Num: mitRCN10080915104s Rel Insp Num: API Well Number: 50-103-20439-00-00 Permit Number: 202-221-0 Inspector Name: Bob Noble Inspection Date: g/~/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3saa ' Type Inj. "/~ TVD ssss IA 3~o Isso Ipso I~6o P.T.D zo22uo ~ TypeTest SPT Test psi Isso pA 3ao aso aso a6o Interval aYRTST p/F P Tubing Ilso Ilso Ilso Ilso , Notes: M s ,~ ~ ~~ j 'G~ ~t'Sfi i 5 ~Fs; f r4 T' ~..a~aa ~~:~wx .. .. }rij Tuesday, August ]0, 2010 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commi~ TO: Jim Regg P.I. Supervisor , I.. ¡ _' ~ (, I~DI¡)Y . F-., ¿"N ¿-'l/ \) (,> DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3S-14 KUPARUK RIV UNIT 3S-14 dP¥ ~\ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: .~ P.I. Suprv .~ I':> Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3S-14 API Well Number 50-103-20439-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060829124426 Permit Number: 202-221-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S-14 Type Inj. w TVD I 5555 IA 850 2610 2530 2520 2520 P.T. 2022210 TypeTest SPT Test psi I 1500 OA 400 550 550 550 550 Interval 4YRTST PIF P ./ Tubing 2000 2000 2000 2000 2000 Notes 1.3 BBLS diesel pumped. I well house inspected; no exceptions noted. S(;ANNED SEP () 82GGB Wednesday, August 30, 2006 Page I of 1 . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 ,\. :~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 ao'ð-- ~~\ Ô S... \ l..\- r ç! -0 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, ~ ~~~ ConocoPhillips Well Integrity Supervisor Attachment r . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 7,2006 Well Name Initial top Vol. of cement Final top of Cement top prD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3S-14, February 19,2004 /3LÇ;8D AK-MW-22198 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-14: Digital Log Images 50-] 03-20439-00 ~()~_~~I 1 CD Rom t ~~-l~~ . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc / ¡v'lC1V\ ^,-Ò ~ \ DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2022210 Well Name/No. KUPARUK RIV UNIT 35-14 Operator CONOCOPHILLlPS ALASKA INC MD 6895 /' 1VD 6175 / Completion Date 2/1/2003 /' Completion Status WAGIN REQUIRED INFORMATION Mud Log No Samples No -- DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens-Neutron Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Uó D ~'pt , Rpt I /-Log I ~~g J-og L '\~.¡;Cí-/ I g lffi- - 0 -ßPt'- ,- / ¿/ED 0 / 10 C Las o/ÉD C Pdf ~- Well Cores/Samples Name Log Log Run Scale Media No Directional Survey LIS Verification 1 2 Directional Survey c.pressure 5 BJu .:7'Temperature Blu 5 trGradiometer 5 Blu ~ment Evaluation 5 11684 ~ Vt::rific;i:1liun ~ 11. t;v..J ~1 C i\i ~ S t.. D ~ôv-' Col LIS Verification 11684 liS Verif~:1tion ~ r~ ~ L\J "It,::. (f..//'¡ J J". ð; vz. d P - 2 12475 Injection Profile 12475 Injection Profile ¿..Jnjection Profile Information: BM Interval Start Stop Sent Received Current Status WAGIN Jþ",,¿ ! i I~ ~(f ~À. API No. 50-103-20439-00-00 UIO- --- Directional surveyG~ _/ (data taken from Logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments 0 6895 Open 1/9/2003 52 6862 Open 7/24/2003 REPLACES DATA RCVD 04/17/2003 0 6895 Open 1/9/2003 6380 6657 Case 2/14/2003 Crossflow Determination Log 6380 6657 Case 2/14/2003 Crossflow Determination Log 6380 6657 Case 2/14/2003 Crossflow Determination Log 6064 6672 Case 2/14/2003 52 6862 Open 4/17/2003 REPLACED BY NEW DATA RCVD 07/24/2003 52 6862 Open 4/17/2003 REPLACED BY NEW DATA RCVD 07/24/2003 52 6862 Open 7/24/2003 REPLACES DATA RCVD 04/17/2003 6190 6667 Case 3/22/2004 MI Injection Profile 6190 6667 Case 3/22/2004 MI Injection Profile 6190 6667 Case 3/22/2004 MI Injection Profile Sample Set Number Comments .~ ~ Permit to Drill 2022210 MD 6895 TVD 6175 ADDITIONAL INFORMATION 0'- Well Cored? Y ø ...... Chips Received? Y 1 N Analysis Received? '-----' Y/N Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3n/2005 Well Name/No. KUPARUK RIV UNIT 35-14 Operator CONOCOPHILLlPS ALASKA INC Completion Date 2/1/2003 Completion Status WAGIN Daily History Received? Formation Tops ~ API No. 50-103-20439-00-00 Current Status WAGIN f""-. ON r,_ (®N Date: UIC Y ---, ;¿ ~ GVL~ ÀL~ S-- .~ dOd -z;¿~ l clr3s II- ) WELL LOG TRANSMITTAL ) ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage. Alaska 99501 RE : Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 3&14 2-24-04 Res. Eva!. CH 1 J f) J-I "1-- s 1 1 Mech. CH Signed: ~:J ' "~ " '\~ c \.'- Ç. -Y"'\.. \ ~ \. L QJ :~ CC' 'Y\ RECEIV"EU 1 Rpt or 2 Color Caliper Survey Date: ""~¡~ p 2? 0004 I ~ ,~, :..... L ",I),}aska 0;' & Gas Cons. Commiaion An~age Print Name: PRoACTivE DÌAGNOSTic SERviCES, INC., PO ßox 1 ~69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~\'{\ (~ STATE OF ALASKA 1 ALASKA OIL AND GAS CONSERVATION COMMISSICJI\I REPORT OF SUNDRY WELL OPERATIONS ~~~¡~~<g¡~!:,!:~f~~~i~~lp;~,í S::¡~~~:~}§,~n~~:'g :'::A;··cû:rl'etit Wén.statûs:'"::: ..;""! -:.>:':;:;:'-::-'.;/ ".; .:'''';''''':'''':!J:.,.,;~ 5. Permit to Drill Number: , ,~·",,:~~t:~i~:g!':','~t~~g;,>:'; 6. API Num::-221I r.. ,,"', . 50-103-20439-00 9. Well Name and Number: 3S-14 ':~f;;::~~¡~ï~~~:';^'B:;t'l~¡ll:'g'~: 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 56' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 6895' feet true vertical 6175' feet measured 6707 feet true vertical 6003 feet Length Size MD 108' 16" 108' 2779' 9-5/8" 2808' 6853' 7" 6879' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2556' 61611 Measured depth: 6560-6570; 6570-6600 RECEIVE'D FEB 0 3 2004 Alaska Oîl & Gas Cons. Cmnrmssion Anchorage true vertical depth: 5868-5878; 5878-5905 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6246' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 496' 12. Stimulation or cem(3ht squeeze summary:'.. . Intervals tr.eated (me~$ured) N/A Treat~ent descriptions including volUmes used arid final pressure: 13. Representative Daily Average Production.or Injection Data Oil-Bbl Gas-Met Water-Bbl Casiri8,'pressure Tubinq Pressure Prior to well operation 7678 . 133~ 2345 Subsequent to ope~ation . 10673 1333 3291 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ::::~N~ame~< ...... ¡Ø'fSÞb(l~C!ér(!~:*Q~~226 Signature . ... , ..-1 .Á.., T...·.itle. .. P.ro. d..·..uotion .E¡j(inee(in~Te()h.·...ni~Cia .·····i: ... . Phone 659;'7535 Date Y$tJ t) U LJ \ r~\NAL .-8fl ~ B-ìOO~ :\ \.J SUBMIT IN DUPLICATE Form 10-404 Revised 2/2003 · STATE OF ALASKA J ALASKA OIL AND GAS CONSERVATION COMMISSICJI'I REPORT OF SUNDRY WELL OPERATIONS j;:~\jr~j;~~~.::8'::";!,¡tt~{·~i\~~~i~~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 56' ..: , ::~. ~ . . , .'. .... .. :.. . ...... 50-103-20439-00 9. Well Name and Number: 38-14 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 6895' feet true vertical 6175' feet measured 6707 feet true vertical 6003 feet Length Size MD 108' 16" 108' 2779' 9-5/8'1 2808' 6853' 7" 6879' Plugs (measured) Junk (measured) Burst Collapse TVD 108' 2556' 61611 Measured depth: 6560-6570; 6570-6600 RECEIVE'D FEB 0 3 2004 true vertical depth: 5868-5878; 5878-5905 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6246' MD. Alaska Oil & Gas Cons. Gmnmïssion Anchorage Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 496' 12. Sti.mulationor c.em'eht squeeze summary: . . Intervals treated (measured) N/A Treat~ent descriptions including vol.umes used and final pressure: 13.Hepreserytative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure· Prior to well operation 7678 133~ 2345 SlIbsequent to operation 10673 1333 3291 14. Attachl1)ßnts . 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: ()il[~] Gas D WA§0 G'.N~D wlNJD WDSPLD· 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: :~:N~aïne~·.....a7ff$Pt~~c!er?~~:~~~226 Signature . . . /fÅ..i .. . T....·..i.tt.e.. ... .. P.r.od..ucti.O. n Engineering... Tec~....n. i~..C. ia.' ... .i: ,.. Phone 659;;7535 Date Y$/J t) " ~ O ~ , G \ N A L ... u .. 'U~,t¡I, fIIIiS BFl ...-0'· i·.~~~, i SUBMIT IN DUPLICATE Form 10-404 Revised 2/2003 · ) y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 9950 I ) '~~CS/J ~ (".' V€D A ·0'/ VIJlIrIJ()¡/.. : 200J & GaS a ~, Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top ofcement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. ;; ~~¡ MJ~ / ConocoPhillips Problem Well Supervisor Attachment :t:.\. \ -:> t"-<)~ «. ~,10~ ~~ ~''-Q. ""'l'\.\-' +0 'f ~\\ 'oÇJ..c.\<-" cM~ç ~~~~ '>~~ c¡,,,,,~-.) \ \...., '-<l.. ""«-,,,~d -\0 S~~. 14\\ o~-\-~ "T~<"'(( ~~~~~~ \::>Q..~'ï f\Qo.\ +"'-<ë. S\...)~~. ~ o.Çù ~-+ "'-<L' C\. c..~ \ 0 '"' t'\((.C!.<:b<J..' 'i ßS3-¥(\JÁ-Ö~ ' ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well TOC Volume 8acks Name PTD# Type ft BBLS Cement 38-03 2030910 Prod 8 0.6 3.6 38-07 2021870 Prod 8 1.5 9.1 38-09 2022050 Inj 14 2.5 15.1 38-10 2022320 Prod 12 1.5 9.1 38-14 2022210 Inj 3 1.5 9.1 3S-15 2022540 Prod 8 0.8 4.8 3S-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 38-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 3S-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0.3 1.8 ) ) ~~. ?-t}-\ \ \ to 8tf WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 03, 2003 RE: MWD Formation Evaluation Logs 3S-14, AK-MW-22198 1 LDWG formatted Disc with verification listing. API#: 50-103-20439-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Dri11ing Service Attn: Jim Galvin ~~~~\tfiP JUL 24 2003 ~Alsa_œ&GasCons.Commis8ÍOnS·o ed- M, /It. ¿ U!I'œ:"- Anellora!(: 1"n . v....· -'V' ð . Note: This Data Replaces Any Previous Data FOB" Well 38-14. .~ ) ) éle-a='*t-&? { llo'(tf ~CJÀ.--~~l WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Aprilll, 2003 RE: MWD Formation Evaluation Logs 3S-14, AK-MW-22198 1 LDWG formatted Disc with verification listing. API#: 50-103-20439-00 PLEASE ACKNOWLEDGE RECEIPT .BY SIGNING AND RETURNING THE ATTACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~- SignU~6.(1(J~ RECE\VED APR 1 7 2003 .Alaska O¡-i & Gas Cons. Commtsston Anchorage ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich ~ 'W·/63 DATE: February 23,2003 Commissioner 'L/ 1. \) 1ft.9v\^ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder - .. I v \ ~ Conoco Phillips P.I. Supervisor ,:.,\ ~ b~~ ' 3'S Pad KRU ) MEMORANDUM FROM: Chuck Scheve Petroleum Inspector NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 38-09 Type Inj. 8 T.V.D. 5590 Tubing 2325 2325 2325 2325 Interval I P.T.D. 202-205 Type test P Test psi 1398 Casi ng 0 1875 1800 1800 P/F f Notes: Well 38-14 Type Inj. 8 TV.D. 5555 Tubing 2250 2250 2250 2250 Interval I P.T.D. 202-221 Type test P Test psi 1389 Casing 775 1900 1850 1850 P/F f Notes: Well 38-26 Type Inj. 8 TV.D. 5749 Tubing 2400 2400 2400 2400 Interval I P.T.D. 201-040 Type test P Test psi 1437 Casing 25 1625 1600 1580 P/F f Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover 0.= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to Conoco Phillips 38 Pad in the Kuparuk River Field and witnessed the initial :MIT on wells 38-09, 38-14 and 38-26. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all three wells demonstrating good mechanical integrity. M.I.T.'s performed: ª Attachments: Number of Failures: º Total Time during tests: 5 hours cc: MIT report form 5/12/00 L.G. MIT KRU 3S Pad 2-23-03 CS.xls 2/27/2003 ') ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conocó'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 February 12, 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 for 3S-14 (APD # 202-221) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations for the Kuparuk well 3S-14. If you have any questions regarding this matter, please contact me at 265-6830 or Scott Lowry at 265-6869. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CP AI Drilling RT/skad i'~~'I'~S6~'~'~"' ,.J1.\; \'" ~ ~', \ ~ !~"';...:. ~ ....,.': ", '.i ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas 0 Suspended 0 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Aband9r!E!9: .p ",,'. I: ; ~, 2.. I· O,.3~: 1; ~:I;D \Flf;)) t ~~ :.. :' ,'.' -, ..~"".'-''"'" ~ ~'~"·,""I '" \""'~1i' '-':MI,,'toi"'\~"~'~!~M...~~f¡:- Classification of Service Well MW AG injector 7. Permit Number 202-221 8. API Number 50-103-20439 9. Unit or Lease Name (ASP:476188, 5993897) Kuparuk River Unit 10. Well Number 2519' FNL, 1071' FEL, Sec.18, T12N, R8E, UM At Top Producing Interval 220' FSL, 1555'FEL,Sec.7,T12N,R8E,UM At Total Depth 351' FSL, 1595' FEL, Sec. 7, T12N, R8E, UM (ASP: 475674, 5996769) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 28' RKB , Pad 24.2' ADL 380106 ALK 4623 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore December 18, 2002 December 23, 2002 De~02 Z... I· ()~ N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 6895' MD / 6175' TVD 6707' MD / 6003' TVD YES 0 No 0 DS nipple @ 496' (ASP: 475704, 5996637) 22. Type Electric or Other Logs Run G R/Res/Dens-Neutron 23. 3S-14 11. Field and Pool Kuparuk River Field Kuparuk River Field / Pool feet MD 16. No. of Completions 1 21. Thickness of Permafrost 1626' CASING SIZE WT. PER FT. 16" 62.58# 9.625" 40# 7" 26# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Suriace 108' Suriace 2809' Suriace 6880' HOLE SIZE 42" 12.25" CEMENTING RECORD AMOUNT PULLED PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period> Calculated OIL-BBL 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 6560' - 6570' MD 5868' - 5878' TVD 6 SPF 27. Date First Production N/A Date of Test N/A Flow Tubing Hours Tested Casing Pressure 24-Hour Rate> 28. 9 cu yds High Early 570 sx AS & 250 sx LiteCrete 8.5" 246 sx Class G w/GasBlok 25. SIZE TUBING RECORD DEPTH SET (MD) 6246' PACKER SET (MD) 6214' 3.5" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A WATER-BBL CHOKE SIZE GAS-OIL RATIO GAS-MCF WATER-BBL OIL GRAVITY - API (corr) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. r= tì~ ~ \'t:U tL,~ None c~~ Gr Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~MS BFl \ ' " \i '~" ¡,; 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 Kuparuk Base Kuparuk 6559' 6597' 5867' 5902' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869 Signed~ ~ Randy Thotas -- .11103 Kuparuk Drilling Team Leader Date ¿ (( ?:.. ( ó 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 (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 ) ) COnocoPh illipsAlaska . c>perations$u m maryRèport Moved Out Mud Pits Pad Maintanence Leveled Pad for Rig Pulled Rig from 3S-09 and Spotted Over 3S-14 Spotted Mud Pits NU 12 1/4" Divertor Knife Valve & 16" Line, Moved Ball Mill & Hooked Up Same, Fill Pits with Water @ 14:00 Hrs, Move In Injection Module & Tank, Berm Cellar & Ball Mill Accepted Rig at 14:00 Hrs 12/17/02 Changed Out Lower Well Control Valve & Actuator on Top Drive Trouble Shoot & Fix Torque Boost & Brakes on Top Drive Service Top Drive, Break Out & Make Up New Saver Sub & Install Clamps PU Mud Motor, MU Bit #1, Adjust MM to 1.5 Deg, MU Std of HWDp & TIH, Tagged at 89' Function Test Divertor & Koomey Unit, Good Test, Note: Jeff Jones with AOGCC Waived Witnessing of Test Stood Back Std of HWDP & Cont MU BHA to Welded Blade Stab, MU Std of HWDP to Press Test Surface Lines Trouble Shoot Top Drive Rotating Handler, Replaced Handler Hyd Motor Filled Hole, Checked Flowline & Riser, Break Circ & Pressure Tested Surface Lines to 3,000 Psi, Ck Ok. Wash & Reamed Down from 89' to 108' Spud Well @ 11 :30 Hrs 12/18/02, Drilled 12 114" hole Per Directional Plan from 108' to 1,183' MD/1, 153' TVD, ART 5.2 Hrs, AST 3.7 Hrs, 35-40K WOB, 80 Rpm's, 411 Gpm's @ 1,400 Psi, Rot Wt 73K, PU Wt 75, Dn Wt 70K 16.00 DRILL DRLG SURFAC Drill 12 1/4" Hole Per Directional Plan from 1,183' to 2,820' MD/2,566' TVD, ART 7.25 Hrs, AST 2.25 Hrs, 35-40K WOB, 80 Rpm's, 549 Gpm's @ 2,300 Psi, Rot Wt 93K, PU Wt 100K, Dn Wt 82K, Off Btm Torque 4k Ft#'s, On Btm 7,500 Ft#'s @ 2,700' Pumped Hi Vis Nut Plug Sweep with Minor Increase in Cuttings Pumped Hi Vis Barafiber Sweep, Had Minor Increase in Cuttings, Circ Hole Clean @ 549 Gpm @ 2,300 Psi & 100 Rpm's, Sweeps Came Up on Calc Strokes Monitored Well-Static, Blew Down Top Drive & POOH Wet to BHA (897'). No Problems, SLM No Corr Monitored Well @ BHA-Static, POOH & LD BHA #1, Cleared Rig Floor Started to Ru to Run 9 5/8" Csg, Changed Out Elevator Bails Fin Ru Nabors Csg Equipment & GBR Fill up Tool, Held PJSM MU 95/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, While RIH with Csg, Started taking Wt at 1,580', Attempted to Circ & Fill Up Tool Malfunctioned 3.50 CASE RUNC SURFAC LD Fill Up Tool & MU Circ Swedge, Washed & Worked Csg Thru Base of Permafrost from 1,580' to 1,780', MU Fill Up Tool with Check Valve Removed 2.00 CASE RUNC SURFAC Cont RIH with 95/8" Csg, Landed Csg in Head - Ran a Total of 66 Jts to 2,808.61' Landed Csg wI FS @ 2,808', FC @ 2,723'. 0.50 CASE RURD SURFAC RD Fill Up Tool & MU Cmt Head 2.00 CEMENTCIRC SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 72, YP from 48 to 23, 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 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-14 3S-14 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Date Sub . From- To Hours Code Code Phase 12/17/2002 06:00 - 08:00 2.00 MOVE DMOB DEMOB 08:00 - 09:00 1.00 MOVE DMOB DEMOB 09:00 - 11 :30 2.50 MOVE MOVE MOVE 11 :30 - 12:00 0.50 MOVE RURD RIGUP 12:00 - 18:30 6.50 MOVE RURD RIGUP 18:30 - 00:00 5.50 RIGMNT RGRP SURFAC 12/18/2002 00:00 - 02:00 2.00 RIGMNT RGRP SURFAC 02:00 - 03:30 1.50 RIGMNT RSRV SURFAC 03:30 - 04:30 1.00 DRILL TRIP SURFAC 04:30 - 05:00 0.50 WELCTL BOPE SURFAC 05:00 - 06:30 1.50 DRILL TRIP SURFAC 06:30 - 1 0:30 4.00 RIGMNT RGRP SURFAC 10:30 - 11 :00 0.50 DRILL OTHR SURFAC 11 :00 - 11 :30 0.50 DRILL REAM SURFAC 11 :30 - 00:00 12.50 DRILL DRLG SURFAC 12/19/2002 00:00 - 16:00 16:00 - 18:00 2.00 DRILL CIRC SURFAC 18:00 - 21 :00 3.00 DRILL TRIP SURFAC 21 :00 - 23:00 2.00 DRILL TRIP SURFAC 23:00 - 00:00 1.00 CASE RURD SURFAC 12/20/2002 00:00 - 01 :00 1.00 CASE RURD SURFAC 01 :00 - 04:00 3.00 CASE RUNC SURFAC 04:00 - 07:30 07:30 - 09:30 09:30 - 10:00 10:00 - 12:00 Start: 12/17/2002 Rig Release: 12/27/2002 Rig Number: Spud Date: 12/18/2002 End: Group: Description of Operations Printed: 1/10/2003 1:06:39 PM ) ) Ce>nocoPhillipsAlaskä· Operatiol1$ Sul11m:âryRE!p.ort 2.00 CEMENT PUMP SURFAC RU Dowell, Pumped 5 bbls CW 100 Chern Wash, Tested Lines to 3,500 Psi, Pumped 45 bbls CW 100 Chern Wash at 8.3 ppg, 5.5 Bpm @ 155 Psi, Dropped Btm Plug, Pumped 38 bbls of 10.5# Mudpush spacer @ 3.0 bpm @ 125 Psi with Red Dye in Spacer, Mixed & Pumped 435 bbls, 570 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 140 Psi, Reciprocated Pipe until cmt. to surface, then Pipe got Tight-Landed Pipe, Observe Nut Plug and Red Dye Markers at Shakers, Pumped Lead Cmt until Cmt to Surface-31 bbls Late. Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield, Pumped @ 6 Bpm @ 275 Psi, 0.50 CEMENT DISP SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 185.6 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 780 Psi, Slowed to 3 bpm @ 430 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 227 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 14:30 Hrs 12/20102 Checked Floats & Held, RD Cmtg & Csg Equipment, LD Landing JT Flushed Divertor System with Water Cleaned Rig Wind Walls & Mud Pits ND 21 1/4" Divertor & 16" Line & Removed Starting Head Installed FMC 11" 5M Gen V Wellhead & 11" 5M Tbg Spool & Set on BOP Stack, NU Wellhead & Tbg Spool & Tested Seals to 1,000 Psi, Good Test NU 13 5/8" 5M, BOP Stack, Trim Up 16" Riser RU to Test BOP's Tested BOP's, Tested Rams, All Valves, Choke Manifold & Rams with 7" Test Jt to 250 Psi Low & 5,000 Psi High, Tested Annular to 250 Psi Low & 3,500 Psi High, Good Test. NOTE: Chuck Scheave with AOGCC Waived Witnessing of BOP Test RD 7" Test Jt, Installed Wear Bushing, Blow Down Choke & Kill Lines Serviced Rig & Top drive Rig Down to Repair IBOP on Top Drive PU & MU 8 1/2" Directional BHA #2, Upload MWD, Pulse Test & Load Radioactive Source TIH & Tagged Cmt at 2,681' (FC @ 2,723') Circ Btms Up & Evened MW In & Out at 9.4 ppg Tested 95/8" Csg to 2,500 Psi for 30 Min, Good Test Drilled Soft-Med Cmt to Float Collar, Drilled Plugs, Fit Collar, Shoe Trac & Float Shoe & 20' of New Form to 2,840' MD/2,583' TVD Circ Btms Up And Displaced Spud Mud with New 9.3 ppg LSND Mud RU & Performed LOT, Formation Broke Down at 935 Psi with 9.3 ppg Mud for a 16.3 ppg EMW Drilled 8 1/2" Hole Per Dir Plan from 2,840' to 4,347' MDI 3,900' TVD, ART 6.75 Hrs, AST .25 Hrs, Raised MW Per Wt Up Schedule from 9.3 ppg to 10.0 ppg While Drilling. 10-20K WOB, 115 Rpm's, 585 Gpm @ 2,450 psi On Btm, 2,000 psi Off Btm with 11.6 ECD, Max Gas 8 Units, Rot Wt 118K, PU Wt 143K, Dn Wt 105K, Off Btm Torque 6K Ft #'s, On Btm 7K 12.00 DRILL DRLG PROD Drilled 81/2" Hole from 4,347' to 5,682' MDI 5,086' TVD, ART 6.75 Hrs, AST 1 Hr, Raised MW from 10.0 ppg to 10.6 ppg. 10-20K WOB, 115 Rpm's, 585 Gpm @ 2,750 psi On Btm, 2,400 psi Off Btm with 11.9 ECD, Max Gas 14 Units, Rot Wt 135K, PU Wt 175K, On Wt 105K, Off Btm Torque 8.5K Ft #'s, On Btm 10K (Last 24 Hrs Total RT 13.5 Hrs, Total ST 1.25 Hrs) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-14 3S-14 ROT - DRILLING n 1268@conocophillips.com Nabors 7ES ..Datè Sub Frorn..; To Hours Cocje Code Phase 12/20/2002 12:00 - 14:00 14:00 - 14:30 14:30 - 17:00 2.50 CEMENT RURD SURFAC 17:00 - 17:30 0.50 CEMENTOTHR SURFAC 17:30 - 19:30 2.00 RIGMNT RSRV SURFAC 19:30 - 22:00 2.50 WELCTL NUND SURFAC 22:00 - 00:00 2.00 WELCTL NUND SURFAC 12/21/2002 00:00 - 03:30 3.50 WELCTL NUND SURFAC 03:30 - 04:30 1.00 WELCTL BOPE SURFAC 04:30 - 09:30 5.00 WELCTL BOPE SURFAC 09:30 - 10:30 1.00 WELCTL BOPE SURFAC 10:30 - 12:00 1.50 RIGMNT RSRV SURFAC 12:00 - 13:00 1.00 RIGMNT RGRP SURFAC 13:00 - 16:00 3.00 DRILL PULD SURFAC 16:00 - 17:00 1.00 DRILL TRIP SURFAC 17:00 - 18:00 1.00 DRILL CIRC SURFAC 18:00 - 19:00 1.00 DRILL DEaT SURFAC 19:00 - 22:00 3.00 DRILL DRLG SURFAC 22:00 - 23:00 1.00 DRILL CIRC SURFAC 23:00 - 00:00 1.00 DRILL LOT SURFAC 12/22/2002 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 Page20f 6 Start: 12/17/2002 Rig Release: 12/27/2002 Rig Number: Spud Date: 12/18/2002 End: Group: Description of Operations Printed: 1/10/2003 1 :06:39 PM .) ) CpnocoPhillips Alaska Operations Summary Rep.ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-14 38-14 ROT - DRILLING n1268@conocophillips.com Nabors 7E8 Date 8ub From;;. To Hours Code Code Phase 12/23/2002 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 06:00 2.00 DRILL CIRC PROD 06:00 - 16:00 10.00 DRILL DRLG PROD 16:00 - 19:30 3.50 DRILL CIRC PROD 19:30 - 00:00 4.50 DRILL DRLG PROD 12/24/2002 00:00 - 02:00 2.00 DRILL CIRC PROD 02:00 - 02:30 0.50 DRILL OBSV PROD 02:30 - 04:00 1.50 DRILL CIRC PROD 04:00 - 09:00 5.00 DRILL TRIP PROD 09:00 - 10:00 1.00 RIGMNT RSRV PROD 10:00 - 12:00 2.00 DRILL TRIP PROD 12:00 - 12:30 0.50 RIGMNT RGRP PROD 12:30 - 13:30 1.00 DRILL TRIP PROD 13:30 - 16:30 3.00 DRILL CIRC PROD 16:30 - 21 :30 5.00 DRILL TRIP PROD 21 :30 - 22:30 1.00 DRILL TRIP PROD 22:30 - 23:00 0.50 DRILL TRIP PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 12/25/2002 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 03:00 0.50 CASE OTHR PROD 03:00 - 04:30 1.50 CASE RURD PROD 04:30 - 05:00 0.50 CASE SFTY PROD 05:00 - 09:00 4.00 CASE RUNC PROD 09:00 - 09:30 0.50 CASE CIRC PROD Page30f 6 Start: 12/17/2002 Rig Release: 12/27/2002 Rig Number: Spud Date: 12/18/2002 End: Group: Description ofOþerations . Drilled from 5,682' to 6,063' ART 2 hrs, AST 0 hrs UP 190K, DN 130K, ROT 145K, WOB 1 0-15k, TQ 11 K on btm- 7K off btm, Gas 10-20 units Circ. & Displace hole with New 12.3 ppg LSND Mud Drilled from 6,063' to 6,635' MDI 5,936' TVD, ART 8 Hrs While Making Conn @ 6635' Torqued Up & Pulled 15K over, Slacked off & Only had Partial Returns Monitored Well, Slight Breathing, Circ Btms Up While Adding LCM (10 ppb Wallnut, 10 ppb Barofibre, 10 ppb Batoseal fine, 5 ppb Barofibre medium), Started Pumping at 2 BPM @ 320, Increased Rate to 10 Bpm @ 1,900 Psi with Approx 15-30 ppb LCM with 75% Returns, Worked Pipe with No Problem, Losses ranging from 38 to 13 bph Drilled from 6,635' to 6,895' MDI 6,175' TVD, TD, ART 4.5 Hrs, Circ at 420 GPM @ 2,280 Psi, 105 RPM's, ROT Wt 155K, PU Wt 195K, Dn WT 130K, Off Btm Torque 9,500 Ft#'s, On Btm 12,000 Ft#'s 10-20K WOB AVe BGG 20 Units, Lost Approx 275 bbls of Mud While Circ & Drlg- Losses ranging from 80 bph to a gain of 11 bph, Est Top of Kup "C" 6,560' MDI 5,868 TVD Pump 30 bbl Hi Vis sweep, circ hole clean. No increase in cuttings. Circ @ 420 GPM & 1810 psi. ECD's @ 12.6 ppg. Rotate wi 115 rpm. MW in & out 12.0 ppg. Lost approx 10 bbls wi circulating. Monitor well fl 30 min. Well gave back approx 5 bbls. Slowed down to two finger witdths in 30 min. Circ and condition mud and hole. On bttm's up: max gas units 69 and only lasted a few minutes wi circ @ 425 gpm wi 1785 psi, rotating 115 rpm. ECD's 12.5 ppg. No mud losses. Pumped 12,000 stokes (2+ BU). Monitored well-- slight movement. Rot wt 145 k SO wt 135 K PU wt 215 k Monitor well. POOH fl short trip to shoe. Trip was good. Monitor well @ shoe wi service top drive. Clean rig floor. RIH slow. Monitor returns. Repair iron roughneck. Continue RIH slow to 6824'. Precautionary ream fl 6824' to TD @ 6895' (71'). No problems. Circulate BU. Max gas units 184. Pump Hi vis sweep. Circ hole clean--no noticable increase in cuttings. Spot "Steel Seal" pill on bttm (125 bbls wi 15 ppb LCM pill with 5#/bbl Barofibre, 7#/bbl Liquid casing, 3#/bbl Baroseal fine, above 50 bbl20 ppb Steel Seal), Estimated mud loss wi circ. 6 bbls. Slowly POOH 10 stands. Monitor well. Pump dry job. Blow down top drive. Continue POOH, SLM, no correction. Monitor well @ 95/8" csg shoe(2808'). No problems. All looking good. Continue POOH to BHA. Monitor well. Lay down DC's. PJSM wi Sperry Sun on radioactive sources. Lay down sources. Download MWD. Total losses on trip out = 8 bbls over calculated. UD BHA, clean rig floor. Pull wear bushing. RU to run 7" casing. PJSM on running 7" 26# L-80 BTC-Mod. Run 7" 26# L-80 BTC-Mod casing to jt # 66 2794'. Good displacement. Circ bottoms up @ 9 5/8" casing shoe wi Frank's fillup tool. No losses. 65 spm = 350 psi. PU wt 95 k SO wt 55k Printed: 1/10/2003 1:06:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) ConocOPhillips Alaska Operation~$ummaryRep()rt 3S-14 3S-14 ROT - DRILLING n1268@conocophillips.com Nabors 7ES PáÇ}e 40fß Start: 12/17/2002 Rig Release: 12/27/2002 Rig Number: Spud Date: 12/18/2002 End: Group: Date From;,. To Hours C. ode. Sub Phase Code Description of Operatiþns 12/25/2002 09:30 - 11 :30 2.00 CASE RUNC PROD 11 :30 - 13:00 1.50 CASE CIRC PROD 13:00 - 20:00 7.00 CASE RUNC PROD 20:00 - 00:00 12/26/2002 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 05:00 05:00 - 08:00 4.00 CEMENTCIRC PROD 1.00 CEMENTCIRC PROD 0.50 CEMENT RURD PROD 3.50 CEMENTCIRC PROD 3.00 CEMENT PUMP PROD Con't RIH wI 7" 26 #/ft L-80 BTC-Mod f/2794' to 4287'(Joint # 101). Running @ 40-50 ftImin. Not displacing enough fluid returns on last 5 joints run. Break circ slow. Circ @ 2.6 bpm wI 570 psi. Losses ranging f/128 bph to 32 bph. Lost total of 147 bbls @ 4287'. Con't RIH wI 7" casing. RIH 10 joints to 4747' @ 30-40 ftlmin. Displacement decreasing. Circ @ 2.6 bpm wI 550 psi fl 53 bbls wI good returns. Lost 6 bbls while circ. Con't RIH wI 7" casing. RIH 10 joints to 5176' @ 30-40 ftlmin. Circ @ 2.6 bpm wI 550 psi wI good returns. Lost 4 bbls while circ. RIH 10 joints to 5596' @ 30-40 ftImin. Circ @ 2.6 bpm wll 600 psi. Circ 105 bbls. Lost 40 bbls while circ. (75% returns. RIH 6 joints to 5848' @ 30-40 ftImin. Very poor displacement. Circ 66 bbls. Lost 15 bbls (75% returns) RIH 12 joints to 6352' @ 30-40 ftlmin. Circ @ 2.6 bpm wI 620 psi. Circ 125 bbls. Lost 39 bbls (75% returns) RIH last 12 joints, MU landing joint and hanger to 6879' land casing. Break circ slowly, bringing rate up f/1 bpm in 1/2 bbl intervals every 30 bbls to @ rate of 3.5 bpm @ first BU (180 bbls pumped). Initial PU wt 200k Initial SO wt 110 k 1 bpm=600 psi 1.5 bpm = 560 psi 2 bpm = 550 psi 2.5 bpm = 530 psi 3 bpm = 475 psi 3.5 bpm = 450 psi Continue to circ and condition hole prior to cement job on 7" 26 # L-80 BTC-Mod casing. Reducing MW f/12 ppg to 11.7 ppg Recip 10' wI PU 205 k & SO 125 k Circ one bottoms up after 11.7 ppg all the way around @ 4.5 bpm 390-420 psi. Gas 17-20 units RID Frank's fillup tool. RU Dowell cement head. Well flowing(Breathing) while changing out head. Flowed back 7.3 bbls in 30 minutes. Continue to circ wI Dowell cement head. Recip casing. First movement off hanger after changing out head req'd 240 k. Then normal PU wt of 190k-205k. SO 120K- 125K. 155 bbls into circulation, max gas units of 153. (Guage hole would indicate 6194') Decressed to 50 units by 180 bbls pumped and progressive back to 0-20 units. Circ @ 4 bpm 380-390 psi Dowell batch mix 10 bbls CW 100 @ 8.3 ppg, 30 bbls MudPush @ 12.5 ppg, 246 sx (51 bbls) @ 15.8 ppg Class "G" GasBlok WI .3%BWOC D65, .02%BWOC B155, 2.0 gal/sk D600G, .2 gal/sk D47 & 1/4 #/sx celloflakes PJSM on cemeting 7" casing. Dowell pump 5 bbls CW 100 @ 8.3 ppg, test lines to 3500 psi, pump 5 bbls CW100 @ 8.3 ppg, drop bttm plug, reload head wI another bttm and top pug. Dowell pump 30 bbls MudPush @ 12.5 ppg @ rate of 4 bpm wI 475 psi. Drop another bttm plug, pump 51 bbls Class "G" GasBlok @ 15.8 ppg wI additives at rate Printed: 1/10/2003 1:06:39 PM ) ) QonoëóPhillips Alaska ()peratiol1$ Summf.iry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-14 3S-14 ROT - DRILLING n1268 @conocophillips.com Nabors 7ES Date Sub Code Code· Phase 3.00 CEMENT PUMP PROD From -To Hours 12/26/2002 05:00 - 08:00 08:00 - 09:30 1.50 CEMENTOTHR PROD 09:30 - 10:30 1.00 WELCTL OTHR PROD 10:30 - 11 :30 1.00 CMPL TN RURD PROD 11 :30 - 12:00 0.50 CMPL TN SFTY PROD 12:00 - 19:30 7.50 CMPL TN RUNT PROD 19:30 - 21 :00 1.50 CMPLTN OTHR PROD 21 :00 - 22:00 1.00 CMPL TN PCKR PROD 22:00 - 23:00 1.00 CMPL TN SOHO PROD 23:00 - 00:00 1.00 CMPL TN OTHR PROD 12/27/2002 00:00 - 00:30 0.50 WELCTL OTHR CMPL TN 00:30 - 03:00 2.50 WELCTL NUND CMPL TN 03:00 - 05:30 2.50 WELCTL NUND CMPL TN 05:30 - 06:30 1.00 CMPL TN FRZP CMPL TN 06:30 - 09:00 2.50 CMPL TN OTHR CMPL TN Page 5 Of6 Start: 12/17/2002 Rig Release: 12/27/2002 Rig Number: Spud Date: 12/18/2002 End: Group: Description of Operätions of 4.5 bpm with 390 psi, shut down, flush lines to rig floor wI seawater. Drop top plug, Dowell displace first 181 bbls seawater @ 8.4 ppg at rate of 4.5 bpm with 990 psi until MudPush around shoe, then slowed rate to 3 bpm with 1050 psi until last 30 bbls of the displacement. For the last 30 bbls of displacement the rate was 2 bpm with 1650 psi. Bumped plug wI total of 265.1 bbls, bumped wI 2300 psi. Bled back 2 bbls for total of 263.1 bbls displaced (Calculated 263.3 bbls). CIP @ 0653 hrs 12/26/02. Had good circ throughout job. No noticable mud losses. Displaced entire job wI Dowell. Recip casing 10' stroke throughout entire job until last 10 bbls of displacement, then landed hanger. Flush out BOP stack wI water, mud pump # 2, kill & choke lines to get mud out of system. UD Landing joint. Install FMC packoff on 7" casing hanger. RILDS. Test to 5000 psi fl 15 min. PU tubing equip. RU to run 3 1/2" completion. PJSM on running 31/2" completion. Run 3 1/2" 9.3#/ft L-80 EUE 8rd-mod completion equip (197 joints wI jewlery) to 6245.67'. PU wt 80 K SO wt 65 K RU & Pressure test 7" casing to 3500 psi fl 30 min test. Chart test. Plot test. Drop Baker 2" packer setting ball. Will set SA B-3 packer @ 6213.78' Slowly pressure 3 1/2" tubing to 2500 psi. Wait 1 0 min. Slack off 20k, then continue to pressure tubing string to 3000 psi and hold fl 15 min. Bleed pressure to 1000 psi. PU to 1 05k to shear PBR. Slack off, tag locator wI 10k. Pressure to 3676 psi to shear ball seat. Bleed off all pressure. Pull joint 197 out of hole (pulling 12' seal assembly out of polished bore recepticle). MU 3 1/2" FMC tubing hanger on joint # 196. Use joint # 197 as landing joint. RIH and land tubing wI locator 2' above fully located in PBR. RILDS. Pressure 3 1/2" tubing to 3500 psi fl 15 min. Bleed pressure to 1500 psi. Pressure 7" x 31/2" annulus to 3500 psi fl 15 min (Pressure on tubing increased to 2100 psi). Bleed tbg pressure to zero. RP sheared wI tubing pressure @ 500 psi. Bleed both sides to zero. All tests were charted. UD3 1/2" landing joint. Install TWC. Nipple Down 13 5/8" BOP stack. Sim op: cleaning pits Nipple up WKM Gen V, 5K psi tree. Orient. Test tree to 5000 psi. Good test, charted. Pull TWC. Sim op: cleaning pits RU to periorm 9 5/8" x 7" FIT prior to freeze protection of annulus. Sim op: cleaning pits Using 11.7 ppg mud, periorm FIT on 9 5/8" x 7" annulus. 9 5/8" shoe @ 2808' MD(TVD = 2555') TOC est @ 5510' (TVD = 4941') Annulus required 6 bbls fluid to fill void. Initial test brought to 18.2 ppg EMW (860 psi) at pump rate of .5 bpm. Repeat test a few of times wI higher pump rate, bleeding pressure off. Noticed that pressure appeared to bleed at a faster rate. Repeat test. Printed: 1/10/2003 1 :06:39 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: GÓnocöPhillips AI.aska QperationsSum märy.Report Page 60f 6 38-14 38-14 ROT - DRILLING n1268@conocophillips.com Nabors 7E8 Start: 12/17/2002 Rig Release: 12/27/2002 Rig Number: 8pud Date: 12/18/2002 End: Group: Date Sub From-To Hours Code Code PhaSe·· Description Of.Operations 12/27/2002 06:30 - 09:00 09:00 - 10:30 10:30 - 11 :00 11 :00 - 16:00 16:00 - 17:00 2.50 CMPLTN OTHR CMPLTN Using 11.7 ppg fluid, annulusl taking fluid @ 490-500 psi. EMW = 15.4 ppg. Pump 4 bbl, bleed back .5 bbls. 1.50 CMPL TN FRZP CMPL TN Flush 9 5/8" x 7" annulus wi 300 bbls water @ 3bpm wi 682 psi. Sim Op of cutting 83' drilling line and service top drive while flushing annulus prior to freeze protection. 0.50 CMPL TN FRZP CMPL TN RU to freeze protect 3 1/2" x 7 " annulus. 5.00 CMPL TN FRZP CMPL TN Freeze protect 3 1/2" tubing & 3 1/2" X 7" annulus RP shear @ 6113' MD= 5464' TVD (tbg cap. 53.2 bbls) Pump 110 bbls diesel down tubing taking seawater returns from annulus to mud pits. SITP = 300 psi Diesel in Annulus(56.8 bbls= 2151' md= 2000' tvd) will migrate to surface. RU to freeze protect 9 5/8" x 7" annulus. 9 5/8" shoe @ 2808' md (tvd = 2555') TOC @ est 5510' md = 4941'md) Pump 60 bbls diesel down 9 5/8" x 7" annulus @ 1.5 bpm & 900 psi. SI press = O. Sim op of laying down 66 joints of 5" dp fl derrick while freeze protecting well. UD mousehole. ***** Noticed small amounts of gas hydrates around 16" conductor in cellar area while freeze protecting. 1.00 WELCTL OTHR CMPL TN Set BPV wi FMC lubricator. 300 psi on tubing. Secure well. Rig released fl 80' move to well 3S-10 Printed: 1/10/2003 1 :06:39 PM Date 01/30/03 01131/03 02/01/03 ) 35-14 Event History ) Comment PULL DCR @611311 RKB & SET DV PT TBG & CASING TO 3000# HOLD FOR 15 MIN. TEST GOOD DRIFT TBG WI 2B' X 22' DUMMY GUN TO 6686' RKB [PT TBG-CSG] WAIT ON RIG PROBLEMS - PERFORMED SCMT @ 1000 PSI AND 3000 PSI - APPEARS TO BE A GOOD CEMENT BOND - PERFORATED BOTTOM SHOT UNDERBALANCED WI 100 PSI SURFACE PRESSURE - RDFN [PERF] PERFORATED 6560-6570 FT MD WITH 2.511 HSD @ 6 SPF, 2506 POWERJET CHARGES. TAGGED TD AT _ 6684 FT MD. WELLHEAD PRESSURE = 750 PSI BEFORE AND AFTER SHOT 2ND RIH - CROSSFLOW DETERMINATION WITH PRESSUREITEMP/GRADIO/CONTINUOUS AND FULLBORE SPINNERS - NO CROSSFLOW WAS DETECTED. Page 1 of 1 2/11/2003 ) ) dDd-ô)d) 06-Jan-03 AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-14 Dear: Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0, MD (if Applicalble) 0.00' MD Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager attachments RECEIVED JAN 0 9 2003 Aiaab œ & Gas Cons. Comniae;on Anchtnge Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-14 - Job No. AKMW22198. Surveyed: 24 December. 2002 Survey Report 3 January, 2003 Your Ref: API 501032043900 Surface Coordinates: 5993896.63 N. 476188.43 E (70023'40.0388" N. 150011'37.4586" W) Grid Coordinate System: NAD27 Alaska State Planes. Zone 4 Surface Coordinates relative to Project H Reference: 993896.63 N. 23811.57 W (Grid) Surface Coordinates relative to Structure: 52.78 N, 266.74 W (True) Kelly Bushing: 55. 90ft above Mean Sea Level Elevation relative to Project V Reference: 55.9Oft Elevation relative to Structure: -O.20ft 5pe.-.......y-!5ul! DRILLING seRVIc:es A Halliburton Company D :F N - V: --' --- Survey Ref: svy10004 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-14 Your Ref: AP/501032043900 Job No. AKMW22198, Surveyed: 24 December, 2002 ConocoPhilfips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -55.90 0.00 0.00 N 0.00 E 5993896.63 N 476188.43 E 0.00 MWD Magnetic 28.20 0.000 0.000 -27.70 28.20 0.00 N 0.00 E 5993896.63 N 476188.43 E 0.000 0.00 196.48 1.040 343.780 140.57 196.47 1.47 N 0.43 W 5993898.10 N 476188.01 E 0.618 1.52 299.25 2.290 352.300 243.30 299.20 4.40 N 0.96W 5993901.03 N 476187.48 E 1.237 4.50 376.60 3.460 351.370 320.55 376.45 8.24N 1.52W 5993904.87 N 476186.94 E 1.514 8.37 466.99 6.110 355.990 410.61 466.51 15.73 N 2.27W 5993912.37 N 476186.21 E 2.960 15.89 -~ 558.17 7.510 355.520 501.15 557.05 26.51 N 3.07W 5993923.15 N 476185.44 E 1.537 26.64 648,08 11.470 355.370 589.81 645.71 41.29 N 4.25W 5993937.93 N 476184.31 E 4.404 41 .40 738.81 13.480 355.380 678.39 734.29 60.82 N 5.83W 5993957.47 N 476182.79 E 2.215 60.90 829.67 16.050 354.130 766.25 822.15 83.88 N 7.97W 5993980.53 N 476180.73 E 2.850 83.98 925.50 18.310 351.800 857.80 913.70 111.96 N 11.47 W 5994008.62 N 476177.32 E 2.465 112.24 1020.55 20.860 350.150 947.34 1003.24 143.41 N 16.50 W 5994040.10 N 476172.39 E 2.745 144.09 1113.93 23.960 349.090 1033.66 1089.56 178.42 N 22.93 W 5994075.12 N 476166.07 E 3.348 179.68 1211.80 26.230 351.100 1122.29 1178.19 219.31 N 30.04 W 5994116.03 N 476159.09 E 2.477 221.18 1306.44 27.740 349.190 1206.62 1262.52 261.61 N 37.41 W 5994158.36 N 476151.86 E 1.839 264.12 1400.43 27.910 350.120 1289.74 1345.64 304.77 N 45.28 W 5994201.54 N 476144.12 E 0.496 307.99 1495.93 30.450 351.170 1373.12 1429.02 350.71 N 52.83 W 5994247.50 N 476136.71 E 2.713 354.54 1590.89 30.820 352.380 1454.82 1510.72 398.59 N 59.75 W 5994295.41 N 476129.95 E 0.757 402.90 1685.86 30.180 351.720 1536.65 1592.55 446.33 N 66.42 W 5994343.17 N 476123.43 E 0.761 451.07 1781.71 29.380 353.120 1619.85 1675.75 493.52 N 72.70 W 5994390.38 N 476117.30 E 1.106 498.63 1876.83 30.480 352.290 1702.28 1758.18 540.59 N 78.74 W 5994437.4 7 N 476111.42 E 1.236 546.03 1970.91 29.450 352.830 1783.78 1839.68 587.18 N 84.82 W 5994484.08 N 476105.48 E 1.132 592.97 2067.28 29.860 353.170 1867.53 1923.43 634.51 N 90.63 W 5994531.42 N 476099.82 E 0.460 640.58 2162.69 31.660 347.360 1949.53 2005.43 682.54 N 98.94 W 5994579.48 N 476091.66 E 3.639 689.32 .--- 2257.41 32.980 344.610 2029.58 2085.48 731.66 N 111.22 W 5994628.64 N 476079.54 E 2.086 739.83 2355.10 33.620 345.880 2111.23 2167.13 783.52 N 124.88 W 5994680.54 N 476066.05 E 0.969 793.28 2447.66 31.690 345.450 2189.16 2245.06 831.91 N 137.24 W 5994728.97 N 476053.84 E 2.100 843.09 2541.14 30.130 350.470 2269.37 2325.27 878.82 N 147.29 W 5994775.92 N 476043.94 E 3.223 891.04 2635.94 30.360 349.910 2351.27 2407.17 925.87 N 155.43 W 5994822.99 N 476035.95 E 0.384 938.79 2732,05 30.320 349.980 2434.21 2490.11 973.68 N 163.91 W 5994870.82 N 476027.63 E 0.056 987.34 2852.94 30.690 351.740 2538.37 2594.27 1034.26 N 173.65 W 5994931.43 N 476018.08 E 0.800 1048.69 2947.60 30.300 351.090 2619.94 2675.84 1081.75N 180.82 W 5994978.96 N 476011.06 E 0.540 1096.71 3042.99 30.260 350.750 2702.32 2758.22 1129.25 N 188.41 W 5995026.47 N 476003.62 E 0.185 1144.80 3138.64 29.790 351.280 2785.13 2841.03 1176.52 N 195.88 W 5995073.77 N 475996.30 E 0.564 1192.65 3233.52 28.740 349.560 2867.90 2923.80 1222.26 N 203.59 W 5995119.53 N 475988.73 E 1.418 1239.02 3 January, 2003 - 14:40 Page 20f5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 38 Pad - 35-14 Your Ref: AP/501032043900 Job No. AKMW22198, Surveyed: 24 December, 2002 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3328.27 28.460 349.180 2951.09 3006.99 1266.83 N 211.96 W 5995164.13 N 475980.51 E 0.352 1284.38 3424.75 27.860 347.580 3036.15 3092.05 1311 .43 N 221.12 W 5995208.76 N 475971.49 E 1.000 1329.89 3520.50 27.450 346.590 3120.96 3176.86 1354.75 N 231.05 W 5995252.11 N 475961.70 E 0.643 1374.28 3616.20 29.600 352.530 3205.06 3260.96 1399.65 N 239.24 W 5995297.04 N 475953.65 E 3.717 1419.92 3711.33 29.860 351.350 3287.67 3343.57 1446.36 N 245.86 W 5995343.76 N 475947.18 E 0.673 1467.07 3806.00 29.640 352.250 3369.86 3425.76 1492.85 N 252.56 W 5995~90.28 N 475940.63 E 0.526 1514.02 ""--' 3902.06 29.260 351 .440 3453.51 3509.41 1539.61 N 259.26 W 5995437.05 N 475934.08 E 0.573 1561 .22 3996.40 28.900 351.540 3535.95 3591.85 1584.95 N 266.04 W 5995482.42 N 475927.44 E 0.385 1607.05 4091.94 28.4 70 350.960 3619.77 3675.67 1630.28 N 273.02 W 5995527.77 N 475920.61 E 0.536 1652.90 4187.21 28.350 351.160 3703.56 3759.46 1675.05 N 280.06 W 5995572.57 N 475913.71 E 0.161 1698.22 4283.03 27.980 351.010 3788.04 3843.94 1719.74 N 287.07 W 5995617.27 N 475906.84 E 0.393 1743.44 4378.32 27.730 350.430 3872.29 3928.19 1763.67 N 294.25 W 5995661.23 N 475899.80 E 0.387 1787.95 4473.38 27.390 350.430 3956.56 4012.46 1807.04 N 301.56 W 5995704.63 N 475892.63 E 0.358 1831.94 4569.01 26.930 349.630 4041.65 4097.55 1850.04 N 309.11 W 5995747.64 N 475885.21 E 0.614 1875.59 4665.01 26.950 350.960 4127.23 4183.13 1892.91 N 316.45 W 5995790.53 N 475878.02 E 0.628 1919.08 4760.51 27.050 351.000 4212.32 4268.22 1935.73 N 323.24 W 5995833.38 N 475871.35 E 0.106 1962.43 4855.43 27.130 350.270 4296.83 4352.73 1978.38 N 330.28 W 5995876.05 N 475864.46 E 0.360 2005.65 4951.08 26.900 349.880 4382.04 4437.94 2021.17 N 337.77 W 5995918.87 N 475857.10 E 0.304 2049.09 5046.29 26.810 347.600 4466.98 4522.88 2063.35 N 346.16 W 5995961.07 N 475848.84 E 1.086 2092.09 5141.87 26.760 348.640 4552.31 4608.21 2105.49 N 355.03 W 5996003.24 N 475840.11 E 0.493 2135.14 5237.79 26.550 348.350 4638.04 4693.94 2147.66 N 363.61 W 5996045.44 N 475831.66 E 0.258 2178.15 5332.74 28.760 349.710 4722.13 4778.03 2190.92 N 371.98 W 5996088.73 N 475823.43 E 2.420 2222.21 5428.06 28.610 348.940 4805.76 4861.66 2235.89 N 380.45 W 5996133.72 N 475815.10 E 0.418 2267.96 5522.41 27.950 349.860 4888.84 4944.74 2279.82 N 388.68 W 5996177.68 N 475807.02 E 0.838 2312.66 ---. 5617.78 29.600 349.250 4972.44 5028.34 2324.97 N 397.01 W 5996222.85 N 475798.83 E 1.757 2358.57 5711.74 29.140 347.910 5054.32 5110.22 2370.13 N 406.13 W 5996268.05 N 475789.86 E 0.854 2404.63 5809.01 28.400 347.610 5139.58 5195.48 2415.89 N 416.05 W 5996313.83 N 475780.08 E 0.775 2451.42 5902.53 28.150 346.800 5221.94 5277.84 2459.09 N 425.86 W 5996357.06 N 475770.41 E 0.490 2495.66 5992.49 27.770 347.120 5301.40 5357.30 2500.18 N 435.38 W 5996398.18 N 475761.02 E 0.454 2537.79 6094.11 27.030 345.700 5391.62 5447.52 2545.63 N 446.36 W 5996443.67 N 475750.18 E 0.971 2584.46 6188.84 26.380 347.340 5476.25 5532.15 2587.02 N 456.29 W 5996485.09 N 475740.39 E 1.037 2626.95 6284.42 25.420 346.230 5562.23 5618.13 2627.67 N 465.82 W 5996525.77 N 475730.98 E 1.125 2668.64 6380.01 24.800 345.970 5648.78 5704.68 2667.04 N 475.57 W 5996565.17 N 475721.36 E 0.659 2709.11 6476.24 24.580 346.320 5736.22 5792.12 2706.07 N 485.19 W 5996604.23 N 475711.86 E 0.274 2749.22 6571.13 24,180 345.360 5822.65 5878.55 2744.05 N 494.77 W 5996642.24 N 475702.40 E 0.593 2788.29 3 January, 2003 - 14:40 Page 3 0£5 DrillQuest 3.03.02.004 Western North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 6663.80 24.150 347.390 5907.20 5963.10 6758.85 23.540 347.350 5994.13 6050.03 6825.84 22.820 347.060 6055.71 6111.61 6895.00 22.820 347.060 6119.46 6175.36 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-14 Your Ref: API 501032043900 Job No. AKMW22198, Surveyed: 24 December, 2002 Local Coordinates Northings Eastings (ft) (ft) 2780.91 N 2818.41 N 2844.12 N 2870.26 N 503.71 W 512.11 W 517.95 W 523.95 W Global Coordinates Northings Eastings (ft) (ft) 5996679.13 N 5996716.65 N 5996742.39 N 5996768.55 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 55.9" MSL. Northings and Eastings are relative to 2519' FNL, 1071' 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 2519" FNL, 1071" FEL and calculated along an Azimuth of 349.930° (True). Magnetic Declination at Surface is 25.245°(17-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 6895.00tt., The Bottom Hole Displacement is 2917.69ft., in the Direction of 349.655° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6895.00 6175.36 2870.26 N 3 January, 2003 - 14:40 Comment 523.95 W Projected Survey Page 4 0'5 475693.58 E 475685.30 E 475679.54 E 475673.62 E ConocoPhi/lips Dogleg Vertical Rate Section (0/100ft) 0.897 0.642 1.088 0.000 Comment 2826.14 2864.53 2890.87 2917.66 Projected Survey --- .-----' DrillQuest 3.03.02.004 Western North Slope Sperry-Sun Drilling Services Survey Report for Kuparuk 38 Pad - 35-14 Your Ref: AP/501032043900 Job No. AKMW22198, Surveyed: 24 December, 2002 ConocoPhillips Survey tool program for 35-14 From Measured Vertical Depth Depth (ft) (ft) 0,00 3 January, 2003 - 14:40 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 6895,00 6175.36 MWD Magnetic ~ "'-~ Page 5 0'5 Dril/Quest 3.03.02.004 ) ) ~~!Æ7E o 'F !Æl~~~«~ TONY KNOWLESJ GOVERNOR I ~ AI~ASIiA. OIL AND GAS CONSERVATION COMMISSION / 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit ConocoPhillips Alaska Permit No: 202-221 Surface Location: 2519' FNL, 1071' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 398' FSL, 1578' FEL, Sec. 7, TI2N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ~o;' day of December, 2002 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. )" COn().c~Phil·l.ips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com November 7, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, injector 38-14 Dear Commissioner Taylor: /_ _, ,,i/"" 1/ ConocoPhill.ips Alaska, Inc. hereby applies for a Permit to Drill an onshorEf's'~'~jz6'well, KRU 38-14, a development well. / '---d/ Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact 8cott Lowry at 265-6869. Sincerely, ~~~ Randy Thomas GKA Drilling Team Leader RECEIVED NOV 1 5 2002 Alaska Oil & Gas Gons. Commission Anchorage n U) ~. r... ~ ~ì'. ,,~1.. }\\ L· r- ~ il =, ~\I P ,,,' ~ \ ~ \.=.? ~' ,~ 6. Property Designation ADL 380106 ALK 4623 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well num~ Number 3S-14 59-52-180 9. Approximate spud date /" Amount December 15, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 6818 ' MD / 6061 'TVD 17. Anticipated pressure (see 20 }AC 25.035 (e)(2)) Maximum surface 2986 psig / At total depth (TVD) 3630 psig Setting Depth ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill 0 Redrill D Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2519' FNL, 1071' FEL, Sec.18, T12N, R8E, UM At top of productive interval 283' FSL, 1558' FEL, Sec. 7, T12N, R8E, UM At total depth 398' FSL, 1578' FEL, Sec. 7, T12N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 283' @ Targe' feet 3S-26 236' @ 600' / 16. To be completed for deviated wells Kickoff depth: 200 MD 18. Casing program size D o 1b. Type of well. Exploratory D Stratigraphic Test ./Service 0 Development Gas D Single Zone 5. Datum elevation (DF or KB) RKB 28 feet feet Maximum hole angle 30° W6A- Il-l ¿Io 1- Development Oil D Multiple Zone D 10. Field and Pool /' Kuparuk River Field Hole Casing Weight 42" 30 x 16" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTCM Length 80' 2788' 6790' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' 9 cy High Early 28' 28' 2816' 2581' 530 sx AS Lite & 220 sx LiteCrete 28' 28' 6818' 6061' 220 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface Production Length Size Cemented Measured depth True Vertical depth 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869 ~~~ . Signed . '\ ,~...... Title: Kuparuk DrHling Team Leader Randy Thomas Commission Use Only Permit Nu mber I API number I Approval date , 2/ r) .2.0<"'- 2.. '2../ 50- /0 ~ - .2.ð SJ~- 0 0 «/y~ 'IÎ,,:;2 Conditions of approval Samples required D Yes ~ No Mud log required Hydrogen sulfide measures DYes t2S1 No Directional survey required ~ Yes Required working pressure for BOPE D2M; . D 3M; D 5M; D 10M; D 0 Other:'le~f EQPE fo/5o.t9j.¡" ¡?~tL·~~/l]:'L c:~t17~\.Ü.tA 1'J'j y'(ÕL~NJ, J\--f'l' tv ,,~l ~ 106 t,~ N a ~..., r ~ f~ u.e....1ÿ(. e q ~ ~.J ¡? YO f;h H'\. , by order of Approved by Commissioner the commission OKI(,;jINAL StGNt:u BY M L. Bill Liner Perforation depth: measured true vertical Form 10-401 Rev. 12/1/85· RECEIVED NOV 1 5 2002 AlasRa Oil·& Gas Qons. Commission Anchorage t ((f'f (o '"L Date PrAn;:¡rArl hv Sh;:¡rnn AI/!:wn-nr;:¡kA Isee cover letter for other requirements U Yes ~ No D No Oat. / ap); ,;2- Submit in triplicate ') '\,pplication for Permit to Drill, Well 3S-14 1 Revision No.O J Saved: 7-Nov-02 Permit It - Kuparuk Well 35-14 Application for Permit to Drill Document MoximizE Well VQlur: Table of Contents 1. Well Name.. ..... ....... ............... ... ...... ....... ............ ....... ......... ........ ..... ............. ... ........ ... 2 Requirements of 20 AAC 25.005 (f).. ....... ............ ......... ................. ......... ..... ......... ................... ............... 2 2. Location Summary. ... ..... ........... ... ....... ........ ......... .... ....... ...... ...... ........ .............. ....... 2 Requirements of 20 AAC 25.005(c)(2) ...... ....................... .................... ..... .......... ........... ................. ....... 2 Requirements of 20 AAC 25. 050(b)........... ...................... .................... .... .............. ......... ........................2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) .................................................................................... ............... 3 4. Dri II i ng Hazards Information.. ... ....... ... ...... ........ ....... ........... ....... ............ ......... ..... ... 3 Requirements of 20 AAC 25.005 (c)( 4) ..... ............... ....... ............. ......................... ............ .......... ........... 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) ....... ....................... ................... ...... ............... ...... ...................... 3 6. 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 uid Program ......... .................. ... ....... ...................... ...... ..... .... ..... ... ........ ... 4 Requirements of 20 AAC 25.005(c)(B) .............. ....... .............. ........ ........ ............... ........ ..... ........ ............ 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................... .............................................................................. 5 10. Seism ic Analysis.... ... ............ ...... .......... ...... ........................... ...... ........... ... ... ........... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................ ................ .................... ............ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ............................................................... ......... ........................ 6 12. Evidence of Bondi ng ... ......... ..... ...... ............ ........ ........... ...... ...... ... ..... ....... ..... ..... .... 6 Requirements of 20 AAC 25.005 (c)(12) ............................................................................... ................. 6 13. Proposed Dri II i ng Program ........... ...... ... ..... ... ....................... ......... ................ ......... 6 3$-14 PERMIT IT. DOC Page 1 of 7 Printed: 7-Nov-02 ) ~.'fPlication for Permit to Drill, Well 3S-14 I Revision No.O Saved: 7-Nov-02 Requirements of 20 AAC 25.005 (c)(13) ........................... ...................... ......... .......................... ...... ...... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ..... ....... ...... ....... ... .... ...... ....... ... .... .......... ....... ................ ......... ... ...... ...... 7 Attachment 1 Directional Plan.. .................. .................... .................................. ....... ..... ...... ...... ............. 7 Attachment 2 Drilling Hazards............................................................................................. 6 Attachment 3 Well Schematic............................ .................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identífied by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branche~ eaä7 branch must similar1y be Identified by a unique name and API number by adding a suffix to the name designated for the well by tIle operator and to the number assigned to the well by the commission. / The well for which this application is submitted will be designated as 35-14. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applic:'i~tion tÓr a Permit to Drill ml/!it be accompanied by eaäJ of'the following items, eXCé:.'l-?t for a/7 item already 0/7 flÏe wIth the commis~ì'on and Identified 1i7 tl7e application: (2) a plat identifyli1g the plVperty and the property's owners and showing (A)the coordinates of'the plVposed location of the well at the sLl/face/ at the top of each objective formation and at total depth referenced to governmental section lines. (8) the coordinates of tf1e proposed location of the well at the surface/ referenced to the state plane coorrjinate ,';;ystem fvr thit; state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) tIle propo!:.t-ed depth of the well at the top of ,ýJ objective formation and at total depth,: Location at Surface 12519' FNL, 1071' FEL, Sec 18, T12N, R8E, UM NGS Coordinates RKB Elevation Northings: 5,993,897 Eastings: 476,189 Pad Elevation / 283' FSL, 1558' FEL, Sec 7, T12N, R8E, UM 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "c" Sand) NGS Coordinates Northings: 5,996,700 Eastings: 475,700 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6581' 5855' 5799' ,/ Location at Total Depth I 398' FSL, 1578' FEL, NGS Coordinates Northings: 5,996,815 Eastings: 475,680 Sec7,T12N,R8E,UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6818' 6061 ' 6005' and (D) other information required by 20 MC 25.050(bJ/ Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviatec!r the application for a PermIt to DrtJl (Form 10-401) must (1) include a plat drawn to a sUItable scale, showing the path of the proposed wellbore/ including all adjacent wellbores within 200 feet of any portion of the proposed welf,· Please see Attachment 1: Directional Plan 3$-14 PERMIT IT.DOC Page 2 of 7 Printed: 7-Nov-02 ') ~plication for Permit to Drill, Well 38-14 } Revision No.O " Saved: 7-Nov-02 and (2) for all wells witl7in 200 feet of the proposed wellbore (A) list the names of the operators of those well,,~ to the extent that tho~--e names are known or discoverable in public record.~ and show that each named operator has been furni!J11ed a copy of the application by certified mall,' or (8) state that tile applicant is the onlyaffeGted owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application lor a Pel7nit to Drill must be accompanied by each of the following ItemSr except for an item already on file with the commission and identified in the application: (3) a diagram and description ol the blowout prevention equipment (80PE) as required by 20 AAC 25.035, 20 MC 25.03~ or 20 AAC 25.037, as applicable;: Please reference BOP schematics on file for Nabors 7ES. ,,/ 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fvr a PermIt to Drill mllst be accompanied by each of the following item5~ except fbr an item already on file with the (X)mmis..';1on and identified in the application: (4) information on drilling hazards, including (A) the mðximum downhole pressure that may be encountered, cl1teda used to detel17Jine it, and maxlinum potentÙ71 surface pressure based 00 a methane gradient; A pressure build-up test performed on Palm lA (3S-2~_~~~ indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft ~ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 3S-14 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5855' tvd: MPSP =(5855 ft)*(0.62 - 0.11 psi/ft) = 2986 psi '/ (B) 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 zoneSr 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 Dr/II must be accompanied by each of the following item~ except for ao item already on file wIth the commission (717d Identified il7 the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(f); A procedure is on file with the commission for performing LOT's. For 35-14 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) 3$-14 PERMIT IT. DOC Page 3 of 7 Printed: 7-Nov-02 ) ~plication for Permit to Drill, Well 3S-14 J Revision No.O Saved: 7-Nov-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following Item5~ except for an item already on file wit/7 the commission and identified in the application: (6) c7 complete proposed casing and cementing program as required by 20 MC 25. 030;. and a desl.-Yiption of'any slotted liner, pre- perforated liner, or screen to be installed; Casinq and Cementinq Proqram Hole / / Top Btm Csgffbg Size Weight Length MOffVO MOffVO OD (in) (in) (Ib/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 2788' 28'/28' 2816'/2581' Lead: 530 sx 10.7 ppg AS Lite Tail: 220 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 6790' 28'/28' 6818'/6061' 220 sx 15.8 ppg 'G' w/ add. Planned TOC= ·5781' ,/ MD 3-1/2 9.3 L-80 EUE 8rd 6453' 28' / 28' 6481'/5768' SAB- 3 packer set at Mod 6481' 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. If 7" casing must be top-set above the Kuparuk C sand, a 3 112" production liner will be used and an exception to 20 AAC 25.412 (b) is requesteo/ The distance between seals at the top of the 3 V2" liner and the top perforation will exceed 200' MD. In the top-set case, the distance between ~ the seals and the top perforation will be 1V400' MD. An adequate leak-off test of the 7" casing shoe, combined with a cement bond log of the liner section below the 7" casing shoe will provide proof of zonal isolation between the seals and the perforated interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by ead7 of the following Items, except for an item already on file with the commission and identified in the application: (1) a diagram and description of the diverter system as required by 20 AAC 25. 030 unless this requirement is we-Jived by the commission under 20 AAC 25:035(/7)(2); Please reference diverter schematic on file for Nabors 7ES. / 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (8) a drilling flUid program, including a diagram and description of the drilling flUid system, as required by 20 MC 25.033; Drilling will be done using mud systems having the following properties: 35-14 PERMIT IT. DOC Page 4 of 7 Printed: 7-Nov-02 ) ~plication for Permit to Drill, Well 3S-14 ) Revision No.O Saved: 8-Nov-02 Surface Hole mud properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value / Density (ppg) 9.4 9.4* 9.4* 9.4* Funnel Viscosity 120-130 120-100 100-120 100-75 (seconds) Yield Point 35-45 27 -40 25-35 20-30 (cP) Plastic Viscostiy 8-15 11-22 15-30 15-30 (lb/100 sf) 10 second Gel 10-30 1 0-25 10-25 1 0-25 Strength (lb/100 sf) 10 minute Gel 25-55 25-55 20-40 15-35 Strength (lb/100 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 Kuparuk Density (ppg) 9.5 10.2 10.6 10.8 12.3 /(1 Funnel Viscosity 42-58 42-58 - 40-55 42-55 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (Ib/100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (lb/100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb/100 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 0-1 5 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 On!1 must be accompanied by each of the following itemS¡. except for an item already on file with the commission and Identified in the application: (9) for an exploratory or stratigrapl7ic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f)/ N/ A - Application is not for an exploratory or stratigraphic test well. 38-14 PERMIT IT. DOC Page 5 of 7 Printed: 8-Nov-02 ') <\\:',PPlication for Permit to Drill, We1l3S-14 , Revision No.O - Saved: 7-Nov-02 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a PermIt to Drill must be accompanied by each of the following item~ exæpt for an Item already on file with the commission and identifìed in the application: (10) for an exploratory or stratigraphic test we/~ a sei~mic retraction or reflection analysis as required by 20 MC 25.061(a),-- N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/icC"1tion for a Permit to Drill mu.~t be accompanied by each of tt7e following Item~ exæpt for an item already on file with the commission and Identified in the application: (11) for a well (fljlled ti"om an offi.:,1Jore platf'Orm, mobile bottom-founded structure, jac.:k-up lig, or floating (frilling vessel, an 8naly~i$ of seabed cvndJtions as required by 20 MC 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 Permit 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: (12) evidence !:J1Jowing that the requirements of 20 MC 25.025 {Bonding}/78ve 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 Onll must be acx:ompanied by each of the (vllowing item!'~ except ('Or an item already on file wHtJ the commis~ion lmd Identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. / 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/S" surface casing point according to directional plan. No LWD logging equipment required. /' 4. Run and cement 9-5/S" 40#, L-SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circ~e to surface, perform top job. Install and test BOPE to ,,/ 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill 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 sand, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). / 7. Run cement bond log to verify zonal isolation prior to running completion. S. Run 3-1/2" 9.3#, {-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 V2" x 7" annulus to 3500 psi......... Burst shear valve for freeze protect. 9. Set TWC and ND BOPE. Install and pressure test production tree. 10. Freeze protect. Secure well. Rig down and move out. 11. Handover well to Operations Personnel. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L-SO BTCM ,/ casing will be run and cemented above the Kuparuk C sand. 6 l/S" hole will be drilled to total depth 38-14 PERMIT IT. DOC Page 6 of 7 Printed: 7-Nov-02 ') 'f>plication for Permit to Drill, Well 3S-14 , Revision No.O . Saved: 7-Nov-02 according to the directional plan and a 3 112" 9.3# L -80 5LHT liner will be ran and cemented across the productive interval. In this case, the cement bond log will be done after moving the rig off the well. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application fvr a Permit to Drill mu."tc be accompanied by each of the fvl/owing items, except for an item a/ready on file with the c:vmmis..c,ion 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 AAC 25. 080 for an annular disposal operation in the we/I.; 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 35-14 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. 3$-14 PERMIT IT. DOC Page 7 of 7 Printed: 7-Nov-02 Sperry-Sun Drilling Services Western North 51qQe ConocoPhillips Ku~~'¡t;Jc 3S Pad 35-14 '35-14 (wp02) ---- Proposal Report 24 October, 2002 Surface Coordinates: 5993896.50 N, 476188.52 E (70023' 40.0375" N, 150011'37.4559" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 56. 10ft above Mean Sea Level """-.,..p'!;/ :a~~:::,:::;lt=~:J: 'o'bH~ Cädpwi,' Proposal Ref: pro9980 DrillQuest 3.03.02.002 Page 2 of6 24 October, 2002 - 17:05 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-14 Plan - 35-14 (wp02) ConocoPhillips Western North 510pe Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Cømment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.1 0 0.00 0.00 N 0.00 E 5993896.50 N 476188.52 E- 0.00 SHL (2519' FNL & 1071' FEL, SEC 18- T12N - R8E) 200.00 0.000 0.000 143.90 200.00 0.00 N 0.00 E 5993896.50 476188.52. E 0.00 Begin Dir @ 2.00/100ft: 200.00ft MD, 200.00ft TVD 300.00 2.000 349.933 243.88 299.98 1.72 N 0.31 W 59938~..8.22 N \jf¡I¡I!~\;4761'~8'!22 E 2.000 1.75 400.00 4.000 349.933 343.74 399.84 6.87 N 1.22W 5~~¡i~'i~7 N '{;)%;1~~6187 .32 E 2.000 6.98 500.00 6.000 349.933 443.35 499.45 15.45 N 2.74W 5993911;i96 N ·4¡Z:ij~,85.83 E 2.000 15.69 ~ 600.00 8.000 349.933 542.60 598.70 5993923.97 N 476183.73 E 2.000 27.88 700.00 10.000 349.933 641 .37 697.47 5993939.38 N 476181.05 E 2.000 43.52 Increase in Dir Rate @ 3.00/100ft : 700.00ft MD, 697.47ft TVD 800.00 13.000 349.933 739.35 795.45 1 .09t'tV 5993959.02 N 476177.63 E ,/' 3.000 63.46 900.00 16.000 349.933 836.15 892.25 15.4 7W 5993983.68 N 476173.33 E 3.000 88.49 1000.00 19.000 349.933 931.51 987.61 20.72 W 5994013.30 N 476168.17 E 3.000 11 8.56 1100.00 22.000 349.933 1025.17 1081.27 26.85 W 5994047.80 N 476162.16 E 3.000 153.58 1200.00 25.000 349.933 1116.86 1172.96 N 33.81 W 5994087.07 N 476155.31 E 3.000 193.45 1300.00 28.000 349.933 1206.35 1262.45 234.40 N 41.61 W 5994131.03 N 476147.65 E 3.000 238.06 1353.19 29.596 349.933 1252.96. 1309.06 259.62 N 46.09 W 5994156.27 N 476143.25 E 3.000 263.68 End Dir, Start Sail @ 29.6° : 1353.19ft MD, 1309.06ft TVD 1400.00 29.596 349.933 1349:76 282.39 N 50.13 W 5994179.04 N 476139.29 E 0.000 286.80 1500.00 29.596 349..93$ 1436.71 331.01 N 58.77 W 5994227.70 N 476130.81 E 0.000 336.19 1600.00 29.596 349;933" 1523.67 379.64 N 67.40 W 5994276.35 N 476122.33 E 0.000 385.58 1625.80 29.5.96 ' 349;933 . 1546.10 392.19 N 69.63 W 5994288.91 N 476120.14 E 0.000 398.32 B. Permafrost 1700.00 29:596 . :349:Q3ß 1554.52 1610.62 428.27 N 76.03 W 5994325.01 N 476113.85 E 0.000 434.96 1800.00 29.596 ..349.933 1641.47 1697.57 476.89 N 84.67 W 5994373.66 N 476105.37 E 0.000 484.35 1900.00 . 29.5ß6 > 349.933 1728.43 1784.53 525.52 N 93.30 W 5994422.32 N 476096.89 E 0.000 533.74 - 2000.00 29.596 '··349.933 1815.38 1871.48 574.15 N 101.93 W 5994470.97 N 476088.42 E 0.000 583.13 2100.00 29.596 349.933 1902.33 1958.43 622.78 N 110.57 W 5994519.63 N 476079.94 E 0.000 632.52 2160.57 29.596 349.933 1955.00 2011.10 652.23 N 115.80 W 5994549.10 N 476074.80 E 0.000 662.43 T. West SaI< 2200.00 29.596 349.933 1989.28 2045.38 671.40 N 119.20W 5994568.28 N 476071.46 E 0.000 681.90 2300.00 29.596 349.933 2076.24 2132.34 720.03 N 127.83 W 5994616.93 N 476062.98 E 0.000 731.29 2400.00 29.596 349.933 2163.19 2219.29 768.66 N 136.47 W 5994665.59 N 476054.50 E 0.000 780.68 2500.00 29.596 349.933 2250.14 2306.24 817.29 N 145.10 W 5994714.24 N 476046.03 E o.oob 830.07 2600.00 29.596 349.933 2337.10 2393.20 865.91 N 153.73 W 5994762.90 N 476037.55 E 0.000 879.45 2672.34 29.596 349.933 2400.00 2456.10 901.09 N 159.98 W 5994798.10 N 476031.41 E 0.000 915.18 B. West Sak Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-14 Plan - 35-14 (wp02) ConocoPhillips Western North 510pe 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) eJ100ft) 2700.00 29.596 349.933 2424.05 2480.15 914.54 N 162.36 W 5994811 .55 N 476029.07 E 928.84 2800.00 29.596 349.933 2511.00 2567.10 963.17 N 171.00 W 5994860.21 476020.59 E 978.23 2816.00 29.596 349.933 2524.92 2581.02 970.95 N 172.38 W 5994867.99 47601923 E 986.13 9-5/8" Csg Pt ". Drill out 8-1/2" Hole 2816.00ft MD, 2581.02ft TVD 9 5/8" Casing 2900.00 29.596 349.933 2597.96 2654.06 1011.79 N 179.63 W 5~?i.~;~6 N "¡;¡;'!¡ïI6012.11 E 0.000 1 027.62 2916.15 29.596 349.933 2612.00 2668.10 1019.65 N 181.03 W 5gg491~í~,~N "4:itQ1O.74 E 0.000 1035.59 C-80 (K-10) -- 3000.00 29.596 349.933 2684.91 2741.01 1060.42 N 18826W 5994957.52 N 476003.63 E 0.000 1077.00 3100.00 29.596 349.933 2771 .86 2827.96 1109.05 N 196.90 W 5995006.17 N 475995.16 E 0.000 1126.39 3200.00 29.596 349.933 2858.82 2914.92 1157.68 N 205.53 W 5995054.83 N 475986.68 E 0.000 1175.78 3300.00 29.596 349.933 2945.77 3001 .87 1 gg!3.30 N 214.16W 5995103.48 N 475978.20 E 0.000 1225.17 3400.00 29.596 349.933 3032.72 3088.82 12~193 N 222.80 \N 5995152.13 N 475969.72 E 0.000 1274.55 ·-:">"<:>::BlliHi'::- 3500.00 29.596 349.933 3119.68 3175.78 !II~õJ~iN 231.43 W 5995200.79 N 475961.24 E 0.000 1323.94 3600.00 29.596 349.933 3206.63 3262.73 . :;~liJ¡t?¡~ 240.06 W 5995249.44 N 475952.76 E 0.000 1373.33 3700.00 29.596 349.933 3293.58 3349.68 248.70 W 5995298.10 N 475944.29 E 0.000 1422.72 3800.00 29.596 349.933 3380.54 3436.64 1i1449.44 N 257.33 W 5995346.75 N 475935.81 E 0.000 1472.11 3900.00 29.596 349.933 3467.49 3523.59 1498.07 N 265.96 W 5995395.41 N 475927.33 E 0.000 1521.49 4000.00 29.596 349.933 3554.44 3610.54 1546.69 N 274.60 W 5995444.06 N 475918.85 E 0.000 1570.88 4100.00 29.596 349.933 3641.40 3697.50 1595.32 N 283.23 W 5995492.72 N 475910.37 E 0.000 1620.27 4200.00 29.596 349,.~3ß '~728.35' 3784.45 1643.95 N 291 .86 W 5995541 .37 N 475901.90 E 0.000 1669.66 4300.00 29.596 349;933\ .. , 3615.30 3871 .40 1692.58 N 300.50 W 5995590.02 N 475893.42 E 0.000 1719.04 4400.00 29.596 349(~33. :, 3902.26 3958.36 1741.20 N 309.13 W 5995638.68 N 475884.94 E 0.000 1768.43 , -..,..~, 4500.00 29.596 3.49.933 3989.21 4045.31 1789.83 N 317.76 W 5995687.33 N 475876.46 E 0.000 1817.82 4569.91 ¿9.596 ;349.933 4050.00 4106.10 1823.83 N 323.80 W 5995721.35 N 475870.53 E 0.000 1852.35 C-40 (K-3) 4600.00 29.Sa6 349.933 4076.16 4132.26 1838.46 N 326.40 W 5995735.99 N 475867.98 E 0.000 1867.21 -' 4700.00 29.596 . . '349.933 4163.11 4219.21 1887.09 N 335.03 W 5995784.64 N 475859.50 E 0.000 1916.59 4800.00 29.596 349.933 4250.07 4306.17 1935.71 N 343.66 W 5995833.30 N 475851.03 E 0.000 1965.98 4900.00 29.596 349.933 4337.02 4393.12 1984.34 N 352.29 W 5995881.95 N 475842.55 E 0.000 2015.37 5000.00 29.596 349.933 4423.97 4480.07 2032.97 N 360.93 W 5995930.61 N 475834.07 E 0.000 2064.76 5100.00 29.596 349.933 4510.93 4567.03 2081.59 N 369.56 W 5995979.26 N 475825.59 E 0.000 2114.15 5200.00 29.596 349.933 4597.88 4653.98 2130.22 N 378.19 W 5996027.92 N 475817.11 E 0.000 2163.53 5300.00 29.596 349.933 4684.83 4740.93 2178.85 N 386.83 W 5996076.57 N 475808.64 E 0.000 2212.92 5400.00 29.596 349.933 4771 .79 4827.89 2227.48 N 395.46 W 5996125.22 N 475800.16 E 0.000 2262.31 5500.00 29.596 349.933 4858.74 4914.84 2276.10 N 404.09 W 5996173.88 N 475791 .68 E 0.000 2311.70 5600.00 29.596 349.933 4945.69 5001.79 2324.73 N 412.73 W 5996222.53 N 475783.20 E 0.000 2361 .08 5700.00 29.596 349.933 5032.65 5088.75 2373.36 N 421.36 W 5996271 .19 N 475774.72 E 0.000 2410.47 5800.00 29.596 349.933 5119.60 5175.70 2421.99 N 429.99 W 5996319.84 N 475766.24 E 0.000 2459.86 24 October, 2002 - 17:05 Page 3 of6 DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 Page 4 of6 24 October, 2002 - 17:05 Based upon Minimum Curvature type calculations, at a Measured Depth of 6818.00ft., The Bottom Hole Displacement is 2962.63ft., in the Direction of 349.933° (True). Magnetic Declination at Surface is 25.4500(17-Sep-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2519' FNL, 1071' FEL and calculated along an Azimuth of 349.930° (True). All data is in.Feet (US) uniess 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 2519' FNL, 1071' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-14 Plan - 35-14 (wp02) ConocoPhillips Western North 510pe 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) (°/1000\ ":2:~%;~::;;~:-... 5823.46 29.596 349.933 5140.00 5196.10 2433.39 N 432.02 W 5996331 .26 N 475764.25 E O.OOO""F 2471.45 Top Morraine 5900.00 29.596 349.933 5206.55 5262.65 2470.61 N 438.63 W 5996368.50 N iH 1?51IiáE,.,t: ;\í¡f~~,g:ggg 2509.25 6000.00 29.596 349.933 5293.51 5349.61 2519.24 N 447.26 W 5996417 .15 Nijl;'¡§?Ií1'~1m 2558.63 6100.00 29.596 349.933 5380.46 5436.56 2567.87 N 455.89 W 5996465.81 N"rlt! 47'&¡iil¡81UíÊ' Yi¡iib.ooo 2608.02 6174.22 29.596 349.933 5445.00 5501.10 2603.96 N 462.30 W 5996501.92 N \i¡f:frf1::57.:52 E 0.000 2644.68 Top HRZ 6200.00 29.596 349.933 5467.41 5523.51 2616.49 N 464.53 W 5996514.46 N 4'4t!þ32.33 E 0.000 2657.41 -~ 6300.00 29.596 349.933 5554.37 5610.47 2665.12 N 473.16 W 5996563.12 N 475723.85 E 0.000 2706.80 6373.18 29.596 349.933 5618.00 5674.10 2700.71 N 479.48 W 5996598.72 N 475717.65 E 0.000 2742.94 Base H RZ 6400.00 29.596 349.933 5641 .32 5697.42 2713.75 N 481.79 W 5996611.77 N 475715.37 E 0.000 2756.19 6499.69 29.596 349.933 5728.00 5784.10 2762.22 N 490·40{f 5996660.27 N 475706.92 E 0.000 2805.42 K-1 6500.00 29.596 349.933 5728.27 5784.37 27@1~~8 N 5996660.42 N 475706.90 E 0.000 2805.57 6581 .34 29.596 349.933 5799.00 5855.10 ,~~¡f~3 N 5996700.00 N 475700.00 E 0.000 2845.74 TARGET: 6581.34ft MD, 5855.1 Oft TVD (283' FSL & 1558' FEL, See T T12N-R8E) Kuparuk Target - 3S-14 (Geo), 150.00 Radiu Cu rrent Target 6600.00 29.596 349.933 5815.23 5871 .33 2811.00 N 499.06 W 5996709.08 N 475698.42 E 0.000 2854.96 6618.14 29.596 349.933 5831.00 5887.10 2819.83 N 500.62 W 5996717.91 N 475696.88 E 0.000 2863.92 Miluveach 6700.00 29.596 349.933 5902.18 5958.28 2859.63 N 507.69 W 5996757.73 N 475689.94 E 0.000 2904.35 6800.00 29.596 349iß33 , !)aß9.13 6045.23 2908.26 N 516.32 W 5996806.39 N 475681.46 E 0.000 2953.74 6818.00 29.5~6 349~ª33 ; 6004.78 6060.88 2917.01 N 517.88 W 5996815.15 N 475679.94 E 0.000 2962.63 Total Depth: 6818.00ft MD, 6047.89ft TVD (398' FSL & 1578' FEL, SEC. 7-T12N-R8E) - 7" Casing ~ DríllQuest 3.03.02.002 Page 5 of 6 24 October, 2002 - 17:05 Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Dip Up-Dip Formation Name (ft) (ft) (ft) (ft) (ft) Angle Dim. 1625.80 1546.1 0 . ,J4~9,.º0<' >"392.19 N 69.63 W 0.000 359.817 B. Permafrost 2160.57 2011 .1 0;'~955.00 : 652.23 N 115.80 W 0.000 359.817 T. WestSak 2672.34 2456:10 : 2400.QO 901.09 N 159.98 W 0.000 359.817 B. West SaJs.- 2916.15 2668.10', .: '26,12.00 1019.65 N 181.03 W 0.000 359.817 C-80 (K-10) 4569.91 4106.10 4050.00 1823.83 N 323.80 W 0.000 359.817 C-40 (K-3) 5823.4~ .~. '., 5196.10 5140.00 2433.39 N 432.02 W 0.000 359.817 Top Morraine --' 6174.22 5501.10 5445.00 2603.96 N 462.30 W 0.000 359.817 Top HRZ 6373.18 5674.10 5618.00 2700.71 N 479.48 W 0.000 359.817 Base H RZ 6499.69 5784.10 5728.00 2762.22 N 490.40 W 0.000 359.817 K-1 6581.34 5855.10 5799.00 2801 .93 N 497.45 W 0.000 359.817 Kuparuk 6618.14 5887.10 5831 .00 2819.83 N 500.62 W 0.000 359.817 Miluveach - SHL (2519' FNL & 1071' FEL, SEC.::18- T12 Begin Dir @ 2.00/100ft : 200.000 MD, 200.00ft Increase in Dir Rate @ 3.0°/1 OOft : 700.00ft MD, 69r!if7ft TVD End Dir, Start Sail @ 29.6": 1353.19ft MD, 1309.06ft TVD 9-5/8" Csg Pt n. Drin out 8-112H Hole: 2816.00ft MD, 2581.02ft TVD TARGET: 6,581.34ft MD, 5855.1 Oft TVD (283' FSL & 1558' FEL, See 7-T12N-R8E) otal Demn¡JiS818.00ft'MD, 6047.89ft TVD (398' FSL & 1578' FEL, SEC. 7-T12N-R8E) 0.00 0.00 N 0.00 E 200.00 0.00 N 0.00 E 697.47 42.85 N 7.61 W 1309.06 259.62 N 46.09 W 2581.02 970.95 N 172.38 W 5855.10 2801 .93 N 497.45 W 6060.88 2917.01 N 517.88 W ConocoPhíllips Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-14 Plan - 35-14 (wp02) 6581.34 6818.00 0.00 200.00 700.00 1353.19 2816.00 Measured Depth (ft) Comments Western North Slope Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-14 Plan - 35-14 (wp02) Western North Slope CasinQ details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) , Casing Detail <Surface> <Surface> <Surface> <Surface> 9 5/8" Casing 7" Casing 2816.00 6818.00 2581.02 6060.88 TarQets associated with this well/Jath Target Name Target Entry Coord inates TVD Northings Eastings (ft) (ft) (ft) Target Shape 3S-14 (Goo) 5855.10 2801 .93 N 497.45 W 5799.00 5996700.00 N 475700.00 E 70024' 07.5966" N 1500 11' 52.0320" W Circle ea Level/Global Coordinates: Geographical Coordinates: 24 October, 2002 - 17:05 Page 60f6 ConocoPhillips '-~ Target Type Current Target ',-,' DrillQuest 3.03.02.002 Spe,}y-Sun Drilling SJrvices Proposal Data - 35-14 Plan - 35-14 (wp02) ..·...·.·...···i,·....·..·r.MP< ·.·.···.P(;¡lta·. ..··.hlbli;,;..:ÄZÖ14~h··· 'Tÿbt'@;tQing~..E~$1jqg~.· .þþgl¢g 8;$ýug... ^..L....:..L...~...L.J!l~:.~; .m .,..~.2....~9.....o . . ......,..~n........^...:..... ..:......~m............: « (ft)···· ·....,.~:..V~.~...:........:, ..:~~~~8g~r.:~..(~/1 9Pft) .. ..1.:..... ....."........q.oo· ................,.......".....,g.:g9.9. ........,..9:,:92.2.. 0.00 0.00 0.00.....................""..· .. . ;<2 200.00 '..' ·~qO;Qq,·· :.0;000 '<Q.QQq'..·..~99¡þ(i·..'........'...·····:'á:qò < ..., ,O:PO 0.000·. 3 700.00$00;QO 10.000 349.933 €i97;47';4~n35>N ,7::e¡1W 2.000 .. ..... 4 ..... ·..·.·..·1~~f·1?"·':~~~;1.~'.,, ..·.~~;P~~,~~~;~~~ ..··.~.39~·P~.', ..:?59.6.?N··..:'~~·O~'^'· ...' :."......,3.0??....:............ ..,... "'>... ,.,........,., ..,. ....<..................:..J . ..~~..... ... ... €i$ß1;34·. .. ..$228.15\2~.5~ª.:949.~Â3,. ..5a5~:10. .......~a01.9~ N '. ..~97A5.W. ...".. .o;qoq· '..... .........9:090... .'......,:o.O?q.: .:. ....... ......%O~Ö; l_..~ê._..¡.__~~!~:q~I......._?~.ê~~~.~J.....~~.~§..ª~......:~~g:~~~1.....~9Ê:9...:~~J._~.~.1?~:91J:JJ..~.~!z.:~.~_'!!L___..__0.oqgl.".~..:..."g.:92RL...~~9.~pq9.J.....c:"..-"-'..!J~Q9q. 23 October~ 2002 - 15:23 - 1 - DrillQuest Spe, }y-Sun Drilling Sdrvices Proposal Data - 35-14 Plan - 35-14 (wp02) rfi:'i~Q ... P~lt~ .. .lhêli~;¡¡IIA~i&.~th ¡. TVP'Nb.hKil)~s¡ ........ .....E~astln~~ ' .. ·pþgl~g.A.BUild .·A.Turn<:, T¢Çlfaé~ ·..·...·..Ir....·..····(ft~:: Mº(~t)·. .. ..tr·' ... ..¡~~).<........<¡(n> . .. ...... . ... .(11)(::·:.·· ...... ·.·jN;·.·.···::· \Ò1.~:Bm, ..¡ erfÖQftf· (f/tOOm···' · ....(~) .J;:'.j::...:.>....::~m'.^m'mm'()':õo .... ...... .... mmmmm.__::__§;~:ª§.T:mm;:..:·!:·P.::9þ2· ^...m·..·:s^Ei·1^Ö^ mSiJ9'S896:5Ò'''N' m^'47tú'àá:'S2"E .... . <.... '.' ......m.....m..;......;..,< .... "'¡2: 200.00 ¡ ¡i2QÖ~QÖ:Q;OQO;. ¡,¡...·¡Q;<:>QÖ m.m:·14àr.$O.·.. 5~93ßØß ..,4¡;61ª~:5~~ .__._~~~:ªmmm..m:¡·:·:·ol·òôò..Q;·. mmm:··Ô;QQ(i ·,·.····.3 "'7ÒQ:Ö() ·¡·····¡5ÖO;ÖÖ 10.000 350.116 '·.¡.·.641;ß'l·. $è~.$~~9.3~¡NTIÎt.,61ä1:.Ó~ï: 2.000 . .. ·'·2~Qdö.··¡ ··:?~q?~,?~~~.1,~ lL.& ..1 681 8·~~.L:_.?'.~~:§gJ.~.g·~g~.U}ÆqL~j_i~L§2~{.z~I._§.@§Jä§;~·$~~E~t§§I~,:~l1~.L 0.000 tLLlg:~~~j.l:LLÞzgp.9.!~._Lm..ŒQ:9,9.g 23 October, 2002 - 15:23 - 1 - DrillQuest ) ) ConocoPhillips Alaska, Inc. Kuparuk River Unit 3S Pad sper-rtY-'·UI1 [J R iCL I N G 'sfef'R V "3' t: e' 5 AH4gU:x,mon ~~J' /' ConocoPhillips DrillQuesl 3.03.02,002 38-14 (wp02) -800 I o I Scale: 1 inch = 800ft 2400 I 3200 I 800 I 1600 I I SHL (25'19' FNL & 107'1' FE!.., SEC. H3· T12N .. R8E) 01/ -----......:.:............---------------------- 0 Begin Dlr @ 2.0°/10011 : 200.0011 MD, 200.00l1TVD ~ Current Well Properties ì ~Q''''.~' lrM:r:a~~~1~~F:ale r 700,0011 MD, 697.4711 TVD ---t 800 - I i ,.<fJrfJ" ~çj, I ... End Dir, Start Sail @ 29.6° : 1353.1911 MD. 1309.0611 TVD I 1600 ....)~lì·7:(. wTfñ:TI/í:!i!;¡---- T - - I Well: 3S-14 Plan Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 5993896.50 N, 476188.52 E 52.65 N, 266.65 W 70· 23' 40.0375" N, 1500 11' 37.4559" W 2519' FNL & 1071' FEL, SEC. 18- T12N - R8E 56.1 Oft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: ::::J en ~ Approved Plan -------------------- -----,--- .' .. i<" '. ~" 'I" (i , ~,¡ J ", ~, 1') ~")¡ Sa,,, ,01 ,v. ,,,,.~,. f¡~t. -,------_._-----'*---- I 2400 - f -........--- ------ I;, w,.,,( S~I,., fYO: J~')fi./(ìf¡ 9-5/8" Casing pt. MD: 281G.OOft i TVD: 2581 .02ft ~¡,T; fTfl!TiJf~,¡;;t(- ì - - - - - I I i I I I - 2400 - ----e-::518""c-s-g-Pr.::-ortrïötl't a: 112"rIö1ê"": - - - - - - - - J 2816.00ft MD, 2581.02ft TVD ",' ~..:..._------------- <Ó LO II III ~ fS .s:: ã. Q) o ëij u '-2 Q) > 3200 - 4000 - -----1---------- ~'".¡u !/1,'''3;! '('Vb: 4{i}Ú./~Y( ------------ 4800 - .t: o o CO II .s:: u .!;;; ~;;;¡",ïITTff<.ï;I';;¡__ t - - - - - - ----:'1'780'---", . - - - - - ---:;.,;¡;; - - - - - - 5~ - ;:;:;:;,;::::;;:'::i . I. ,~...,~ ",S' :~~::41:t\!~:e:'~~ ;':~r:$:: $~~ : : : ~ ~D~a~~.~1 TVD: GOGO. 88ft å5 ëij u en Total Depth: 6818.00ft MD, 6047.89ft TVD (398' FSL & 1578' FEL, SEC. 7- T12N-R8E) I -800 I 800 I 1600 I 2400 I 3200 o Scale: 1 inch = 800ft - 800 - 1600 ::::J en ~ - 3200 (Ó LO II III ~ fS .s:: ã. Q) o (ij u 1:: Q) > - 4000 - 4800 - 5600 õ o CO II .s:: u .!;;; å5 ëij u en ) ) ConocoPhillips Alaska, Inc. Kuparuk River Unit 3S Pad '~/ ConocoPhillips 35-14 (wp02) sper-II'Y-,·U:" d-j¡::fIC'LTi\i"G 5 E FI V t r:"e 5 Al1aßjt¡.yrt.;.m ç~r(¡( TARGET: 6581 .34ft MD, 50155,10ft (?ß~V ¡::'Sl.. &. 15Sa' ¡::'[1" S\~C '7-"i"'12N·HHE) 7' Casing Pt. MD: 6818.0011 TVD: 6060. 88ft o o I I 400 I 800 I Scale: 1inch = 400ft -1600 I ·1200 I Eastings(2519' FNL, 1071' FEL) ·800 -400 I I Total Depth: 6818.00ft MD, 6047.89ft TVD (398' FSL & 1578' FEL, SEC. 7-T12N-R8E 2800 - - 2800 w 2400 - - 2400 CÞ cr ~ .¡::.. ~ "'0' 4800,00lt '"0 o ß 2000 - ..\10: 4400,001I: - 2000 Reference is True North .\10: 40OQ,00It 1600 - Well: Current Well Properties 3S-14 Plan - 1600 FC: 3600.0011 !/) C> c :ë 1::: o Z Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 1200 - RKB Elevation: North Reference: Units: 5993896.50 N, 476188.52 E 52.65 N, 266.65 W 70023' 40.0375" N, 1500 11' 37.4559" W 2519' FNL & 1071' FEL, SEC. 18- T12N - R8E 56.1 Oft above Mean Sea Level True North Feet (US) I-VD:3l00,OOfl !/) C> c :ë 1::: o Z - 1200 Approved Plan .,¡vD: 2aoo.00It 800 - ¡ /f I I VD 24oo00rt I 9-518" Csg Pt ... D rill out 8-1/2" Hole: 2816.000 MD, 2581.02ft TVD ! "'~ '~î 9-5/8' Casing Pt, MD: 2816,0011 TVD: 2581,02ft - 800 ~ o o '<t II .c u .!: 400 - I End Dir, Start Sail @ 29.6° : 1353.19ft MD, 1309,06ft TVD ",0' '~O<>I Increase in Djr Rate @ 3.00/1001t: 700.00ft MD, 697.4~ i ~ '¡VI '20000lt o _ _ _ _ _ _ Begin_ Djr @ 2~00/100tt~ 200.0ot~ MD, 20~OOtt TV~ ~I_ _ _ _ _ _ _ _ _ 0 ~ 8 '<t II -400 .c u .!: Qj ãi u en Qj ãi u en Si-·IL (2519' Ft'Jl & í()ì1' FEL.. SEC. 1l)- TEN" RßE'¡ I -1600 I -1200 I -800 I -400 o I 400 ( 800 Scale: 1 inch = 400ft Eastings DrlllQuest 3.03.02.002 Phillips Alaska, Inc. 35-14 (w 2) MD Inc Azim. SSTVD TVD NIS EIW y X DLS V.S. Comment ""- (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) (ft) 0.00 0.00 0.00 -56.10 0,00 0.00 N 0,00 E 598389650 N 476188.52 E 0.00 0.00 SHL 200.00 0.00 0.00 143.90 200.00 0.00 N 0.00 E 5993896.50 N 476188.52 E 0.00 0.00 Begin Dir in 12-1/4" Hole 700.00 10.00 349.93 641.37 697.47 42.85 N 7.61 W 5993939.38 N 476181.05 E 2.00 43.52 Increase in Dir Rate @ 3.0o/100ft 1353.19 29.60 349.93 1252.96 1309.06 259.62 N 46.09 W 5994156.27 N 476143.26 E 3.00 263.68 End Dir; Start Sail 1625.80 29.60 349.93 1490.00 1546.10 392.19 N 69.63 W 5994288.91 N 476120.14 E 0.00 398.32 B. Permafrost 2160.57 29.60 349.93 1955.00 2011.10 652.23 N 115.80 W 5994549.10 N 476074.80 E 0.00 662.43 T. West Sak 2672.34 29.60 349.93 2400.00 2456.10 901.09 N 159.98 W 5994798.10 N 476031.41 E 0.00 915.18 B. West Sak 2816.00 29.60 349.93 2524.92 2581. 02 970.95 N 172.38 W 5994867.99 N 476019.23 E 0.00 986.13 9-5/8" Csg pt n. Drill 8-1/2" Hole 2916.15 29.60 349.93 2612.00 2668.10 1 019.65 N 181.03 W 5994916.72 N 476010.74 E 0.00 1035.59 C-80 (K-10) 4569.91 29.60 349.93 4050.00 4106.10 1823.83 N 323.80 W 5995721 .35 N 475870.53 E 0.00 1852.35 C-40 (K-3) 5823.46 29.60 349.93 5140.00 5196.10 2433.39 N 432.02 W 5996331.26 N 475764.26 E 0.00 2471.45 Top Morraine 6174.23 29.60 349.93 5445.00 5501.10 2603.96 N 462.30 W 5996501.92 N 475734.52 E 0.00 2644.68 Top HRZ 6373.18 29.60 349.93 5618.00 5674.10 2700.71 N 479.48 W 5996598.72 N 475717.65 E 0.00 2742.94 Base H RZ 6499.69 29.60 349.93 5728.00 5784.10 2762.22 N 490.40 W 5996660.27 N 475706.92 E 0.00 2805.42 K-1 6581.34 29.60 349,93 5"799.00 5855,10 2801.93 N 497,45 VV 5996700,00 f'\I 47570û.00 E 0.00 2845.75 TARGET -.~~ 6618.14 29.60 349.93 5831.00 5887.10 2819.83 N 500.63 W 5996717.91 N 475696.88 E 0.00 2863.92 Miluveach 6818.00 29.60 349.93 6004.78 6060.88 2917.01 N 517.88 W 5996815.15 N 475679.94 E 0.00 2962.63 Total Depth Cómp~y: Field: Reference Site: Reference Well: R¢f¢rt\llce Well path: Phillip$ AlaSka Inc. Kuparuk RiverUnit KlJparuk3S Pad Plan:·3S"14 PIàr1:38-14 ) ') Sperry-Sun Anticollision Report I)att\; 10/24/2002 '(hue: .. . 09: 13;25 Pagt\: Có-ordinate(NE) Reference: Vertical (TVD) Reference: Well:· Plan: 3S-14, Grid North 56~1. 56.1 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.000 ft Depth Range: 28.100 to 6818.000 ft Maximum Radius: 878.990 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 5/14/2002 Validated: No Planned From To Survey ft ft 28.100 500.000 500.000 6818.000 Casing Points MD TVD ft ft 2816.000 2580.983 6818.000 6060.756 Planned: 38-14 (wp02) V3 Planned: 3S-14 (wp02) V3 Diameter in 9.625 7.000 Hole Size in 12.250 8.500 Name 95/8" 7" Summary <___________m________ Offset Wellpath .----------------------> Site Well Wellpath Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 38 Pad 38-26 3S-26 Plan: 3S-02 Plan: 38-02 Plan: 3S-03 Plan: 38-06 Plan: 38-06 Plan: 38-07 Plan: 38-08 Plan: 38-08 Plan: 3S-09 Plan: 38-10 Plan: 38-10 Plan: 38-15 Plan: 3S-16 Plan: 38-17 Plan: 3S-17 Plan: 3S-18 Plan: 38-19 Plan: 38-19 Plan: 38-20 Plan: 38-21 Plan: 38-21 Plan: 3S-22 Plan: 3S-23 Plan: 38-24 3S-26 V1 38-26a V1 Plan: 38-02 V2 Plan: 3 Plan: 38-02F V2 Plan: Plan: 3S-03 V2 Plan: 3 Plan: 3S-06 V2 Plan: 3 Plan: 38-06F V2 Plan: Plan: 38-07 V3 Plan: 3 Plan: 3S-08 V2 Plan: 3 Plan: 38-08F V2 Plan: Plan: 38-09 V1 Plan: 3 Plan: 3S-10 V1 Plan: 3 Plan: 38-1 OF V3 Plan: Plan: 3S-15 V1 Plan: 3 Plan: 3S-16 V1 Plan: 3 Plan: 3S-17 VO Plan: 3 Plan: 38-17F V1 Plan: Plan: 3S-18 V3 Plan: 3 Plan 38-19F V2 Plan: 3 Plan: 38-19 V1 Plan: 3 Plan: 3S-20 V1 Plan: 3 Plan: 3S-21 V1 Plan: 3 Plan: 38-21 F V2 Plan: Plan: 3S-22 V2 Plan: 3 Plan: 3S-23 V1 Plan: 3 Plan: 38-24 V1 Plan: 3 Version: Toolcode Tool Name CB-GYRO-SS MWD Camera based gyro single shot MW D - 8tandard Reference Offset Ctr-Ctr No-Go AlloWable MD MD Distance Area Deviation Warning. I ft ft ft ft ft 594.839 600.000 236.079 10.075 226.082 Pass: Major Risk 594.839 600.000 236.079 10.075 226.082 Pass: Major Risk 250.217 250.000 240.334 5.082 235.252 Pass: Major Risk 250.217 250.000 240.334 5.082 235.252 Pass: Major Risk 300.311 300.000 220.955 5.891 215.065 Pass: Major Risk 250.146 250.000 160.409 5.173 155.235 Pass: Major Risk 250.146 250.000 160.409 5.173 155.235 Pass: Major Risk 350.264 350.000 140.274 6.606 133.680 Pass: Major Risk 250.111 250.000 120.409 5.233 115.175 Pass: Major Risk 250.111 250.000 120.409 5.233 115.175 Pass: Major Risk 300.168 300.000 101.314 6.444 94.870 Pass: Major Risk 300.144 300.000 80.877 6.486 74.391 Pass: Major Risk 300.144 300.000 80.877 6.486 74.391 Pass: Major Risk 349.926 350.000 21.605 7.527 14.079 Pass: Major Risk 299.916 300.000 40.885 6.287 34.599 Pass: Major Risk 299.866 300.000 61.339 6.227 55.113 Pass: Major Risk 299.866 300.000 61.339 6.164 55.175 Pass: Major Risk 299.812 300.000 80.414 6.311 74.103 Pass: Major Risk 249.901 250.000 100.417 5.162 95.256 Pass: Major Risk 249.901 250.000 100.417 5.162 95.256 Pass: Major Risk 249.874 250.000 120.398 5.017 115.381 Pass: Major Risk 299.697 300.000 140.507 6.225 134.282 Pass: Major Risk 299.697 300.000 140.507 6.225 134.282 Pass: Major Risk 249.841 250.000 160.164 5.112 155.052 Pass: Major Risk 299.624 300.000 180.466 6.247 174.218 Pass: Major Risk 249.806 250.000 200.429 5.153 195.276 Pass: Major Risk ANì1-COLLISION SETIlNGS COMPANY DEfAll.S WElll'ATII DETAILS Nm: +Nl· +FJ·W ~\rthîn l:asline l..alitud Longi!ude Sbt PhiIips AmkaInc. Pbn:3S-14 - Interpolation Method:MD Interval: 50.000 Engineerng 'bII:' 53.505 ·2M.SIY. 5'i<J3!!<){\.50 47M!!!!52 70'23'-IO.037N 150'1 \"37.456W NlA Depth Range From: 28.100 To: 6818.000 Kuparuk Rig: 1'<7ES Un_:~..~ P~ Q7Q 1'01) PnflT7JV'Æ Dlnn· 1'i 1 A V'-¡I'~ Cakuh1i>n MetOOd: Minimum Cun.= Ref. Datum: 56.1 56. 100ft Error System: lSCWSA V.Socwn Origm Origin StarÚ1g SURVEY PROGRAM ScanMetOOd: TrnveyliOOecNorth Angk +NI-S +EJ-W FromTVD Error Suñace: EJlipU:al + Caslllg Waming MetOOd: Rtà:s Basal 350.12' OJXX) 0.000 0.000 Depth Fm Depth To SurveylPlan Tool From Colour To MD From Colour To MD 28.100 500.000 Planned: 35-14 (wp02) V3 CB-GYRO-SS 0 - 200 0 - 200 500.000 6818.000 Planned: 3S-14 (wp02) V3 MWD ~gg == ¿gg ~gg == m 600 800 600 w,."^W'W~ 800 800 - 1000 800 - 1000 1000 - 1200 1000 - 1200 1200 - 1400 1200 - 1400 1400 - 1600 1400 - 1600 1600 1800 1600 1800 1800 - 2000 1800 - 2000 2000 2500 0 2000 2500 o 2500 - 3000 -36 Je 2500 - 3000 -174 174 3000 3500 . . 3000 3500 3500 - 4000 ~ -. :" .... ~ 3500 - 4000 -1'0 ; Ii -30 ~:~~ ~~3~~~ ~1 :: '--100 -20 ,,~/.;~.'~,:.':<.~.'. . ... 0?~o...., o. ", ~ . / // '~.>:" ". ", .... / /...~ 'Ox '_" / '. / />: ,. . ~s: /,' ' ~: \;,~;(./;( =4~,Xl\ 90 ,~\ \ ";", l,' ~:~, ~ .~. J ,:r-;o' ,..' ... n...·../ I,,(¡;.. / / -SO PI"3S,15c>r,w3S-IS) ,\ ~:~';:~;jÍ -. ' ' -~~,>/j/ -100 ~O ~ ;f!";~ =~;~ '_ .,~. ,.u.~., .' ~.. .,>. .:.:.....,..... ·nn..../·.-··/.../;\, ,X,.. _/'-___ -. -~_ / -~---._. ._.~_r-~··\ ././ .,,/ -150 -30 " 2[';':/= 30~,~/:=¿:;;;: -174 -36 180'J SECfION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSec Target 1 2R.lOO 0.00 0.00 2R.lOO 0.000 0.000 0.00 0.00 0.000 2 200.000 0.00 0.00 200.000 0.000 0.000 0.00 0.00 0.000 3 700.000 10.00 350.12 6970465 42.R77 -70468 2.00 350.12 43.523 4 1353.2RO 29.60 350.12 1309.135 259.814 -45.266 3.00 -0.01 263.728 3S 14 (WpOi"'Þ) 5 65R 1ARO 29.60 350.12 5R55.100 2R03.779 -488.569 0.00 0.00 2846.028 3S (14) -.£¡ 6 6X I X.OOO 29.60 350.12 6060.756 2918.866 -508.623 0.00 0.00 2962.849 --- Approved Plan --- Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [lOOftJin] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ftJin] ) Target: 38 (14) ) Well: Plan: 3S-14 Based on: Plan: 3S-14 (wp02) Vertical Depth: 5799.00 ft below Mean Sea Level Local +N/-S: 2803.78 ft Local +E/-W: -488.57 ft Longitude: 150° 11 '52.032W Radius: 150 ft Site: Kuparuk 3S Pad Drilling Target Conf.: 75% Description: Map Northing: 5996700.00 ft Map Easting : 475700.00 ft Latitude: 70024'07.597N Shape: Circle ·.·.·.·.·[··.·.1.·.·:l··+:j· ,)·:··+-'6 ....,....,....,...,....j.. ..1...1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I , I , , , I , 1 , 1 , 1 1 , , 1 I.::L::I.::[.:. LIt......I...t..J..I... 'A~(\ 'A 1<1(\ '.Af\t\ ,,, .........~3rO........ .·r· ¡) ~~'1iLji~JJ¡~ ··..'o~.9Ji e, . :1 ".. ...t,,'¡'" j j. .3Ø2~...:...:....,............. .................. ...........................,............. -I ,..1,. j?èOO -! ..J.....,......... : i ¡. i . ..'.. .1. .... . ...... ...... .. .... . .. . , ··········¡"iiIJ . ········,···,····I···..····'·..'···.,...j········ :1' " ·······1 ....... ...'... ....... ·:·i. .·:........··········1············ ..,.. 04o!± ..... '/ ./ . , b .,. i····· .·····:···1····· ..,. .! : ...,' ..... : .,..: .... ....... T ····.···1, . ' .... i , .j ... . ..:.......: ... ..... ...... ..... I ..... ....... ..1. ... .... ... i. .;"" ,i:r: )~ : : .....'.....¡...... ........ .,....... '....... ,.., ,. . I: ........ : :: .':.4£ i ..L I· ...... .........¡.... ill ···Jt g-2? . I' , ... Ì29 _I i ::r·:; -+-29 -I.... -j....... :i.·...·... -1-29 ~'.'.' :1 -Lp9 _L..~... ...... .'- i: 'I"'j : . ...... ....... ,;:it':' ""\.¡ , , ....... . ....f... ................ .............. \ I. .... ,. r '/ / , ,j.¡n:,¡:,¡,;tl,,~ ';;·1 ::;;:':!it: .. l.l'T.: iI', t¡::::IIj):~¡,:, "~:'~:II ;\;1::1:1: ,; , · _..,'. ~ ,lluil;¡¡r- '.! 'I..' 'I' _. - " -- L __' - - '. -- 1 ; , i : /~ ..·.92011 ¡ : - 8 , : '.'::þ'. - - ~ . , , ......... ....... .............. I I· , ¡ .9Oü.tf - .J". ........... ..... '. ++- ¡. +- ., ....... . . .~= J 2·8 _I , ~ ~28 g -:-2800 -f ··~d...¡........·...........·.·..¡. . I 40...~....,...... .......L.,... ¡ Þ,.. ,. ~ 2()··:·..· ........... ß.... : 12 i !~ .. ....... ........ '#E , IE 4øf-t . i' -~ I ·1 1 I - .... .- ...- .... .. . ? :::r.. -. -! - -< "'-¡-2540" , :, . i , , . i ,_ '740 -720 -700 -680 -660 -640 -6:20 -600 -580 -560 -540 -520 -500 -480 -460 -440 -420 -400 -380 -360 -340 -3lw -300 -280 -260 -24Ö' =t-~$+Q·I·T1·1"T+T1·rT+1"T·1"TI·1"T1"TI..r..1"rT·t..1"T..r1"I·TTrT..I·rT·TTI·TT"r1+,"r"rT+1"I"T·1"I·TTT·T··1"r·1"r..l·rrTr·1"·1"r1"r"I·TrT·11·lr1"r+rrT·1·1·"rrT"1"+1"r1"111"1"r·r+1"1"r1"l·I"Tr'1"+rf~fu ) ) 3S-14 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" CasinCllnterval Risk Level I M itiqation Strateqy Low Monitor cellar continuously during interval. Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation Low Moderate Moderate Low Low 8-1/2" Hole / 7" Casinq Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Low Moderate Moderate Moderate If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM M itiqation Strateqy Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. / 35-14 Drilling Hazards Summary.doc prepared by Scott Lowry 7/30/02 Page 1 of 1 KRU - 38-14 t .~~ctor Proposed Completion Schematic Single Completion ) .~ ConocoPhillips 16"x30" insulated I" r ~ "" 2 ~ conductor @ i i ~ +/- 108' MD I I ~ j ~ ~ TAM 9-518" Poft..tiW. Z ~ d~ Collar Stnd ~ ~ Grade BTC I ~ Threads (+/- ~ ~ 1000' MOITVD) ~ ~ I ~ I ~ "" ~ Surface csg. i ~ 9-5/8"40# L-80 i ~ BTC (2816' MD /......u:. ~ 2581' TVD) ~ Casing point ~ ~ 100' above the ~ C80 sand ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ :.:.) C Sand Peñs (to be done after rig moves off) Production csg. 7" 26# L-8Q BTCM (+/- 6818' MD) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~-q~ ~ ~ ~ =~ ~ ~ ... . ~ ~ ~~j:; ~ I I i ~ i ~ i ~ ~~ ~ ~ ~ ~ ~ ~ ~ L...... - J r- i--.- - .." r- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - - i . -.-,). ~ ~ ~ ~ ~ ~ ~ ~ I ~ Gemen~ 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-112", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. Use of port collar at the discretion of the drilling team. 3-1/2" X 1-1/2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-112" Camco "DS' nipple w/2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +/-100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'D' nipple w/ 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide w/ shear out sub. Tubing tail 50' above top planned perforation. / TD @ 6,818' MD / 6061' TVD (200' MD below Miluveach) Scott L Lowry 10/28/02 .- .... . . ->"- -n --<-ç:..- ~~~-·~~~~~'·~;~~~*~~J~~~-~~'~'¡~/~-."-~~~7~_-~~~:?~~~_~~~~~,,~~:,,-~~~"~';¿:_=-:~j;~;' II'~~'~-~'~ K. ~LL~UP-DRAKE ~ .... .~-, ... ... .. .,- ..... .'. . - "1~Ó; ~. . PH'LL.'P.S PET.'.RO.' LEUMCO....MPANY 711 GST. .1\/ l . .... r ~ ANCHORAGE AK \J95010AT.}ytJ~l.) /4tJ;(.frn I) ~~ CHA·.S.,..·' E····c.h.as..e.ManhattanBanku.SA...N..A ValidUpT.05000Dollars . , . . 200WMeCIay Center Dr., Hewark. DE 19711 .. ... . . . . . . I :0 Z~þ- 4r~J]--k ~ '1:0:11. ~OO ~1, 1,1: a800001, 2 '1'25 '1'1I'~OO'1' / ~~~V Ji -..Æ ·¡.t~·~~ ~- -;:;. Wi ~ -~-- 2~~· 1.oóÌ::----:·~'"-·~L-- ~-¿·~iir~......~~=<-=-J- --:__':E~ ~--~-~~-~,:-'-Jm<'~~~~~~ ~. ""-~/ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~R(J/ 3~-/~ PTD# 202- - 2-. Z ) CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception 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 COMPAN~~ Æ//fWELL NAME~4 .3,<;-/51 PROGRAM: Exp _ Dev _ Redrll_ Re-Enter _ Serv ~ Wellbore seg_ FIELD & POOL £j 70/0 0 INIT CLASS /- /~ .lr- 0 /1'-'''' GEOL AREA ?,7rJ UNIT# // /6";'Y ON/OFF SHORE..Q.:t) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . '-:". . . . . . Y. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . y' N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N /l?, //.J, J,",,> 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 4.!L ~<.....-- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order # 2/1 ~ *" J:':,^-J,_I ~ (Service Well Only) 14. All wells wlin Y-s mile area of review identified. . . . . . . . .. c.v~ A ;(/.d~ c:. ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N 16. Surface casing protects all known USDWs. . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . N, 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . fy tIP f-K W '^"^- A-f) · 19. CMT will cover all known productive horizons. . . . . . . . . N 20. Casing designs adequate for C: T, B & permafrost. . . . . . . N "" I ~ '. 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N fUe<.. r (',. 7 &S . 22. If a re-drill, has a 10-403 for abandonment been approved. . . . rJ.h 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . .. . N 1/1/1 25. Drilling fluid program schematic & equip list adequate. . . . . N ll/v;v"¿ , Y{ uJ l 0 . '5 ¡JYl . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 27. BOPE press rating appropriate; test to 5000 p sig. N k- { 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~./G I t..( z, 0 L 29. Work will occur without operation shutdown. . . . . . . . . . . . ~. 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y .@/ 31. Mechanical condition of wells within AOR verified. . . . . . . . ¥-N /JIlt- 32. Permit can be issued w/o hydrogen sulfide measures. . . . . CŸ?N 33. Data presented on potential overpressure zones. . . . . . . . }{ 34. Seismic analysis of shallow gas zones. . . . . . . .: .: .: .: .: ..: ~ ~.. /U , Aj 35. Seabed condition survey (if off-shore). . . . . . . IJ 36. Contact namelphone for weekly progress reports. GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE APPR DATE (Service Well Only) GEOLOGY APPR DATE /t/ ~~2 (Explorato~ Õ~ly) Rev: 10/15/02 t':r?1'-' ,: %< I1~YU ,. /~ UIC ENGINEER COMMISSIONER: /4M :L t?'fO~O~ h-/IJ 2-/"" Z, TEM JDH JBR SFD_ // MJW WGA G:\geology\perm its\checklist.doc COT DTS MLB /~<' l l' J. Comments/Instructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. , To inlprove the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of infonnation. ) ) Sperry-Sun Drilling Services LIS Scan Utility :2.0~ -;;t d--- \ Jf(P~ci $Revision: 3 $ LisLib $Revision: 4 $ Sal May 24 00:26:40 2003 Reel Header: Service n~me.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0:3 /0.5 /24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation NumbeL·...... 01 Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . S'I.'S LIS Writing Library. Scientifi.c Technical Services Tape Header Service name.~...........LISTPE Dä t e... . ... . . . . . . . . . . . . . . 0 J /05/24 Origin.. .... . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation NurnbeL..... 01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOr CorrunenL Eecon:J TAPE HEADEE Kuparuk Eiver MWD/¡V¡AD LOGS Ii WELL NAME: API NUMBER: OPCRATOR: LOGGING COMPANY: TAPE CREATION DATE: if ,JOB DAT.1\ 3S-14 Redo 501032043900 Conoca Phillips Alaska Inc. Sperry Slm l1-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AKMW22198 E. QUAM M. THORNTON MWD RUN 2 AI<MW22198 E. QUAM M. THORNTON # SURFACE LOCATION SECTION: TOWNSHfP: RANGE: FNL: F'SL: FEL: FWL: F,J.F,VA'T'TON (F1' FEOM KELLY BUSHING: DERRICK FLOOR: GROUNO LF.VF.T.: ,18 l?N 8E 2519 1071 MSl. 0) .00 55.90 ?7.70 if WELL CASING RECORD 1ST STRING 2ND STRING 3ED STEING PRODUCTION STRING OPF.N HOLF. CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.290 16.000 108.0 8. :,00 9.G25 2808.. C¡ if EEtv'J\RKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MOl UNLESS OTHERWISE NOTED. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD1. 3. MND RU!'! 100 !^JI\S DIRECTION1\L !^JIT!-l DUJ\L Gl'J·1..fv[J\, P}\Y ) ') (DGR) , UTILIZING GEIGER-MULLER TUBE DETECTORS. 4. MWD RUNS 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MULLER TUBE DETECTORS ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO-DENSITY (SLD). .s. MWD DATA IS CONSIDERED PDC PEf\. THE GKPlò" GEOSCIENCE GROUP. 6. MWD RUNS 100 - 200 REPRESENT WELL 38-14 WITH API # 50-103-20439-00. THIS WELL REACHED A TOTAL DEPTH ('rD) OF 6895 I HD, 6175' TVD. SROP = SMOOTHED RATE OF .!?ENETRATION IÑHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SHOOTHED PH,1l,.SE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOO'I'HE:U PHASE: SPACING) . SEMP = SHOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACIN(3) . SFXE = SMOUrHED FORMATION EXPOSURE TIME. SPSF = StvIOOTHED NEUTRON POROSITY SANDSTONE tvINrRIX FIXED HOLE SIZE. SRD? SMOOTHED BULK DENSITY COMPENSATED(LOW-COUNT BIN). S Hr. F"I' IJE: RI VE D RE:SI S'I'IVI '["{ ( SHAL,I,OIi\l StLIFT DERIVED RESISTIVITY (MEDIUH SHIFT DERIVED RESISTIVITY (DEEP SC02 = SMOO'rl:ŒD STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 SMOOTHED NEAR DETECTOR ONI~ PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = SLD SENSOR DEPTH IN STEERT.NG INTERVALS. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG I?R.OCESSING: BOREHOLE SIZE: IlI\lJ[) SAL,TNT'I"{: FORMATION WATER SALINITY: HUD WEIGHT: FLUID DENSITY: MATRIX DENSITY: MATRIX LITHOLOGY: 8.5" ]00 - 300 ppm CL- 25,000 pprn CL- 9.4 - 12.3 ppg 1.00 glee 2.65 glee SANDSTONE $ File Header Servic:e name............ .STSI.TR.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/05/24 M~ximum PhYGie~l Rccord..65535 file Type.............. ..LO PLevi0u::; File Ndwe.......STSLIB.OOO Comment Record fILE HEADER FILE NUMBER: EDITED MERGED MWD DepLh ::;hiILed DEPTH INCREt1E:NT: # FILE Süivü"íARY PBU TOOL CODE GR RüF' N':NT 1 dud (;llµµed (;urve::;; dll blt ruel':; meryed_ .5000 STI\RT DEPTH 52.:) 108.5 26-12..5 STOP DE PTH 6862.5 6895.0 6811. C ) ) FCNT PEF RPD RPM RPS RPX FET DRHO RHOS NPHI $ 2642.5 2652.0 2792.5 2792.5 [/92.5 27 92.5 2792.5 2808.5 2808.5 2808.5 6811.0 6820.0 6855.0 6855.0 6855.0 6855.0 6855.0 6820.0 6820.0 6811.0 # 8^SELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEJ\SURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ff MERGED DATA SOURCE PBU TOOL CODE MWD Jv1W 0 $ BIT RUN NO MERGE TO!? 1 52.5 2 2820.0 MERGE BASE 2820.0 6895.0 ff REMARKS: MERGED MAIN PA.8S. $ II Data Format Specification Record Data Record Type..................O Data Specification Block 'I'ype.....O Logging Direction.................Do~m Optical loq depth uni t:s. . . . . . . . . . . Feet Data Reference Point..............Undefined Frame Spacing..... ............... .60 .1IN Jv1ax frames per record.............Undefined AbsenL value...................... -999.25 Depth Units....................... Datum Speci. fi.cation Block sub-type... 0 Name Service Ordc:r Units Size NiJam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP .MWD FT/H 4 .1 68 4 - GR MWD API 4 .1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RI?M MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 '7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 PEF MWD BIE 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 NCNT MWD CNTS 1 1 68 11·1 12 RHOB t'JIWD GICC 4 1 68 48 13 DRHO MWD G/ce 4 1 68 52 14 Fi rst Last Name SerV.lce Unit Min Max Mean Nsam Reading Readin DEPT FT 52..5 G895 3473.75 13G8G 52.5 GO 5 c' ROP WpJD FT!H 2.. 7 796.51 188.378 13017 108.5 68 5 GR MWD API 19.69 409.j9 99.99i:U U6n 52.5 6d62..::J RPX ì"fV'JD o !-¡f"1¡V¡ 0.28 2000 3.89446 8126 27 92.5 6855 RPS MWD OHMM 0.21 2000 1.05532 8126 2792.5 6855 RPM MWD OHMM 0.1 2000 4.8661 8126 2"192.:' 68:':' Rt'D HWD o HtviJ"l 0.32 2000 9.11868 8126 2792.5 G85;:, FST ~1í"JD IlR 0.14 97 56.4967 0.926134 8126 2792..5 6855 NPHI M~'D PU-;3 19.86 81.76 49.0947 8006 2808.5 6811 i?EF ¡víV'JD BIE 0.39 11.57 2.95948 8083 2652 6:S:::CI FCNT M\^JD CNTS '106 1195 598.651 80811 26'1::~.5 62,11 NCNT MWD CNTS 2182 3599 2569.93 8084 2642.5 6811 RHOB ¡V¡WD Glee 1.981 2.912 2.30282 8024 2808.5 6820 DRIIO Hí"JD GICC -0.1.88 0.313 0.0390764 8024 2808.5 6820 ) First Reading For Entire File..........52.5 Last Reading For Entire File...........6895 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/05/24 Maximum Physical Record..65535 FEe Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Vers.i.on Number.......... .1.0.0 Date of Generation.......03/05/24 Maximum Physical Record..65535 F i 1 e Type................ 1.0 Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DE PTH INCRE~1ENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP 2 ') header data for each bit run in separate files. 1 .5000 START DEPTH 52.5 108.5 STOP DEPTH 2 'j 63 . 0 2820.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOLt.JNHOLE SOFTWARE VERSION: DATA. TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TO!? LOG INTEJWAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: Ml\XIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR ... ~ BOREHOLE l\ND 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 (P?M): ~LUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPER.LI"TURE (DEGF) HUD AT HEASURED TEHPERATURE (i"IT): MUD AT MÞ~,{ CIRCUU\TING TERM PERATURE: MUD FILTRATE AT MT: HUD CAKE AT t"1T: 19-DEC-02 Insite !1. 3 Memory 2820.0 . (ì 33.6 TOOL NUMBER '1"/114 12.300 108.0 SPUD 9.40 165.0 9.4 6.3 .000 .000 .000 .000 .0 7'1. ,I .0 " 0 ') / ') " NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL S'rANDOFF (IN): EWR FREQUENCY (HZ): jf REf\1ARKS : $ # D~t3 Format Specification Record Data Record Type.................. 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 Absent value...................... - 999.25 Depth Uni.ts....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam g,ep Code Offset Channel DEPT FT 4 1 6f3 (I 1 ROP MWDOIO FT/H 4 1 68 4 2 GR MWDOIO API 4 1 68 8 :3 First Lùst Name Service Uni.t Min Max Mean Nsam Reading Reading DEPT FT ~)2. 5 2820 1436.25 5536 52.5 2820 ROP MWDOIO FT/H 7.31 454.56 195.201 4897 108.5 2820 GR MWDOIO API 19.69 135.91 69.3,549 5422 52.!) 2'163 First Reading For Entire File..........52.5 Last Reading For Entire File...........2820 File Trailer- Service name............ .ST3L1B. 002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/05/24 Maximum Physical Record.. 6553.5 File Type................ LO Next File Name.... .......8T8LI8.003 Physical Eor File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/24 Maximum Physical Record..6bb3b rile Tyµe................LO Prcviou~ file N~mc.......STSLIC.002 Comment Record f:'ILE HE1\DER FILE NUMBER: 3 Ri\W ¡vrwo Curvcs ~nd log he~dcr d~t~ for c~ch bit run in sep~r~te filc~. BIT RUN NUMBER: DEPTH INCREMENT: .5000 # FILE SUr-¡fv1ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2i63.b 6~62.!) ) RPS 2792.5 6855.0 FET 2'/92.5 6855.0 FCNT 2792.5 6811.0 RPM 2792.5 6855.0 PEE' 2ï 92. S 6820.0 NCNT 27 92.5 6811.0 RPD 2792.5 6855.0 RPX 27 92 . 5 6855.0 NPHI 2808.5 6811. 0 DRHO 2808.5 6820.0 RHOB 2808.5 6820.0 ROP 2820.5 6895.0 $ if LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY Or<.. REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT FWTA'I'ING SPEED (RPM): HOLE INCLINATION (DEG MINIHUH ANGLE: MAXIMUM ANGLE: if TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOT'I'OM) TOOL TYPE DUAL GAMMA HAY ELECTROMAG. RESIS. I.] COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRiLLER':3 CASING DEPTH (FT): BORE:HOLE: 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 MEJ.\SURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPE:RATURE:: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: JvlATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ ff Data Format Specification Record Data Record Type.................. 0 D~t~ Specification Clock Type. ....0 Logging Direction.... .......... ...Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................. ...60 .lIN Max frames per record.............Undefined Absent value.... ....... ........ ...-999.~5 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . DaLufII S¡:.,ec.i.ficdLic,r! Bluck sub-Ly¡:.,e...O ) 23-DEC-02 Insite 0.43 Memo·L'Y 6895.0 22.8 30.7 TOOL NUMBER 142827 121079 119007 39307 8.500 2t108.0 LSND 12.30 55.0 8.0 100 7.9 3.60U 1.904 3.000 4.500 6e.o 131.]. G ó8.0 68.0 \ ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 GR MWD020 AP I 4 1 68 8 ~, Rex lVlWD020 OHlVl(V¡ 4 1 68 12 4 RPS .MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 "I i?ET ¡'1ìi'lD020 H1\. 4 1 68 28 co NFIll MWD020 PU-S 4 1 68 32 9 PEF MWD020 BIE 4 1 68 36 10 FCNT JvTWD020 CNTS 4 1 68 40 11 NCNT Mt^!D020 CNTS '1 1 68 '1,1 12 RHOB MWD020 G/CC 4 1 68 48 13 DRHO MWD020 G/CC 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2763.5 6895 4829.25 8264 2763.5 6895 ROP MWD020 FT/I-¡ 2.7 '796.51 184.278 8EjO 2820.5 6895 GR (V¡WD020 ¡"PI 42.31 409.39 120.263 8199 2763.5 6862.5 RPX .MWD020 OHMM 0.28 2000 3.89446 8126 2792.5 6855 RPS MWD020 OHMM 0.24 2000 4.05532 8126 2792..5 6855 RPM .MWD020 OHMM 0.1 2000 4.8661 8126 2792.5 6855 Rl?c. r"l'V\IDO 2 0 OHÎ'ü'-l 0.32 2000 9.11868 8126 2792.5 6855 FET M'V\m 0 2 0 HE 0.1497 56.4967 0.926134 8126 27 92.5 6855 NPHl MWD020 pu-s 19.86 81.76 49.0947 8006 2¡:W8. .5 6811 PEF ¡vrwD020 BIE 0.31 11.57 2.93278 8056 2792.5 6820 !?CNT MND020 CNTS 106 1195 599.48 8038 2792.5 6811 NCNT MWD020 CWE S 2182 3599 2570.84 8038 2792.5 6811 RHOS MWD020 GICC 1. 981 2.912 2.30282 8024 2808.5 6820 DRIlO .MWD020 G/CC -0.188 0.313 0.0390764 8024 2808.5 6820 First Reading For Entire File..........2763.5 Last Eeading For Enti.r:e File...........6895 F'ile Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/24 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 [Jhysicul EOr Tape Trailer Service name.............LISTPE Ua t e. . . . . . . . . . . . . . . . . . . . . u.j / 0 ~ / ::.:: 4 OLigin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNr:NO\^JN Continuation Number......01 .. T, _. I 1T1.. c,' ...,., . Y ,\. TT....." Jr."'.""" T l'it:::'AL .1 <:1!:--II:::: l~dllle'................................. Ul"l.I\.1"1.Vw'H'i Comment:::................ .STS LIS Wr:-it.ing Librar:-y. Scientific Technical Sen¡iCe3 Reel Trailer Service n~mc....__.........LISTPE Da t <? . . . . . . . . . . . . . . . . . . . . 0 3 / 0:) / 2 4 Origin _ _ _ _ _ _ _ . _ . _ . _ . . . . . . STS Reel Name............... . UNKNOWN Cc>ntinl1.=¡tinn NIJmher_ _ _ _ _ .Oi Next Reel N¿)[:1e.......... .UNKN01frN Comments.................STS LIS Writing Librar:-y. Scientific Technical Services Phvsic.:::l EOF 2hysical EOr t:nd Of LIS FilE' ) ) ) ) Sperry-Sun Drilling Services LIS Scan Utility $Rev:Lsion: 3 $ LisLib $Revision: 4 $ Fri Apr 11. 12:02:25 2003 Reel Header Service name.............LISTPE Oat e. . . . . . . . . . . . . . . . . . . . . () 3 /04/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments................ ..STS LIS \il7riting Library. Scientific Techni.cal Services Tape Header Service name.. ...........LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wei.ting Libral~Y. Scient.i. f:Lc 'fechn.ical Services Physical EOF Comment Record Tl\PE HEADER Kuparuk River MWD/MAD LOGS II WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 38-14 501032043900 Conoco Phillips Alaska Inc. ~)percy Sun 11-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AKM"V\722198 E. QUAM M. THORNTON MWD RUN 2 AKMW22198 E. QUAM M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 10 . ~, 12N 8E 2519 1071 MSL 0) .00 55.90 2'/.'/0 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.290 16.000 108.0 8.500 9.625 2808.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). j. MI"¡D RUN 1 00 WAS DIRECTION1\L WITH DUAL G.AMMi\ RAY (DGR), UTILIZING GEIGER-MULLER TUBE DETECTORS. (~Oa-d/O 1/10 rej 10'¡--LÀ( ) ) 4. MWD RUNS 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MULLER TUBE DETECTORS ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD RUNS 100 - 200 REPRESENT WELL 3S-14 WITH API #50-103-20439-00. THIS WELL REACHED A TOTAL DEPTH ('I'D) OF 6895' MD, 6175' TVD. SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMM.A RAY COMBINED. SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SI-IALLOW SPACING). SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) . SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SMOOTHED FORMATION EXPOSURE TIME. SMOOTHED NEUTRON POROSITY SANDSTONE Ml\TRIX .FIXED HOLE SIZE. SMOO'rHED BULK DENSITY COMPENSA'l'ED (LOW-COUNT' BIN). SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SMOOTHED NE.AR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = SLD SENSOR DEPTH IN STEERING INTERVALS. SROP SGRC SEXP SESP SE1'1P SEDP SFXE SPSF SBD2 SC02 SNP2 ENVIRONMENTAL PARAMETERS USED FOE NUCLLEAR LOG1 PROCESSING: BOREHOLE, SIZE: MUD SALINITY: FOR1'1ATION WATER SALINITY: MUD WEIGHT: FLUID DENSITY: MATRIX DENSITY: MA'I'lUX LITHOLOGY: ,$ 8.b" 100 - 300 ppm CL- 25,000 ppm C1,- 9.4 - 12.3 ppg 1.00 g/ce 2.65 glee SANDSTONE F:L1c He,,\der Service name............ .STSLI8.001 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.. .....03/04/11 Maximum Physical Record..6S53b File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shi Hed DEPTH INCRE1'1ENT: # FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT PEF RPD RPM RPS RPX FET DRHO RHOS NPHI 1 and clipped curves; all bit runs merged. .5000 $ START DEPTH 52.5 108.5 2642.5 2642.5 2652.0 2"1 92 . tJ 2792.5 2792.5 2/92.tJ 2792.5 2808.5 2808.5 2802..5 STOP DEPTH 6862.5 6895.0 6811.0 6811.0 6820.0 6f:Jbb.ü 6855.0 6855.0 68bb.U 6855. (I 6820.0 6820.(\ 68l1.C # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIE'TED DEPTH --------- ) ) BASELINE DEPTH $ # MERGED DATA SOURCE PSU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 52.5 2820.0 MERGE BASE 2820.0 6895.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block '1'ype.....O Logginç] Direction................. . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing....... ..............60 .1IN Max frames per record.............Undefined Absent value............... ...... .-999.25 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block ,sub-type... 0 Name Service Ord(2r Un.i..ts Siz(:: Nsam RE:;p CodE:; Offset Channel DEPT 1:''1' 4 1 68 0 1 ROP MWD F'1'/H 4 1 68 4 2 GR MWD API 4 '1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD pu-s 4 1 68 32 9 PEF MWD B/E 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 NCN'1' MWD CNTS 4 1 68 44 12 RHOB MWD G/CC 4 1 68 48 13 DRHO HWD G/CC 4 1 68 5? 14 F i.r..s t Last Name Service Unit Min Max Mean Nsam Reading Read.ing DEPT FT !:)2.5 6895 3473.75 13686 52.5 6895 ROP MWD FT/H 2.7 '796.51 188.378 1304'7 108.5 6895 GR HWD API 19.69 409.39 99.9983 13621 52.5 6862.5 RPX MWD OHMM 0.28 2000 3.89446 8126 2792.5 6855 RP8 MWD OI-IMM 0.24 2000 4.05532 8126 2792.5 6855 RPM MWD OHMM 0.1 2000 4.8661 f:¡126 2792.5 6855 RPD MWD OHMM 0.32 2000 9.11868 8126 2792.5 6855 FET MWD HR 0.1497 56.4967 0.926134 8126 2792.5 6855 NPHI MWD PU-8 19.B6 81.76 49.0947 8006 2808.5 6811 PEF MWD B/E 0.39 11.57 2.95948 8083 2652 6820 FCNT MWD CNT8 406 1195 598.654 8084 2642.5 6811 NCNT MWD CNTS 2182 3599 2569.93 808'1 26'12.5 6811 RHOB ¡V¡WD G/CC 1.981 2.912 2.30282 8024 2808.5 6820 DRHO MWD G/ec -0.188 0.313 0.0390764 8024 2808.5 6820 First Reading for Entire file..........52.5 Last Reading For Entire File...........6895 File Trailer Service name........... ..8T8L1B.00l Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/04/ll Maximum Physical Record..65535 File Type............... .LO Next File Name...........8TSLIB.002 Comment Record fILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR ROP $ ) Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number........ . . .1.0.0 Date of Generation.......03/04/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name.......STSLIB.001 2 I. .5000 52..5 STOP DEPTH 2763.0 2820.0 108.5 # LOG HEADER D]\TA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA 'EYPE (MEMORY OR REAL-TIME): TO 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 BOTTOM) VENDOR TOOL CODE TOOl., TYPE GM Dual GR $ # BOREHOLE AND CASING DAT.A OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MU 0 Cl\KE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMJ\RKS : $ Data Format S~ecification Record Da ta Record Type.................. 0 Data Specification Block Type.....O ') 19-DEC-02 Insite 4.3 Memory 2820.0 .0 33.6 TOOL NUMBER 77114 12.300 108.0 SPUD 9.40 165.0 9.4 225 6.3 .000 .000 .000 .000 .0 74.4 .0 .0 ) ) Logging Direction............. ....Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing................. ....60 .lIN Max frames per record.............Undefined Absent value......................-999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Uni.ts Size Nsam Rep Cod,e Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Mi..n Max Mean Nsatn Reading Reading DEPT FT 52.5 2820 1436.25 5536 52.5 2820 ROP MWD010 FT/H 7.31 454.56 195.201 4897 108.5 2820 GR MWD010 API 19.69 135.91 69.3549 5422 52.5 2763 First Reading For Entire File..........52.5 Last Reading For Entire Fi1e...........2820 F.ile Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... ..1.0.0 Date of Generation.......03/04/11 Maximum Physical Record..65535 file Type................ LO Next File Name.. .........ST8LIB.003 Physical EOr File Header Service name.... ........ .8TSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/04/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS fET tCNT RPM PEF NCNT RPD RPX NPHI DRHO RHOS ROP 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2763.5 2792.5 2792.5 2792.5 2792.5 2792.5 2792.5 2792.5 2792.5 2808.5 2808.5 2808.5 2820.5 $ LOG HEfl.DER D.J:\.TA STOP DEPTH 6862.5 6855.0 6855.0 6811.0 62.55.0 6820.0 6811.0 6855.0 6855. C' 6811.0 6820.0 6820.0 6895.0 ) DATE LOGGED: SOFTWARE SURFACE SOFTW1.l"RE VERSION: DOWNHOLE SOF'I'WARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MÞv'UMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COM.PENSATED NEU'I'.RON STABILIZED LITHO DEN # BOREHOLE J.\ND CASING DJ:\'I'A OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD rry PE : MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MI.l"X CIRC1.JL1\TING TEF\MPEF\A.'I'URE: MUD FILTRATE AT MT: MU D CAKE AT' MT': NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: .$ # Data Format Specification Record Data Record Type.... .... ........ ..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 Absent value...................... -999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 23-DEC-02 Insite 0.43 Memory 6895.0 22.8 30.7 TOOL NUMBER 142827 121079 119007 39307 8.500 2808.0 LSND 12.30 55.0 8.0 100 7.9 3.600 1.90'1 3.000 4.500 68.0 13'1.6 68.0 68.0 Name Serv.ice Order Units Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO 0 FT!H 4 1 62- 4 - GR MWDO 0 API 1 68 0 3 u RPX tv¡WDO 0 OHMM 1 68 12 4 RrS Mh'DO 0 o Hf\1.M 1 68 16 5 RPM MWDO 0 OHMM 4 1 68 20 6 RPD M~~DO 0 OHMM 4 1 68 24 7 FET Mli<JDO 0 HR 4 1 68 28 2. NPHI ~~DO 0 PU-S 4 1 68 32 ~; PEF MWDO 0 BIE 4 1 68 36 10 !:CNT HWDO 0 CNTS "I 1 68 '10 11 NCNT MWDO 0 CNTS 4 1 68 44 12 RHOB HWDO 0 G/CC 4 1 68 48 13 ') ) DRHO rvIWD020 GlCC 4 1 6U c:;n JL 14 Flr.'¡:;t La,st Name Service Unit rvlin Max Mean Nsam Readin<] Reading DEPT FT 2763.5 6895 4829.25 8264 2763.5 6895 ROP MWD020 FT/H 2.7 796.51 184.278 8150 2820.5 6895 GR Mì^lD020 J-\PI 42.31 409.39 120.263 8199 2763.5 6862.5 RPX MWD020 OHMM 0.28 2000 3.89446 8126 2792.5 6855 RPS MWD020 OHMM. 0.24 2000 4.05532 8126 27 92.5 6855 RPM MWD020 OHMM 0.1 2000 4.8661 8126 2792.5 6855 ¡:;>J?D M\~D020 OHMM 0.32 2000 9.11868 8126 2792.5 6855 FET MWD020 HR O. 14 97 56.4967 0.926134 8126 2792.5 6855 NPHI MWD020 pu-s 19. êJ6 81..76 49.0947 8006 n08.5 6811 PEF MWD020 B/E 0.31 11.57 2.93278 8056 27 92 . 5 6820 FCNT MWD020 CNTS 406 119~j 599.48 8038 2792.5 6811 NCNT MWD020 CN'I'S 2182 3599 2570.84 8038 2792.5 6811 RHOB MWD020 GICC 1.981 2.912 2.30282 8024 2808.5 6820 DRHO MWD020 (3/ CC -0.188 0.313 0.0390764 8024 2808.5 6820 First Reading For Entire File..........2763.5 Last Reading For Entire File...........6895 File Trailer Service name........ .....STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/04/11 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOE' Tape Trailer ,Service name............ .LI3TPE Date.....................03/04/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNI-CNOWN Continuation Number...... 01 Next Tape Name...........UNKNOWN Comments............ .....3'1'8 LIS Writin(,J Lihr.ary. Scientific Technical Services Reel Trailer Service name........___..LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 031 04/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... .... ........UNKNOWN Continuation Number......Ol Next Reel Name.. ........ . UNKNOWN Comments.. ...............STS LIS W~iting Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS file