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Home My WebLink About203-088 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-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_06Aug2023 203088_3S-06_Perf_29Aug23 203088_3S-06_USIT DSLT_13Sep2022 203088_3S-06_USITDSLT_16Nov2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:17:36 -09'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 9-5/8" L-80 2606' 7" L-80 6133' 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 8569' SIZE DEPTH SET (MD) 42.4' 62.5# 40# 108' 42.4' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 73 bbls 15.8 ppg Class G cement (perf wash) 5570-5720' 68.5 bbls 15.8 ppg Cement (perf wash) Surf-5570' 231 bbls15.8 ppg Type I-II Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 5390-5540' 5560-5749' Plugged and Abandoned 8252-8282' MD and 5870-5895' TVD (Cemented) Gas-Oil Ratio:Choke Size: 8.7 bbls 15.8 ppg Class G Cement Per 20 AAC 25.283 (i)(2) attach electronic information 7911' MD/5596' TVD PACKER SET (MD/TVD) 42" 12-1/4" 66 sx ArcticCrete 42.4'510 sx AS Lite, 300 sx LiteCrete 42.4' 3072'42.4' 42.4' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE CEMENTING RECORD 5998960 SETTING DEPTH TVD 5999137 TOP HOLE SIZE AMOUNT PULLED 476103 476138 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 1565' MD/ 1548' TVD N/A 2483' FNL, 915' FEL, Sec. 18, T12N, R8E, UM 2558' FNL, 1119' FEL, Sec. 7, T12N, R8E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476344 5993933 2544' FSL, 1154' FEL, Sec. 7, T12N, R8E, UM Surface/Surface 8579' MD/ 6142' TVD ADL0380106, ADL0380107 ALK 4623 50-103-20454-01-00 KRU 3S-06A May 25, 2003 May 15, 2003 9. Ref Elevations: KB: 28' Kuparuk River Field/ Kuparuk River Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/16/2023 203-088/ 322-430 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 300 sx Class G w/ GasBlok7" 7943' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 1:30 pm, Nov 15, 2023 Abandoned 10/16/2023 JSB RBDMS JSB 111723 xGDSR-11/22/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1565' 1548' 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: Dusty Ward Digital Signature with Date:Contact Email:dusty.ward@conocophillips.com Contact Phone:(907) 265-6531 Staff Workover 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 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: EL CORRECTED TAG 5,562.0 3S-06A 8/27/2023 condijw Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Final P&A - added marker Plate and trimmed casing 3S-06A 11/7/2023 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: AOGCC Inpsector Guy Cook Witnessed the Marker Plate information and weld 10/15/2023 bsgreen NOTE: Well Stub ~ 8' 10" below OG (tundra) 10/14/2023 bsgreen NOTE: PUMP 231 BBL OF 15.8 PPG CEMENT TO CTU LAYING IN CEMENT IN 7" PC TO SURFACE 9/30/2023 bsgreen NOTE: Waivered for Water-Only Injection due to TxIA on gas 11/16/2017 pproven 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 42.4 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 42.4 3,071.7 2,606.5 40.00 L-80 BTC PRODUCTION 7 6.28 42.4 8,568.6 6,133.4 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 7,841.0 Set Depth … 7,943.2 Set Depth … 5,621.4 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,856.8 5,553.5 38.54 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 7,894.6 5,583.1 38.21 SEAL ASSY 4.500 LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 2.992 7,896.6 5,584.7 38.19 PBR 5.890 BAKER 80-40 PBR BAKER 80-40 2.990 7,910.3 5,595.5 38.07 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.992 7,911.2 5,596.2 38.06 PACKER 5.960 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,916.1 5,600.1 38.02 MILL 3.500 80-40 MILL OUT EXTENSION 80-40 2.992 7,935.2 5,615.1 37.82 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 7,942.3 5,620.7 37.75 WLEG 5.000 WLEG w/ SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 42.4 42.4 0.34 MARKER PLATE Marker Plate 10/14/2023 0.000 5,749.0 4,149.4 55.37 CIBP AK EL (LEGACY) CIBP MID- ELEMENT AT 5750' RKB, OAL 2' LEGACY 000- 5610- 002 9/24/2022 0.000 7,841.0 5,541.2 38.68 CUT WELLTEC MECHANICAL TUBING CUT AT 7841' RKB 9/1/2022 2.992 7,932.0 5,612.6 37.86 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/30/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,390.0 5,414.0 3,943.5 3,957.4 8/29/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,416.0 5,456.0 3,958.5 3,981.7 8/28/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,458.0 5,498.0 3,982.9 4,006.1 8/28/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,500.0 5,540.0 4,007.3 4,030.4 8/28/2023 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,570.0 5,720.0 4,047.6 4,132.9 10/1/2022 21.0 APERF 4.72" HSD, PowerFLow 4621, RDX (19g, 21 spf, 60° PHASE, API: 5.9 PEN, 0.83" EH). (10/4/22) 8,252.0 8,282.0 5,870.5 5,895.1 UNIT D, 3S-06A 5/25/2003 6.0 IPERF 2.5" HSD PJ Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,943.2 8,382.0 5,621.4 5,977.4 Cement Plug 7/30/2022 7,933.0 7,943.3 5,613.4 5,621.5 Cement Plug 7/30/2022 42.4 3,071.7 42.4 2,606.5 Cement Plug Pumped 108 BBLS of 15.8 PPG Permafrost Cement down the 7" x 9 5/8" annulus - Changed top was 34.0 11/5/2022 5,570.0 5,720.0 4,047.6 4,132.9 Plug – Perf- Wash-Cement PUMP 68.5 BBLS OF 15.8 PPG CEMENT THROUGH HYDRAWELL TOOL 11/20/2023 5,560.0 5,749.0 4,041.8 4,149.4 Cement Plug LAY IN 8.7 BBL, 15.8 PPG, CLASS G 8/2/2023 5,390.0 5,540.0 3,943.5 4,030.4 Plug – Perf- Wash-Cement 73 BBLS, 15.8 PPG, CLASS G 9/4/2023 42.4 5,570.0 42.4 4,047.6 Plug – Plug Back / Abandonment Plug LAY IN 231 BBLS,15.8 PPG, TYPE I-II, CEMENT 7"PROD CSG TO SURFACE - Changed for P&A - was 35.1 9/30/2023 3S-06A, 11/9/2023 1:05:02 PM Vertical schematic (actual) PRODUCTION; 42.4-8,568.6 IPERF; 8,252.0-8,282.0 Cement Plug; 7,943.2 ftKB Cement Plug; 7,933.0 ftKB CEMENT RETAINER; 7,932.0 PACKER; 7,911.2 CUT; 7,841.0 CIBP; 5,749.0 APERF; 5,570.0-5,720.0 Plug – Perf-Wash-Cement; 5,570.0 ftKB Cement Plug; 5,560.0 ftKB APERF; 5,500.0-5,540.0 APERF; 5,458.0-5,498.0 Plug – Perf-Wash-Cement; 5,390.0 ftKB APERF; 5,416.0-5,456.0 APERF; 5,390.0-5,414.0 SURFACE; 42.4-3,071.7 CONDUCTOR; 42.4-108.0 MARKER PLATE; 42.4 Plug – Plug Back / Abandonment Plug; 42.4 ftKB Cement Plug; 42.4 ftKB KUP INJ KB-Grd (ft) 33.60 RR Date 5/12/2003 Other Elev… 3S-06A ... TD Act Btm (ftKB) 8,907.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045401 Wellbore Status INJ Max Angle & MD Incl (°) 56.78 MD (ftKB) 3,116.73 WELLNAME WELLBORE3S-06A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-06A Plug and Abandonment November 6, 2023 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-06A, commencing operations on September 1, 2022 and completing the Plug and Abandonment on October 16, 2023. After successful suspension of the Kuparuk formation, tubing was cut at 7,841ft KB, and rig operations performed to remove tubing from cut depth to surface. After the rig moved off, a bond log was run to determine top of cement in the 7” x OH annulus and to establish intervals for Perf/Wash/Cement operations. A CIBP was set at 5,749ft KB, the production casing was perforated from 5,570ft to 5,720ft 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. Due to excessive fill and incomplete/inconclusive logging results, it was decided to perform a second Perf/Wash/Cement operation uphole, from 5,390ft to 5,540ft KB. After the second Perf/Wash/Cement operation, cement in the production casing was milled to 5,570ft KB and a bond log run to validate that adequate cement had been placed in the 7” x OH annulus. The well was then cemented to surface inside both the 7” production casing and 7” x 9-5/8” annulus. With cement verified at surface, the well was 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. Page 1/4 3S-06 Report Printed: 11/6/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/4/2022 11:00 9/4/2022 19:00 8.00 MIRU, MOVE MOB P Warm Up Cold Start Motor's - B/D - R/D Pipe Shed - Unplug Sub/Pits Interconnect - Move Pits/Motors Back From Sub Base - Move Sub Base off 3S -21 And Down Pad To 3S-06 SimOps - Move Rig Mats And 3" x 12" Where Needed For Sub Base And Pits/Motors Taking The Time To Show All Crew Members How To do It. Then Moving On To The Next Step 0.0 0.0 9/4/2022 19:00 9/4/2022 20:00 1.00 MIRU, MOVE MOB P Spot Sub Base Over 3S-06 - Lower Stompers - Skid Floor Into Postion 0.0 0.0 9/4/2022 20:00 9/5/2022 00:00 4.00 MIRU, MOVE MOB P Move Pits/Motors F/3S-21 T/3S-06 0.0 0.0 9/5/2022 00:00 9/5/2022 06:00 6.00 MIRU, MOVE MOB P Spot Pits/Motors Up To Sub Base - M/U Service Lines - Spot Pipe Shed - Work On Rig Acceptance Checklist 0.0 0.0 9/5/2022 06:00 9/5/2022 10:00 4.00 MIRU, MOVE MOB P Work On Rig Acceptance Checklist - Get RKB's SimOps - Spot Rock Washer And Cuttings Tank - Bring On Seawater To Pits @ 10:45 HRS SimOps - Set Up Diverter Valve ,Annular And Tee For 3S-625 Rig Accepted @ 10:00 HRS 0.0 0.0 9/5/2022 10:00 9/5/2022 12:00 2.00 MIRU, WELCTL CIRC P R/U To Circ Seawater DN TBG - Returns Out IA - Cont Bring On Seawater 0.0 0.0 9/5/2022 12:00 9/5/2022 17:00 5.00 MIRU, WELCTL CIRC P Rig Up Test Lines T/2500 PSI F/5 Min - Test CSG T/2500 PSI F/15 Min - Trouble Shoot Circ Line Up - SSSV Closed 0.0 0.0 9/5/2022 17:00 9/5/2022 19:30 2.50 MIRU, WELCTL CIRC P PJSM - Circ Seawater S/S - Pump 25 BBLS High Vis Pill - Chase W/330 BBLS Seawater - Circ @ 7 BPM 1800 PSI 0.0 0.0 9/5/2022 19:30 9/5/2022 20:30 1.00 MIRU, WHDBOP OWFF P Flow Check - B/D - R/D Lines 0.0 0.0 9/5/2022 20:30 9/5/2022 21:45 1.25 MIRU, WHDBOP SEQP P PJSM - Set BPV - Test T/1000 PSI F/10 Min In The Direction Of Flow - B/D And R/D Lines - Pump 3 1/2 BBLS Bleed Back 3 1/2 BBLS 0.0 0.0 9/5/2022 21:45 9/5/2022 23:15 1.50 MIRU, WHDBOP NUND P Demo Scafoldling - N/D Tree And Adapter Flange 0.0 0.0 9/5/2022 23:15 9/6/2022 00:00 0.75 MIRU, WHDBOP NUND P Clean And Inspect TBG Hanger - Verify Lock Down Screw Function 3 3/4" IN 4 3/4" Out - Clean Hanger Threads - Install Blanking Plug 11 1/4 Turns 0.0 0.0 9/6/2022 00:00 9/6/2022 05:00 5.00 MIRU, WHDBOP NUND P N/U BOP And 11" x 13 5/8" Adapter Flange To Well Head - Install Turn Buckles - Install Flowline - M/U Flowbox , Low PSI Bleed Off Line , Hole Fill , Mud Bucket Line - Install Trip Nipple 0.0 0.0 9/6/2022 05:00 9/6/2022 08:30 3.50 MIRU, WHDBOP BOPE P R/U Test BOP - M/U Blanking Plug X/Over T/Test JT - Grease Upper/Lower IBOP - 4" FOSV And Dart Together - Install 3 1/2" Test JT - M/U Top Drive T/Test JT SimOps - Cut 1' off Riser - Inspect Traction Motor A 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/8/2022 Page 2/4 3S-06 Report Printed: 11/6/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/6/2022 08:30 9/6/2022 09:00 0.50 MIRU, WHDBOP BOPE P Fill Stack And Choke With Water - Work Air Out - Shell Test T/3000 PSI F/5 Min - Good Test 0.0 0.0 9/6/2022 09:00 9/6/2022 13:30 4.50 MIRU, WHDBOP BOPE P Test BOP W/ 3 1/2" Test JT - All Test 5 MIn each @ 250/2500 PSI - Test The Following Annular , Upper VBR 3 1/2" x 6" , Blind Rams , Lower VBR 3 1/2" x 6" , Test Choke Valves 1-14 , HCR Kill/Choke , Manual Kill/Choke , Auto/Manual IBOP's , XT-39 FOSV/Dart Valve , 4" Demco Kill Line Valve , Neddle Valve On Choke Manifold , Draw Down Test On Super/Manual Chokes T/1500 PSI Koomey Drawdown Test ISP = 3000 PSI ISP After Function = 1400 PSI 200 PSI = 18 SEC Full PSI = 170 SEC 4 Nitrogin Bottles = 2368 PSI AVG Bottle Pre-Charge = 1050 Closing Times BAG = 18 SEC UPR = 7 SEC Blinds = 13 SEC LPR = 7 SEC HCR Kill/Choke = 1 Sec each Test Gas Alarms AOGCC - Brian Bixby Waived Witness Of BOP Test 9-4-22 @ 13:24 HRS 0.0 0.0 9/6/2022 13:30 9/6/2022 15:00 1.50 MIRU, WHDBOP BOPE P R/D BOP Testing Equipment - Clear Rig Floor 0.0 0.0 9/6/2022 15:00 9/6/2022 17:45 2.75 COMPZN, RPCOMP SEQP P Pull Blanking Plug - B/D Choke/Kill Lines 0.0 0.0 9/6/2022 17:45 9/6/2022 18:45 1.00 COMPZN, RPCOMP SEQP P Pull BPV 0.0 0.0 9/6/2022 18:45 9/6/2022 19:00 0.25 COMPZN, RPCOMP PULL P P/U 3 1/2" EUE Landing JT - Make Up T/Hanger 12 Turns 0.0 0.0 9/6/2022 19:00 9/6/2022 19:45 0.75 COMPZN, RPCOMP PULL P M/U X/Overs To Landing JT - Make Up Top Drive - BOLDS 0.0 0.0 9/6/2022 19:45 9/6/2022 20:15 0.50 COMPZN, RPCOMP PULL P Pull Hanger Off Seat @ 120K - Break Over WT - 130K - Clean Up WT 120K - Flow Ckeck 15 Min Static - Land Hanger Back On Seat 0.0 0.0 9/6/2022 20:15 9/6/2022 20:30 0.25 COMPZN, RPCOMP PULL P Break Off Cross Overs From Top Drive And Landing JT 0.0 0.0 9/6/2022 20:30 9/6/2022 20:45 0.25 COMPZN, RPCOMP PULL P Pick Hanger Up Off Seat = 120K UP Drain Stack - Pull HAnger T/Floor 7,841.0 7,810.0 9/6/2022 20:45 9/6/2022 21:15 0.50 COMPZN, RPCOMP PULL P Lay DN Hanger and Pup JT 7,810.0 7,810.0 9/6/2022 21:15 9/7/2022 00:00 2.75 COMPZN, RPCOMP PULL P POOH - L/D 3 1/2" TBG To Pipe Shed F/7810' T/5917' 7,810.0 5,917.0 9/7/2022 00:00 9/7/2022 04:15 4.25 COMPZN, RPCOMP PULL P POOH W/3 1/2" Tubing Lay DownTo Pipe Shed F/5917' T/2124' - 73K UP 5,917.0 2,124.0 Rig: DOYON 19 RIG RELEASE DATE 9/8/2022 Page 3/4 3S-06 Report Printed: 11/6/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/7/2022 04:15 9/7/2022 09:30 5.25 COMPZN, RPCOMP FRZP P Rig Up T/ Freeze Protect Well Wait On Little Red Oil Field Services SimOps - Monitor Well On Trip Tank No Loss No Gain - Test Run Top Drive Cable Guard For Modifying - Clean And Clear Rig Floor - Install Sensor And Wires For SLBG On Stand Pipe - Adjust Brakes On Draw Works 2,124.0 2,124.0 9/7/2022 09:30 9/7/2022 10:30 1.00 COMPZN, RPCOMP FRZP P PJSM - For Freeze Protect Well - Little Red Test Lines To 2500 PSI - Little Red Pump 75 BBLS Down The Inner Annulus - Take Returns Up The Tubing To The Open Top Tank - Pump @ 2 BPM ICP 400 PSI - FCP 340 PSI - 75 BBLS Pumped 75 BBLS Returned 2,124.0 2,124.0 9/7/2022 10:30 9/7/2022 11:15 0.75 COMPZN, RPCOMP FRZP P U-Tube Tubing And The Inner Annulus - ISP 35 PSI FSP - 0 PSI - Open Up To The Open Top Tank And Verify No Flow 2,124.0 2,124.0 9/7/2022 11:15 9/7/2022 12:00 0.75 COMPZN, RPCOMP FRZP P Blow Down And Rig Down All Lines For Freeze Protect 2,124.0 2,124.0 9/7/2022 12:00 9/7/2022 15:00 3.00 COMPZN, RPCOMP PULL P PJSM - POOH From 2124' To Surface - Laying Down Tubing To The Pipe Shed Lay Down A Total Of 249 Joints Of 3 1/2" EUE Tubing - Gas Lift Mandrel And Pup Joints - DS Nipple - Hanger And The Pup Joint Under It - 8 Foot Space Out Pup Joint- Cut Joint Laid Down = 13.11' - Leaving The Tubing Stump @ 7,841' From 7ES RKB Depth 2,124.0 0.0 9/7/2022 15:00 9/7/2022 16:30 1.50 COMPZN, RPCOMP FRZP P PJSM - Rig Up To Fill The hole With Little Red - Little Red Test Lines T/2500 PSI - Fill The Hole With Diesel With Little Red - Pump 7 BBLS Into The Annulus To Fill Hole - Suck Back .3 BBLS Little Red Pump A Total Of 81.7 BBLS Down Hole SimOps - Rig Down Casing Equipment - Assist SLBG With Sensors And Wires On The Goose Neck On The Stand Pipe In The Derrick 0.0 0.0 9/7/2022 16:30 9/7/2022 17:30 1.00 COMPZN, RPCOMP FRZP P Rig Down Little Red And Circulating Lines - Clean And Clear Rig Floor And Cellar Area 0.0 0.0 9/7/2022 17:30 9/7/2022 19:30 2.00 COMPZN, WHDBOP NUND P PJSM - Blow Down All Surface Lines - The Choke And The Kill Line On The Stack - Mud Pump Line , Bleeder Line's And The Hole Fill Line - Pull The Riser To The Rig Floor 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/8/2022 Page 4/4 3S-06 Report Printed: 11/6/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/7/2022 19:30 9/8/2022 00:00 4.50 COMPZN, WHDBOP OTHR P PJSM - Perform CPAI Between The Well Maintenance On The BOP's - Inspect The Annular Preventer Element , Open Upper 3 1/2" x 6" VBR - Blind Rams - Inspect Ram Body , Rubber Elements , Wear Plates , Cavities And Door Seals SimOps - Clean Pits Of Fluids - Drain Pumps And Clean Sumps - Blow Down Water To Rig Floor - Start Unhooking Service Lines Between The Pits And The Sub Base Also Unhook Lines Between The Mezzanine And The Rig Floor 0.0 0.0 9/8/2022 00:00 9/8/2022 03:00 3.00 COMPZN, WHDBOP OTHR P PJSM - Continue To Perform CPAI Between The Well Maintenance On The BOP's - Lower 3 1/2" x 6" VBR - Inspect Ram Body , Rubber Elements , Wear Plates , Cavities And Door Seals - Close Rams Doors And Tighten Up The Ram Door Bolts - Pick Up Work Area SimOps - Prep Rock Washer , Pits And Motors Complex's For Moving To 3S- 625 0.0 0.0 9/8/2022 03:00 9/8/2022 06:00 3.00 COMPZN, WHDBOP NUND P PJSM On Nipple Down The BOP's - Remove Flow Line From The Flow Box - Remove Flow Box And Set Down In The Cellar - Break The BOP's At The 13 5/8" Spacer Spool - Break The11" x 13 5/8" Adaptor Spool Off The Well Head And Set Aside In The Cellar - Stand Back The BOP's On The BOP Stand And Secure 0.0 0.0 9/8/2022 06:00 9/8/2022 07:15 1.25 COMPZN, WHDBOP NUND P Nipple Up The 7 1/16" Dry Hole Tree 0.0 0.0 9/8/2022 07:15 9/8/2022 07:45 0.50 COMPZN, WHDBOP DHEQ P PJSM - Rig Up Little Red Fill Dry Hole Tree With Diesel 0.0 0.0 9/8/2022 07:45 9/8/2022 08:45 1.00 COMPZN, WHDBOP DHEQ P PJSM - Test The Dry Hole Tree To 2500 PSI With Little Red For 30 Min - Pumped 3.5 BBLS Bleed Back 3.5 BBLS 0.0 0.0 9/8/2022 08:45 9/8/2022 10:00 1.25 DEMOB, MOVE DMOB P Rig Down Little Red - Secure Well - Clean Tree , Cellar area - Blow Down The Steam On The Sub Base - Prep To Move To 3S-625 Rig Release @ 10 AM Off HighLine @ 9:30 AM Zero PSI On The 7" Casing 0.0 0.0 Rig: DOYON 19 RIG RELEASE DATE 9/8/2022 DTTMSTART JOBTYP SUMMARYOPS 4/29/2022 SUPPORT OTHER OPERATIONS DRIFT TBG W/ 2.75" DMY CA2 PLUG TO 7935' RKB, PERFORM INJECTIVITY TEST DOWN TBG UP TO 3 BPM @ 2250 PSI. PERFORM INJECTIVITY TEST DOWN OA UP TO 1.25 BPM @ 1175 PSI. (SEE ATTACHMENTS FOR PUMP REPORT) READY FOR CTU PENDING WELL INTERVENTIONS ENGINEER REVIEW. 7/30/2022 SUPPORT OTHER OPERATIONS FUNCTION TEST BOPS SET RETAINER @ 7932' PUMPED 28 BBLS OF 15.8 PPG CEMENT PUMPED 27 BBLS BELOW RETAINER & 1 BBL ON TOP DRESS CEMENT TOP OFF 7817' POOH 8/5/2022 SUPPORT OTHER OPERATIONS DRIFT TBG W/ 2.75" CENT & SAMPLE BAILER, TAG TOC @ 7928' SLM, RECOVER CEMENT IN SAMPLE BAILER, NOTE TIGHT SPOT @ 7825' SLM, PERFORM PASSING MITT TO 1500 PSI. PERFORM PASSING DDT- T. IN PROGRESS 8/11/2022 SUPPORT OTHER OPERATIONS (P&A PREP) FUNCTION TEST T & IC LDS/GNS (COMPLETE), T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED) 8/12/2022 SUPPORT OTHER OPERATIONS STATE WITNESS DRIFT TBG W/ 2.25" CENT @ SAMPLE BAILER, TAG TOC @ 7933' SLM, RECOVER CEMENT IN SAMPLE BAILER,LRS TO MITT & CMIT WELL, (PASSED) JOB COMPLETE 8/13/2022 SUPPORT OTHER OPERATIONS PULLED DV @ 7812' RKB. CMIT TxIA TO 2500 PSI (PASS) 9/1/2022 SUPPORT OTHER OPERATIONS CUT 3-1/2" TUBING WITH WELLTEC MECHANICAL CUTTER AT 7841'. CCL TO CUTTER = 18.04', CCL STOP DEPTH = 7822.96'. GOOD INDICATION OF CUT (TATTLE TAIL INDICATED 3.651" BLADE OD ONCE AT SURFACE). JOB IS READY FOR VALVE CREW TO SET H-BPV. 9/4/2022 RECOMPLETIO N N/D Riser And Lines - N/D BOP - Rack Back - M/U Tree Test T/2500 PSI - Move Rig T/3S-06 9/5/2022 RECOMPLETIO N Finish Rig Acceptance Checklist - Circ Seawater - Set BPV - N/D Tree - Install Blanking Plug 9/6/2022 RECOMPLETIO N N/U BOP And Lines - Test BOP - Pull Blanking Plug - Pull BPV - Unseat Hanger - POOH L/D 3 1/2" TBG 9/7/2022 RECOMPLETIO N Pull Out Of The Hole With 3 1/2" Tubing To 2,124' - Freeze Protect The 7" Casing With 75 BBLS Of Diesel - Pull Out Of The Hole With 3 1/2" Tubing To Surface - Fill Hole With 6.7 BBLS Of Diesel - Perform Between The Well Maintenance On The BOP Stack 9/8/2022 RECOMPLETIO N Finish CPAI Between The Well Maintenance On The BOP Stack - Nipple Down The BOP Stack And Rack Back On The BOP Stand - Nipple Up The 7 1/16" Dry Hole Tree - Fill The Tree With Diesel And Test Tree Along With The 7" Casing To 2500 PSI - Prep The Rig And The 3S-625 Cellar Area To Move The Rig To 3S-625 9/13/2022 SUPPORT OTHER OPERATIONS DRIFT 7" CASING WITH JUNK BASKET AND 5.96" GAUGE RING TO TUBING STUB AT 7835'. PERFORM CEMENT EVALUATION LOG WITH USIT/DSLT FROM 7820' TO 5350'. CONFIRM GOOD DATA AND UPLOAD DATA FOR RUSH PROCESSING. JOB COMPLETE. 9/24/2022 SUPPORT OTHER OPERATIONS SET 7" AK E-LINE (LEGACY) CIBP AT 5750.0' RKB (MID-ELEMENT), CCL TO MID-ELEMENT= 13.0', CCL STOP DEPTH = 5737.0' RKB, CORRELATED TO USIT LOG DATED 09/13/2022 JOB COMPLETE, READY FOR CASING PERFORATIONS 9/29/2022 SUPPORT OTHER OPERATIONS SLB ELINE PREPARED 150' FT OF PERFORATION ACROSS COYOTE FORMATION (5570' TO 5720') ON 7" CASING WITH 4.72" HSD POWERFLOW RDX SPOT EQUIPMENT 9/30/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 29-SEP-2022*** . GUN 1 PERFORATED INTERVAL = 5700'-5720', CCL TO TOP SHOT = 7.17', CCL STOP DEPTH = 5692.83' GUN 2 PERFORATED INTERVAL = 5680'-5700', CCL TO TOP SHOT = 7.48', CCL STOP DEPTH = 5672.5' GUN 3 PERFORATED INTERVAL = 5660'-5680', CCL TO TOP SHOT = 7.58', CCL STOP DEPTH = 5652.42' ***JOB IN PROGRESS*** 3S-06A Plug and Abandon Summary of Operations 10/1/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 30-SEP-2022*** . GUN 4 PERFORATED INTERVAL = 5640'-5660', CCL TO TOP SHOT = 7.125', CCL STOP DEPTH = 5632.88' GUN 5 PERFORATED INTERVAL = 5620'-5640', CCL TO TOP SHOT = 7.25', CCL STOP DEPTH = 5612.75' GUN 6 PERFORATED INTERVAL = 5600'-5620', CCL TO TOP SHOT = 7.33', CCL STOP DEPTH = 5592.66' ***JOB IN PROGRESS*** 10/4/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 01-OCT-2022*** . GUN 7 PERFORATED INTERVAL = 5580'-5600', CCL TO TOP SHOT = 7.27', CCL STOP DEPTH = 5572.73' GUN 8 PERFORATED INTERVAL = 5570'-5580', CCL TO TOP SHOT = 7.35', CCL STOP DEPTH = 5562.65' JOB IS READY FOR SL DRIFT (JUNK BASKET) 10/6/2022 SUPPORT OTHER OPERATIONS TAGGED CIBP W/ 3.78" CENTRALIZER & 3" DRIVE DOWN BAILER @ 5,749' RKB. RECOVERED MUD LIKE MATERIAL IN BAILER. 10/23/2022 SUPPORT OTHER OPERATIONS PERFORM (PRE OA CEMENT SQUEEZE) CEMENT BOND LOG OF THE 7" x 9-5/8" CSG FROM 3500' TO SURFACE. DATA SENT TO TOWN FOR INTERPRETATION. JOB COMPLETE. 11/2/2022 SUPPORT OTHER OPERATIONS INJECTIVITY TEST PUMP 35 BBLS DSL DWN OA TO ESTABLISH INJECTION PRESSURE @ 1, 1.25, & 1.5 BPM GOOD INJECTION @ APPROX 1000PSI & FALLING EACH STAGE 11/5/2022 SUPPORT OTHER OPERATIONS RIG UP HALLIBURTON CEMENT VAN. PUMP 5 BBL FW SPACER DOWN OA. PUMP A TOTAL OF 108 BBLS OF 15.8 PPG PERMAFROST CEMENT DOWN OA. SHUT DOWN PUMP. OA PRESSURE DROPPED TO 0 PSI. FLUSH LINES. WAIT 72 HOURS AND READY FOR E-LINE. 11/13/2022 SUPPORT OTHER OPERATIONS INJECTIVITY TEST DWN WELL BORE (NO TBG STRING) 2.7BBLS DSL TOTAL INJECTED DWN WELL, JOB POSTPONED DUE TO LOW INJECTIVITY 11/14/2022 SUPPORT OTHER OPERATIONS DRIFT CASING WITH 5.80" GAUGE RING/JUNK BASKET *** JOB IN PROGRESS *** 11/15/2022 SUPPORT OTHER OPERATIONS ***JOB CONTINUED FROM 11-14-2022*** TAG WITH DRIFT/5.80" GAUGE RING/JUNK BASKET AT 5698' LOG IBC/DSLT PERFORM PASS FROM 3500-SURFACE WITH NO SURFACE INDUCED PRESSURE PERFORM PASS FROM 3500-SURFACE, 1000PSI PRESSURE PASS *** JOB IN PROGRESS *** 11/16/2022 SUPPORT OTHER OPERATIONS *** JOB CONTINUED FROM 11-15-2022*** ATTEMPT TO LOG LOWER LOGGING SECTION FROM 5700'-5300', UNABLE TO KEEP IBC SUB ROTATING FOR LOG, SUSPECT DEBRIS DOWNHOLE CAUSING SUB TO STALL OUT, LOG CBL OVER INTERVAL 5675'- 5300' JOB COMPLETE, READY FOR CTU 11/18/2022 SUPPORT OTHER OPERATIONS WEEKLY BOP TEST. PERFORM BIAS TEST ON MICROMOTIONS. RIH WITH MOTOR AND 6.0" MILL. DRY TAG CIBP AT 5,739' CTMD (5,749' RKB). PICK UP 30' AND PAINT FLAG. END OF PIPE AT FLAG IS 5,693.5' RKB. RIH TO FLAG WITH PERF WASH/ CEMENT BHA. CORRECT DEPTH AT FLAG TO 5,710' RKB. PUMP SEAWATER AT 3.5 BPM. MAKE 5 FPM PERF WASH PASS UP. PUMP POWERVIS GEL SWEEP WITH TOOLS ABOVE PERFS. MAKE 1 FPM PERF WASH DOWN PASS.MADE WASH PASS UP @ 2 FPM & DOWN @ 1 FPM TAG PUH 1 ' PUMP 5/8" BALL LANDED BALL @ 19.8 BBLS TOOL SHIFTED @ 1800 PSI 11/20/2022 SUPPORT OTHER OPERATIONS PUMP 68.5 BBLS OF 15.8 PPG CEMENT PUMPING AT 1.6 BPM @ 2000 PSI PULLING AT 10 FPM IN THE SUMP AND 4.2 FPM FROM 5720' BOTTOM PERF'S ACROSS PERF'S TO TOP PERF'S AT 5570' CLEAN OUT TO 5420'. CHASE EXCESS CEMENT TO SURFACE. WASH ACROSS TREE VALVES AND BOPS. CEMENT WILL BE READY IN 48 HOURS FOR TAG AND TEST. 11/24/2022 SUPPORT OTHER OPERATIONS STATE WITNESS (CAM STJOHN) TAG & TEST: TAG TOP OF CEMENT @ 5459' RKB. PERFORM PASSING MIT ON THE 7" PRODUCTION CSG TO 1700 PSI. READY FOR COIL 11/26/2022 SUPPORT OTHER OPERATIONS MIRU. BOP TEST AND MU LUBRICATOR STACK AND TOOLS. DIESEL LEAK & SPILL DURING LUBRICATOR/WHA PRESSURE TEST. NOTIFY ALL PARTIES AS REQUIRED. STAND BACK FROM WELL. REPLACE CUT LUBRICATOR O-RING. BACK TO WELL.. STARTED MILLING FROM 5459' AND CURRENTLY AT 5625' PUMPING @ 3 BPM CIRC PRESSURE @ 1570 .PUMPING GEL SWEEPS EVERY 50' ****JOB IN PROGRESS**** 11/27/2022 SUPPORT OTHER OPERATIONS CONTINUE MILLING W/ 6" MILL TO 5739' CTMD (5749' RKB). POOH. RBIH W/ 6-1/4" UNDERREAMER TO 5449'. UNDERREAM 5449' - 5747' CTMD (5749' RKB) @ 2.50 - 3.0 FPM PUMPING SSW & GEL SWEEPS @ 3.0 BPM. PUMP 5/8" BALL TO SHIFT CIRC SUB & POOH @ 80% CIRCULATING 15 BBL GEL SWEEP TO SURFACE. FREEZE PROTECT COIL & WELL FROM 3000' W/ 150 BBL S. DIESEL. BLOW DOWN REEL W/ N2 & RDMO TO DEADHORSE FOR SPOOLING OPERATIONS. ****JOB IN PROGRESS - READY FOR SLU***** 12/1/2022 SUPPORT OTHER OPERATIONS STATE WITNESS TAG & TEST: TAG @ 5604' SLM,(BTM OF SQUEEZED PERFS 5720') OBTAINED SAMPLE OF MILLED UP CEMENT. CONSULT WITH TOWN, COIL NEEDED FOR CLEAN OUT. 12/4/2022 SUPPORT OTHER OPERATIONS TAG FILL/CEMENT @ 5637' CTMD, CLEANOUT DOWN TO CIBP @ 5750' RKB PUMPING HIGH VIS GEL SWEEPS. CHASE TO SURFACE. LET SETTLE FOR 1 HR. RBIH AND RE TAG CIBP AT 5750' RKB. WELL READY FOR SLICKLINE. 12/8/2022 SUPPORT OTHER OPERATIONS TAG SOFT CEMENT @ 5736' RKB (BTM PERF @ 5720' RKB); ATTEMPT TO PT AND ABLE TO PUMP 1 BPM @ 1200 PSI. CONSULT W/ TOWN ENGINEER AND LINE UP TO BE STATE WITNESS TAGGED. 12/10/2022 SUPPORT OTHER OPERATIONS STATE WITNESS TAG (ADAM EARL): TAG CEMENT @ 5654' RKB 82' HIGHER THAN PRE-TAG ON 12/8 (BTM PERF @ 5720' RKB; PERFORM INJECTIVITY TEST @ 1 BPM @ 1160 PSI. JOB SUSPENDED FOR PLAN FORWARD. 6/6/2023 SUPPORT OTHER OPERATIONS TRAVEL FROM DEADHORSE TO 3S-06 MIRU, PUMP A 1.375" DRIFT BALL, COMPLETED BOP TEST, PERFORMED FILL CLEANOUT FROM 5637' CTMD TO HARD TAG AT 5750' CIBP, PUMPING SLICK SEAWATER AND POWER-VIS SWEEPS AT 3.1 BPM WHILE MAINTAINING 1:1 RETURNS THROUGHOUT CLEANOUT, CHASE ALL SWEEPS TO SURFACE, LET SETTLE FOR 1 HR. RBIH AND RE TAG AT 5682' CTMD, BEGIN FCO AGAIN FROM 5682' CTMD DOWN TO CIBP AT 5750' RKB RBIH AND TAG @ 5711 PUMP ANOTHER 50 BBL GEL SWEEP AND CHASE IT TO SURFACE MAINTAINING 1:1 RETURNS RBIH TAGGED @ 5726' CTMD 5748 RKB FLUFF & STUFF RE-TAG @ 5736' CTMD 6/8/2023 SUPPORT OTHER OPERATIONS SLB ELINE CEMENT EVALUATION LOG - IBC/DSLT TAG FILL INITIALLY AT APPROX 5695', LOGGING PASSES FROM 5690' - 5350', LOG PASSES AT MULTIPLE RESOLUTIONS, 5DEG 6IN, 5DEG 3IN, 5DEG 1.5IN, 5DEG 0.6IN, LOG REPEAT PASSES, TAGGED FILL HIGHER ON SUBSEQUENT PASSES, LAST TAG AT 5645', UNABLE TO ROTATE SUB, POOH, DATA UPLOADED TO INTERACT FOR PROCESSING JOB COMPLETE 6/20/2023 SUPPORT OTHER OPERATIONS TAG FILL @ 5714' SLM W/ 3" BAILER (COLLECTED SAMPLE FOR COMPOSITIONAL ANALYSIS). READY FOR PLAN FORWARD. 8/2/2023 SUPPORT OTHER OPERATIONS DRY TAG AT 5738' CTMD, LAY IN 8.7 BBLS OF 15.8 PPG CLASS G CEMENT, TOC AT 5520' CTMD, F/P TO 3000' CTMD, JOB IN PROGRESS 8/5/2023 SUPPORT OTHER OPERATIONS RIG UP ELINE AND 3RD PARTY CRANE FOR PERFORATING. RIH WITH PEK/WPSA/4.72'' POWERFLOW HSD,20FT, 21SPF. ATTEMPTED TO TAG EXPECTED TD AT 5520 BUT AFTER SEVERAL TRIES, TAGGED TD AT 5286'. LOGGED FROM THERE TO 250FT. CONFER W/ TOWN ENGINEER, POOH TO DISARM GUN AND INSTALL CCL WITH WEIGHTBARS TO TAG TD AGAIN. CONTINUE JOB TO NEXT DAY 8/6/2023 SUPPORT OTHER OPERATIONS CONTINUED PERFORATION JOB, UNABLE TO PERFORATE INTERVAL DUE TO TAGGING TD SEVERAL TIMES ABOVE THE INTERVAL AT 5290', WAS DETERMINED THAT PERFORATION OF INTERVAL UNABLE TO BE ACHIEVED AND POOH. *** JOB READY FOR PLAN FORWARD *** 8/24/2023 SUPPORT OTHER OPERATIONS 05:00 - 23:00 STANDBY @ 3B PAD. 23:00 - 23:59 INITIATE CTU MOVE TO 3S PAD. 8/25/2023 SUPPORT OTHER OPERATIONS MIRU RIH W/ 5.91" OD BEAR CLAW MILL. TAG OBSTRUCTION @ 5500'. MILL OFF OBSTRUCTION EASILY AND CONTINUE MILLING TO 5540'. POOH L/D MILL. P/U UNDERREAMER. RIH TO 5287'. UNDERREAM TO 5540'. 8/26/2023 SUPPORT OTHER OPERATIONS CHASE GEL SWEEPS AND BOTTOMS UP TO SURFACE WHILE FREEZE PROTECTING FROM 3000' W/ S. DIESEL. READY FOR ELINE. 8/26/2023 SUPPORT OTHER OPERATIONS CTU6 STAGED ON 3S PAD ON STANDBY WAITING FOR RIG MOVE OPERATIONS TO BE COMPLETE & ALLOW FOR ACCESS TO 3S PAD ACCESS ROAD. CTU CREW REPACKS TRIPLEX PUMP & PERFORMS HOUSEKEEPING & MAINTENANCE AS NEEDED. 8/27/2023 SUPPORT OTHER OPERATIONS CTU6 STAGED ON 3S PAD ON STANDBY WAITING FOR RIG MOVE OPERATIONS TO BE COMPLETE & ALLOW FOR ACCESS TO 3S PAD ACCESS ROAD 8/27/2023 SUPPORT OTHER OPERATIONS PERFORM JUNK BASKET/DRIFT RUN, TAGGED AT 5562' PREPARE FOR PERFORATION RUNS 8/28/2023 SUPPORT OTHER OPERATIONS PERFORM PERFORATION RUNS WITH BELOW INTERVALS WITH 4.72" POWERFLOW HSD GUNS, 21 SPF, 60 DEG PHASING: 5458' - 5498' 5500' - 5540' ***JOB CONTINUED*** 8/28/2023 SUPPORT OTHER OPERATIONS CTU6 STAGED ON 3S PAD ON STANDBY WAITING FOR RIG MOVE OPERATIONS TO BE COMPLETE & ALLOW FOR ACCESS TO 3S PAD ACCESS ROAD 8/29/2023 SUPPORT OTHER OPERATIONS CONTINUE PERFORATION RUNS AND COMPLETE THE BELOW INTERVALS WITH 4.72" POWERFLOW HSD GUNS, 21 SPF, 60 DEG PHASING: 5390' - 5414' 5416' - 5456' RUN POST PERF JUNK BASKET/GAUGE RING, TAG @ 5487' **READY FOR PWC** 8/29/2023 SUPPORT OTHER OPERATIONS CTU6 STAGED ON 3S PAD ON STANDBY WAITING FOR RIG MOVE OPERATIONS TO BE COMPLETE & ALLOW FOR ACCESS TO 3S PAD ACCESS ROAD 8/30/2023 SUPPORT OTHER OPERATIONS CTU6 STAGED ON 3S PAD ON STANDBY WAITING FOR RIG MOVE OPERATIONS TO BE COMPLETE & ALLOW FOR ACCESS TO 3S PAD ACCESS ROAD 8/31/2023 SUPPORT OTHER OPERATIONS CTU6 STAGED ON 3S PAD ON STANDBY WAITING FOR RIG MOVE OPERATIONS TO BE COMPLETE & ALLOW FOR ACCESS TO 3S PAD ACCESS ROAD 9/3/2023 SUPPORT OTHER OPERATIONS MIRU, RIH W/ HYDRAWELL WASH TOOL TO 5560' RKB (+11' CORRECTED DEPTH). WASH PERFS PER PROGRAM PUMPING SW AND GEL SWEEPS AT 3 BPM, 3700 PSI CIRC PRESSURE, 525 PSI WHP. RE-PACK CTU TRIPLEX PLUNGER WHILE WAITNG FOR CEMENT BLEND TEST RESULTS. 9/4/2023 SUPPORT OTHER OPERATIONS TRIPLEX PUMP WILL NOT PASS FIT FOR PURPOSE TEST. NPT WAITING FOR LRS PUMP TO ARRIVE. RU LRS, PUMP CEMENT WASH PER HYDRAWELL REP, MIXED AND PUMPED 73 BBLS, 15.8 CLASS G, AT 1.65 BPM, CONTAMINATE W/ 35 BBLS POWER VIS TO PLANNED TOC AT 5240' RKB, WASH OUT ~56 BBLS OF EXCESS CEMENT IN 7". FREEZE PROTECT COIL, 21 BBLS AND 7" CASING TO 3000' WITH 114 DIESEL. 9/6/2023 SUPPORT OTHER OPERATIONS STATE WITNESS (ADAM EARL) TAG CEMENT @ 5215'SLM. BRING BACK SAMPLE OF CEMENT. CONDUCT PASSING MIT. IN PROGRESS 9/6/2023 SUPPORT OTHER OPERATIONS MOVE RIG UP FROM 3S-26 TO 3S-06 MIRU RIH W / 5.90" BEAR CLAW MILL TAGGED CEMENT TOP AT 5217' CTMD START MILLING. MILL HARD CEMENT F/5217' T/ 5378', SLOW ROP. LRS PUMP DIED, PULL TO SURFACE, SWAP LRS UNITS.BHA LOOKED GOOD @ 5430' MILLING AHEAD 9/8/2023 SUPPORT OTHER OPERATIONS AT 5430' MILLING AHEAD PUMPING GEL SWEEPS. MILL TO 5570' CTMD, REACH TARGET DEPTH, CHASE 10 BBL PV GEL SWEEP OUT. CHANGE TO 6.25" UNDEREAMER. START UNDERREAM PASS F/ 5150' TO 5570' CTMD. PUMP 50 BBL GEL SWEEP AND CHASE TO SURFACE FREEZE PROTECT WELL FROM 2500' W / 96 BBLS OF DIESEL AT SURFACE P/U A NZ AND JET BOP'S RDMO 9/9/2023 SUPPORT OTHER OPERATIONS STANDBY WHILE HARDLINE CREW INSTALLS BOP. SPOT IN ELINE UNIT AND CRANE. HARDLINE CREW DOWNSTACK VALVE FROM WELLHEAD. HYDRAULIC LINE ON CRANE REPAIRED PRIOR TO RIGGING UP PRESSURE GEAR. JUNK BASKET WITH 5.9'' GAUGE RING RUN TO FIND TD, TAGGED AT 5532'. RETIREVED PIECE OF CEMENT FROM JUNK BASKET. PERFORM IBC-CBL LOG FROM 5525' TO 5300' WITH PASSES OF: 5deg 6" / 5deg 3" / 5deg 1.5" WAIT FOR WINDS TO DIE DOWN PRIOR TO UNSTAB, BEGIN RIG DOWN ***CONTINUED INTO NEXT DAY*** 9/10/2023 SUPPORT OTHER OPERATIONS FINISH RIGGING DOWN PCE. JOB COMPLETE 9/27/2023 ACQUIRE DATA (AC EVAL) OA-DDT (COMPLETE) 9/29/2023 SUPPORT OTHER OPERATIONS (P&A) OA TOC @ 83'. 9/29/2023 SUPPORT OTHER OPERATIONS TRAVEL FROM PRUDHOE T/3S-06/ MIRU 9/30/2023 SUPPORT OTHER OPERATIONS PUMP 231 BBL OF 15.8 PPG CEMENT TO CTU LAYING IN CEMENT IN 7" PRODUCTION CASING FROM 5570' TO SURFACE. SAMPLED & WEIGHED CEMENT RETURNS @ SURFACE = 15.8 PPG. READY FOR WELLHEAD EXCAVATION. 10/2/2023 CHANGE WELL TYPE (P&A) OA DDT (IN PROGRESS) 10/3/2023 SUPPORT OTHER OPERATIONS (P&A) T x IA DDT PASSED TO 0 PSI, T X IA TOC 12', OA DDT TO 0 PSI IN PROGRESS. 10/4/2023 CHANGE WELL TYPE (P&A) OA DDT (IN PROGRESS) 10/5/2023 CHANGE WELL TYPE (P&A) OA DDT (IN PROGRESS) 10/6/2023 CHANGE WELL TYPE (P&A) OA DDT (1 HR DDT PASS) 10/7/2023 CHANGE WELL TYPE (P&A) CIRC'D IN 10 BBL SURFACTANT INTO OA, CIRC'D IN ~3.0 BBL 15.7 LBS/GAL PORTLAND TYPE 1 CEMENT INTO OA, TOPPED OFF 7" WITH ~0.5 BBL 15.7 LBS/GAL PORTLAND TYPE 1 CEMENT. 10/9/2023 CHANGE WELL TYPE (P&A) CUT AND REMOVE THE WELLHEAD (COMPLETE) 10/10/2023 CHANGE WELL TYPE (P&A) CUT & REMOVE CELLAR BOX (COMPLETE) SET SHORING "CAN" (COMPLETE) EXCAVATION TO > 4' BELOW OG (IN PROGRESS) 10/11/2023 CHANGE WELL TYPE (P&A) EXCAVATE TO >4' BELOW TUNDRA (IN PROGRESS ~8' BELOW PAD GRADE) 10/12/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- CONTINUED TO EXCAVATE WITHIN SHORE CAN TO >4' BELOW ORIGINAL GROUND (TUNDRA). APPROXIMATE CURRENT DEPTH 10' BELOW PAD GRADE . ***NEXT STEP PREP WELL STUB FOR REMOVAL.*** 10/13/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- CUT INSULATED JACKET, CONDUCTOR AND SURFACE CASING WINDOWS. ****NEXT STEP- CUT PC WINDOW, REMOVE WELL STUB AND PREP FOR MARKER PLATE.. 10/14/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- CUT AND REMOVED ADDITIONAL ~67" OF WELL STUB. APPROXIMATE LOCATION OF TOC IS 8' 10" BELOW OG (TUNDRA). PREPARED WELL STUB FOR MARKER PLATE WELD, WIRE WHEELED SHORE CAN FOR INSPECTION BY MISTRAS. ***NEXT STEP- AOGCC WITNESS OF TOC AND MARKER PLATE INFORMATION & INSTALLATION*** 10/15/2023 CHANGE WELL TYPE (P&A) AOGCC INSPECTOR GUY COOK WITNESSED MARKER PLATE INFORMATION AND WELD FOR 3S-06A P&A. MISTRAS INSPECTED SHORE CAN PRIOR TO CAN EXTRACTION. BACKFILLED SHORE CAN AND VIBRATED OUT OF THE GROUND. *** NEXT STEP - REQUEST FINAL SITE CLEARANCE, TOWN ENGINEER TO SUBMIT 10-407, DRILLING TO INSTALL NEXT CONDUCTOR.*** 10/16/2023 CHANGE WELL TYPE (P&A) FINAL SITE CLEARANCE VIEWED BY AOGCC INSPECTOR SEAN SULLY SULLIVAN. P&A COMPLETED . READY FOR DRILLING DEPARTMENT. 10/25/2023 MAINTAIN WELL FREEZE PROTECT FLOWLINE PUMPED 3 BBLS METH DWN FL TO HEADER Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 7/30/2022 00:00 Cementing End Date Wellbore Name 3S-06A Comment Cement Stages Stage # <Stage Number?> Description Cement Plug Objective Top Depth (ftKB) 7,943.2 Bottom Depth (ftKB) 8,382.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 7/30/2022 00:00 Cementing End Date Wellbore Name 3S-06A Comment Cement Stages Stage # <Stage Number?> Description Cement Plug Objective Top Depth (ftKB) 7,933.0 Bottom Depth (ftKB) 7,943.3 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 11/5/2022 08:00 Cementing End Date 11/5/2022 16:30 Wellbore Name 3S-06A Comment Pumped 108 BBLS of 15.8 PPG Permafrost Cement down the 7" x 9 5/8" annulus. Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 42.4 Bottom Depth (ftKB) 3,071.7 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 108 BBLS of 15.8 PPG Permafrost Cement down the 7" x 9 5/8" annulus - Changed top was 34.0 Cement Fluids & Additives Fluid Fluid Type Abandonment Cement Fluid Description Other Estimated Top (ftKB) 29.6 Est Btm (ftKB) 3,071.7 Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: SUPPORT OTHER OPERATIONS-ABAND… Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 11/20/2022 00:00 Cementing End Date Wellbore Name 3S-06A Comment Cement Stages Stage # <Stage Number?> Description Plug – Perf-Wash- Cement Objective Top Depth (ftKB) 5,570.0 Bottom Depth (ftKB) 5,720.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment PUMP 68.5 BBLS OF 15.8 PPG CEMENT THROUGH HYDRAWELL TOOL Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 8/2/2023 00:00 Cementing End Date 8/2/2023 00:00 Wellbore Name 3S-06A Comment LAY IN 8.7 BBLS, 15.8, CLASS G Cement Stages Stage # <Stage Number?> Description Cement Plug Objective Top Depth (ftKB) 5,560.0 Bottom Depth (ftKB) 5,749.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment LAY IN 8.7 BBL, 15.8 PPG, CLASS G Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 9/4/2023 00:00 Cementing End Date 9/4/2023 00:00 Wellbore Name 3S-06A Comment Cement Stages Stage # <Stage Number?> Description Plug – Perf-Wash- Cement Objective Top Depth (ftKB) 5,390.0 Bottom Depth (ftKB) 5,540.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) 5,581.0 Drill Out Diameter (in) 6 Comment 73 BBLS, 15.8 PPG, CLASS G Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: Page 1/1 3S-06 Report Printed: 11/8/2023 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 9/30/2023 06:45 Cementing End Date Wellbore Name 3S-06A Comment Cement Stages Stage # <Stage Number?> Description Plug – Plug Back / Abandonment Plug Objective Top Depth (ftKB) 42.4 Bottom Depth (ftKB) 5,570.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment LAY IN 231 BBLS,15.8 PPG, TYPE I-II, CEMENT 7"PROD CSG TO SURFACE - Changed for P&A - was 35.1 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: 2023-1015_Surface_Abandon_KRU_3S-06A_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/15/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-06A Conoco/Phillips Alaska PTD 2030880; Sundry 322-430 10/15/2023: I arrived on site and met with Roger Mouser with CPAI. We talked about the P&A and looked at the program and Sundry. After CPAI Safety had checked for gas at the well and gave us the go-ahead to enter the confined space, we headed towards the well-site. When we arrived at the well-site and confirmed the cutoff casing was 8 feet 8 inches under tundra level and that the information on the identification plate was correct. At this time, we asked the welder to add the “A” at the end of the well name on the plate. We also confirmed that the cement to surface was good hard cement. I gave the go-ahead to install the identification plate. After the plate was installed, I confirmed the ¼-inch thick plate was completely welded and sealed to the casing. I gave the go-ahead to bury the well and then left location. Attachments: Photos (5)     2023-1015_Surface_Abandon_KRU_3S-06A_gc Page 2 of 4 Surface Abandonment – KRU 3S-06A (PTD 2030880) Photos by AOGCC Inspector G. Cook 10/15/2023 2023-1015_Surface_Abandon_KRU_3S-06A_gc Page 3 of 4 2023-1015_Surface_Abandon_KRU_3S-06A_gc Page 4 of 4 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:8579 ft MD Lease No.:ADL 0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3072 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8569 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 7943 Feet Tbg Cut@ 7841 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 5749 ft 5215 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1660 1580 1545 IA OA 430 430 430 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sidney Furguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled out to KRU 3S-06A to witness a wireline tag and pressure test for P & A operations. Tagged top of cement @ 5215 ft MD.The tool string consisted of 13 feet of 2 1/8-inch weight bar, oil jars, spangs, and a sample bailer. Hanging weight was 175lbs. Good sample of set-up cement in bailer. Pressure test went as per chart above. September 6, 2023 Adam Earl Well Bore Plug & Abandonment KRU 3S-06A ConocoPhillips Alaska Inc. PTD 2030880; Sundry 322-430 none Test Data: P Casing Removal: rev. 3-24-2022 2023-0906_Plug_Verification_KRU_3S-06A_ae              1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 9-5/8" L-80 2606' 7" L-80 6133' 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 203-088/ 322-149 27' 62.5# 40# 108' 27' WT. PER FT.GRADE CEMENTING RECORD 5998960 SETTING DEPTH TVD 5999137 TOP HOLE SIZE AMOUNT PULLED 476103 476138 TOP SETTING DEPTH MD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: SUSPENDED Perforations: 8252-8282' MD and 5870-5895' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 510 sx AS Lite, 300 sx LiteCrete 30' 3072'30' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 8569' SIZE DEPTH SET (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 1565' MD/ 1548' TVD 6644' MD/ 4677' TVD 2483' FNL, 915' FEL, Sec. 18, T12N, R8E, UM 2558' FNL, 1119' FEL, Sec. 7, T12N, R8E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476344 5993933 2544' FSL, 1154' FEL, Sec. 7, T12N, R8E, UM 7933' MD/ 5613' TVD 8579' MD/ 6142' TVD ADL0380106, ADL0380107 ALK 4623 50-103-20454-01-0 KRU 3S-06A May 25, 2003 May 15, 2003 9. Ref Elevations: KB: 28' Kuparuk River Field/ Kuparuk River Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/12/2022 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 300 sx Class G w/ GasBlok7" 7943'3-1/2" CASING 27 bbls 15.8 ppg Cement below retainer, 1bbl 15.8 Cement above retainer 7933'-8282' MD 7911' MD/ 5596' TVD PACKER SET (MD/TVD) 42" 12-1/4" 66 sx ArcticCrete 30' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:03 am, Feb 21, 2023 Suspended 8/12/2022 JSB RBDMS JSB 022823 xG Permit to Drill Number / Sundry 8/12/2022 DSR-3/3/23WCB 2023-07-17 Susp Suspended Service KRU 3S-06A 203-088/ 322-149 Kuparuk River Field/ Kuparuk River Oil Pool Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1565' 1548' 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 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. 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 Signed for Jill Simek Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this documentLocation:Date: 2023.02.20 15:22:26-09'00'Foxit PDF Editor Version: 12.0.1 Allen Eschete Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: Mill out cement plug 5420' - 5749' RKB 3S-06A 11/27/2022 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for Water-Only Injection due to TxIA on gas 11/16/2017 pproven General Notes: Last 3 entries Com Date Last Mod By THIS WELLBORE WAS ABANDONED, REPLACED BY 3S-06A 5/23/2003 Admin TREE: FMX / WKM / GEN 5 / 5M TREE CAP CONNECTION: TOP 5.75"" ACME with 3.5"" EUE8RD THREAD 5/17/2003 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 29.6 3,071.7 2,606.5 40.00 L-80 BTC PRODUCTION 7 6.28 27.1 8,568.6 6,133.4 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,841.0 Set Depth … 7,943.2 Set Depth … 5,621.4 String Ma… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,856.8 5,553.5 38.54 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 7,894.6 5,583.1 38.21 SEAL ASSY 4.500 LOCATOR SUB & PBR 12' SEAL ASSEMBLY (SPACED OUT) 2.992 7,896.6 5,584.7 38.19 PBR 5.890 BAKER 80-40 PBR BAKER 80-40 2.990 7,910.3 5,595.5 38.07 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.992 7,911.2 5,596.2 38.06 PACKER 5.960 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,916.1 5,600.1 38.02 MILL 3.500 80-40 MILL OUT EXTENSION 80-40 2.992 7,935.2 5,615.1 37.82 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 7,942.3 5,620.7 37.75 WLEG 5.000 WLEG w/ SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,749.0 4,149.4 55.37 CIBP AK EL (LEGACY) CIBP MID- ELEMENT AT 5750' RKB, OAL 2' LEGACY 000- 5610- 002 9/24/2022 0.000 7,841.0 5,541.2 38.68 CUT WELLTEC MECHANICAL TUBING CUT AT 7841' RKB 9/1/2022 2.992 7,932.0 5,612.6 37.86 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/30/2022 0.000 7,933.0 5,613.4 37.85 TUBING PLUG Pumped 28 bbls of 15.8 ppg cement. 27 bbls below & 1 bbl on top 7/30/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,570.0 5,720.0 4,047.6 4,132.9 10/1/2022 21.0 APERF 4.72" HSD, PowerFLow 4621, RDX (19g, 21 spf, 60° PHASE, API: 5.9 PEN, 0.83" EH). (10/4/22) 8,252.0 8,282.0 5,870.5 5,895.1 UNIT D, 3S-06A 5/25/2003 6.0 IPERF 2.5" HSD PJ Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,420.0 5,749.0 3,960.8 4,149.4 Cement Plug 15.8 ppg Cement pumped through HyrdaWell tool. 11/20/2022 IPERF; 8,252.0-8,282.0 TUBING PLUG; 7,933.0 CEMENT RETAINER; 7,932.0 PACKER; 7,911.2 CUT; 7,841.0 CIBP; 5,749.0 APERF; 5,570.0-5,720.0 Cement Plug; 5,420.0 ftKB SURFACE; 29.6-3,071.7 Cement Plug; 29.6 ftKB CONDUCTOR; 30.0-108.0 DTTMSTART JOBTYP SUMMARYOPS 7/30/2022 SUPPORT OTHER OPERATIONS FUNCTION TEST BOPS SET RETAINER @ 7932' PUMPED 28 BBLS OF 15.8 PPG CEMENT PUMPED 27 BBLS BELOW RETAINER & 1 BBL ON TOP DRESS CEMENT TOP OFF 7817' POOH 8/5/2022 SUPPORT OTHER OPERATIONS DRIFT TBG W/ 2.75" CENT & SAMPLE BAILER, TAG TOC @ 7928' SLM, RECOVER CEMENT IN SAMPLE BAILER, NOTE TIGHT SPOT @ 7825' SLM, PERFORM PASSING MITT TO 1500 PSI. PERFORM PASSING DDT-T. IN PROGRESS 8/11/2022 SUPPORT OTHER OPERATIONS (P&A PREP) FUNCTION TEST T & IC LDS/GNS (COMPLETE), T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED) 8/12/2022 SUPPORT OTHER OPERATIONS STATE WITNESS DRIFT TBG W/ 2.25" CENT @ SAMPLE BAILER, TAG TOC @ 7933' SLM, RECOVER CEMENT IN SAMPLE BAILER,LRS TO MITT & CMIT WELL, (PASSED) JOB COMPLETE 3S-06A Suspend Summary of Operations The retainer was set @7932', 320' above the uppermost perfs, between 50' and 500', satisfying 25.112(c)(1)(D). -WCB SET RETAINER @ 7932' PUMPED 28 BBLS OF 15.8 PPG CEMENT PUMPED 27 BBLS BELOW RETAINER & 1 BBL ON TOP DRESS CEMENT TOP OFF 7817' POOH Taking into account the retainer depth, tubing and casing capacities, and cement volume pumped, 11.1 bbls cement were pumped into the formation, meeting their squeeze volume of 10 bbls. -WCB DRIFT TBG W / 2.75" CENT & SAMPLE BAILER, TAG TOC @ 7928' SLM TOC was tagged @7933', basically at the depth of the retainer, not the planned 7817' (115' of cement atop the retainer). -WCB **The below WBS does not show cement in the 7" casing. Per my request, Conoco sent an updated WBS, showing the cement in the casing. The new WBS is its own PDF, separate from this file. -WCB MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: na Rig Elevation: na Total Depth: 8,569 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@ 3072 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8569 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 7943 Feet Tbg Cut@ 7841 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 5749 ft 5654 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1175 IA 1175 OA 400 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Well taking fluid at 1 bbl/min 1175 psi steady. 4 bbls pumped total. Tagged hard cement @ 5,654 ft MD with good cement sample in bailer. Tool string consisted of 10 ft of 1-7/8" wt bar, centralizer, and 24-inch long 1-3/4" bailer. Down weight 220lbs . December 10, 2022 Adam Earl Well Bore Plug & Abandonment KRU 3S-06A CPAI PTD 2030880; Sundry 322-430 none Plugging Data: Test Data: F Casing Removal:Casing/Tubing Data: No CPA rep on location rev. 11-28-18 2022-1210_Plug_Verification_KRU_3S-06A_ae 9 9 9 9 9 9 9 999 9 9 9 9 9 9 9 9Well taking fluid at 1 bbl/min 1175 psi steady. James B. Regg Digitally signed by James B. Regg Date: 2023.04.19 15:45:47 -08'00' 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: 8579 ft MD Lease No.: ADL 0380107 Operator Rep: Suspend: P&A: XXX Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3072 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8569 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 7943 Feet Tbg Cut@ 7841 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 5749 ft 5600 ft 7.5 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Program called to tag CIBP at 5749 ft after CTU cleanout. Only got to 5600 ft SLM. I call Victoria Loepp (AOGCC) and she stated they need to log the perfs so I didn’t do the MIT as they need CTU to do another cleanout. December 1st 2022 Brian Bixby Well Bore Plug & Abandonment KRU 3S-06A ConocoPhillips Alaska, Inc. PTD 2030880; Sundry 322-430 none Test Data: Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-1201_Plug_Verification_KRU 3S-06A_bb 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.04.19 12:24:01 -08'00' 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: Doyon 19 Rig Elevation: 33.6 ft Total Depth: 8579 ft MD Lease No.: ADL 0380107 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 3072 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8569 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 7943 Feet Tbg Cut@ 7841 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 5749 ft 5459 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA 1710 1600 1550 OA 650 660 660 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): Pre-test pressures: IA 0 psi, O/A 350psi; 3-1/2" tbg cut at 7841 ft MD and removed. Passing test with less than 10% pressure loss and good stabilization. November 24, 2022 Kam StJohn Well Bore Plug & Abandonment KRU 3S-06A ConocoPhillips Alaska Inc PTD 2030880; Sundry 322-430 Cement sample Picture Test Data: P Casing Removal: rev. 11-28-18 2022-1124_Plug_Verification_KRU_3S-06A_ksj 9 9 9999 9 9 9 9 9 9 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. 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Rep Email: Well Name:PTD #2030880 Sundry #322-430 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1440 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8"P Pit Level Indicators PP #1 Rams 1 3.5" X 6"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3.5" X 6"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3.125 P Time/Pressure Test Result HCR Valves 2 3.125 P System Pressure (psi)3000 P Kill Line Valves 1 3.125 P Pressure After Closure (psi)1400 P Check Valve 0NA200 psi Attained (sec)18 P BOP Misc 1 4" Kill line Demco P Full Pressure Attained (sec)170 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 @ 2368 P No. Valves 14 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 18 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 13 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/4/22 1:15pm Waived By Test Start Date/Time:9/6/2022 9:00 (date) (time)Witness Test Finish Date/Time:9/6/2022 13:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Doyon Test all BOPE componets with 3.5" test joint 250psi low 5mins ea / 2500psi high 5min ea. Bottle Precharge - 1050 psi. Kelly Haug Einar Fleagle CPAI Andy Lundale Dusty Pickworth KRU 3S-06A Test Pressure (psi): rig19@doyondrilling.com d19cm@conocophillips.com Form 10-424 (Revised 08/2022) 2022-0906_BOP_Doyon19_KRU_3S-06A 9 9 9 999 9 9 9 9 9 9 9 9 -5HJJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 8579 ft MD Lease No.: ADL0380106 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3072 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8569 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 7943 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer 7932 ft 7933 ft 7.1 ppg Wireline tag MITT Initial 15 min 30 min 45 min Result Tubing 1500 1475 1475 IA 260 280 280 OA 280 280 280 MITIA Initial 15 min 30 min 45 min Result Tubing 380 400 400 IA 1690 1660 1660 OA 450 450 450 Remarks: Attachments: Suspension plug. Inspector Bob Noble and I arirved on location; talk with S/L unit operator witnessed run in the hole with a bailer for plug tag. Pick up and set down 3 times after initial tag - call depth 7933 ft MD. Top of cement and retainer depths are oddly close; email from Victoria Loepp (AOGCC) determined good cement job. MITT & MITIA went well. Location was in good order. 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"$ !" #$+,- #. $/0 $ 11# (!""23 %4 *!& !" #/$ &*"5$0 $ &'&6&! &!7$%/ / 8%/ ,- #$%/ 1!9$0 $ :! &$/0 $ 6;4!(- 9<!(&" =&$0 $ ,1* =& * #;&>$ !((!&,1* &'&)?@1& (&.> $ 0' FHPHQW WRS SHUI WR 77 $0 $%/ ^hWZ^ %# !'! ^hWZ^ • Pris3O Q Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, November 13, 2017 11:18 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: MIT KRU 3S-06A Diagnostic 8-23-17 \GC'q I((131 t7 Attachments: MIT KRU 3S-06A Diagnostic 8-23-17.xlsx SCANNED f • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoo(o)alaska.gov AOGCC.Inspectors(cDalaska.aov phoebe.brooks(cdalaska.00v chris.wallace alaska.ciov OPERATOR: ConocoPhillips Alaska,Inc. ' e?i II(i?,it 7 FIELD/UNIT/PAD: Kuparuk/KRU/3S Pad DATE: 08/23/17 OPERATOR REP: Phillips/Arend AOGCC REP: None Well 3S-06A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2030880- Type lnj G - Tubing 3410 3350 - 3350 ` 3350 ' Type Test P Packer TVD 5596 ' BBL Pump 0.7 IA 1840 2850 - 2820 _ 2820 ' Interval 0 Test psi 1500 - BBL Return OA 90 . 150 . 150 - 150 - Result P ✓ Notes: Non-witnessed Diagnostic Test. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. . PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Retum OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Retum OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 35-06A Diagnostic 8-23-17 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, October 8, 2017 11:08 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3S-06 (PTD 203-088) Update Chris, Injector KRU 35-06(PTD 203-088)completed a 30-day monitoring period of water injection. The pressure trends during this monitoring period were very stable and showed no suspicious anomalies. However,the IA pressure was left at a relatively high pressure (-1600 psi)following the gas injection period. Before submitting a proposal for Administrative Approval,CPAI proposes performing an additional 30-day monitoring period of water injection with a reduced IA pressure. If this additional monitoring period is successful,we will submit an application for Administrative Approval for water injection only. Please let me know if you have any questions or disagree with this plan. Regards, Travis From: NSK Well Integrity Supv CPF3 and WNS Sent: Monday, September 04, 2017 1:36 PM Sata" `ti, , To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 3S-06(PTD 203-088) Update on Suspect IA pressure Chris, Injector KRU 35-06(PTD 203-088)was previously reported for a suspect increasing IA pressure. The DHD crew has obtained diagnostics including a passing MITIA and packoff tests. They also performed an IA drawdown test that didn't show pressure build-up initially. The well is currently on a 30-day gas injection monitor. However, based on the monitor results to date and the results from a bleed done today,TxIA communication on gas injection appears confirmed. The plan is to end the gas monitor early and WAG the well to water as soon as operationally possible for a 30-day monitor on water injection. If the well shows integrity while on water injection,CPAI intends to submit an application for Administrative Approval to continue water-only injection. Attached is a 90-day TIO plot. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, September 4, 2017 1:36 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3S-06 (PTD 203-088) Update on Suspect IA pressure Attachments: 3S-06 TIO plot 90-day 9-4-2017.docx Chris, Injector KRU 3S-06 (PTD 203-088)was previously reported for a suspect increasing IA pressure. The DHD crew has obtained diagnostics including a passing MITIA and packoff tests. They also performed an IA drawdown test that didn't show pressure build-up initially. The well is currently on a 30-day gas injection monitor. However, based on the monitor results to date and the results from a bleed done today,TxIA communication on gas injection appears confirmed. The plan is to end the gas monitor early and WAG the well to water as soon as operationally possible for a 30-day monitor on water injection. If the well shows integrity while on water injection,CPAI intends to submit an application for Administrative Approval to continue water-only injection. Attached is a 90-day TIO plot. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 WED (3E1) 1 ?Pi./ S • S Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, August 21, 2017 5:23 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3S-06A (PTD# 203-088) IA Pressurization Attachments: 3S-06A 90-day TIO jpg; 3S-06A.pdf Chris, KRU 3S-06A(PTD#203-088) is a WAG injector currently on gas injection and has been identified with an increasing IA pressure trend. The current plan is to bleed down the IA pressure and put the well on a 30-day monitoring period. Additionally,CPAI plans to send a DHD crew to do diagnostics and update you with the results and plan forward. Attached is a 90-day TIO plot. Please let us know if you have any questions or disagree with this plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED AUG 2 3 .2n17 • • i ED OCT 232015 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 20, 2015 CANNED MAY 1 201G 03- 0(3'Z5 S 3 Commissioner Cathy Foerster Alaska Oil& Gas Commission 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 spreadsheet 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, / . /c...j.------/- MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/20/2015 3H,3J,3Q&3S Pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-26 501032020800 1940290 9" NA 9" NA 4.3 10/9/2015 3J-18 500292270100 1961470 12" NA 12" NA 8 10/3/2015 3J-19 500292270200 1961480 11" NA 11" NA 4.25 10/5/2015 3Q-21 500292263000 1951930 12" NA 12" NA 5.5 10/9/2015 3S-6A 501032045401 2030880 11" NA 11" NA 9.1 10/3/2015 3S-23A 501032045301 2060430 16" NA 16" NA 6.2 10/3/2015 3S-24A 501032045601 2040610 18" NA 18" NA 6.3 10/3/2015 3S-26 501032036101 2010400 9" NA 9" NA 3.8 10/3/2015 `li ices V N.e.," STATE OF ALASKA O C I 0 8 2015 ALIIIIA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing fl Operations shutdown r Performed: Suspend r Perforate r Other Stimulate rAlter Casing rChange Approved Program g ppr Plug for Redrill Perforate New Pool rRepair Well r. Re-enter Susp Well r Other:Conductor Extension 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 203-088 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20454-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380106 KRU 3S-06A 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 8579 feet Plugs(measured) None true vertical 6142 feet Junk(measured) None Effective Depth measured 8401 feet Packer(measured) 7911 true vertical 5993 feet (true vertical) 5596 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 1640 630 SURFACE 3042 9-5/8 3072 2606 5750 3090 PRODUCTION 8542 7 8569 6113 7240 5410 Perforation depth: Measured depth: 8252-8282MED J/N 0 Z U i b True Vertical Depth: 5870-5895 e� Tubing(size,grade,MD,and TVD) 3.5, L-80, 7942 MD,5621 TVD Packers&SSSV(type,MD,and TVD) PACKER=BAKER SAB-3 PACKER @ 7911 MD and 5596 TVD SSSV=CAMCO"DS"NIPPLE @ 507 MD and 506 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 17 Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r 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: 315-431 Contact MJ Loveland/Martin Walters Email n1878(p�conocophillips.com Printed Name Martin Walters Title WI Project Supervisor SignatureA44t///Vid&--- VTL _ Phone:659-7043 Date: 10/4/2015 fottz-/i5. RBDMS fir i 12 2015 Form 10-404 Revised 5/2015 Submit Original Only • • 3S-06A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/15 Welder welded 12"x 16" .375 62#extension onto conductor. 10/03/15 Injected 9.1 gallons of RG2401 sealant into the conductor. • • 3S-06A DESCRIPTION OF WORK COMPLETED SUMMARY OF Tk evwP //7; cv THE STATE • ` Alaska Oil and Gas ofdAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 4LAS1+ Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland1 ?M WI Project SupervisorE.CA � �1 ConocoPhillips Alaska, Inc. S— a,03 - og5 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-06A Sundry Number: 315-533 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Ct day of September, 2015 RBDMS SEP 11 2015 Encl. STATE OF ALASKA • A KA OIL AND GAS CONSERVATION COMOSION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other Conductor Extensions 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r— Development r' 203-088 3.Address: 6.API Number: Stratigraphic r Service ;. P. O. Box 100360,Anchorage,Alaska 99510 50-103-20454-01 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 F7 I KRU 3S-06A . 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): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8579 . 6142 . 8401'' 5993'• Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' SURFACE 3042 12 3072' 2606' PRODUCTION 8542 10 8569' 6113' t AUi .2 $ 2015 c / . AO G GG Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8252-8282 ., 5870-5895 3.5 L-80 7942 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SAB-3 PACKER • MD=7911 TVD=5596 NIPPLE-No SSSV • MD= 506 TVD=506 12.Attachments: Description Summary of Proposal r 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: 9/9/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS IT WAG 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: MJ Loveland/Martin Walters Email: N1878@conocophillips.com Printed Name MJ Loveland Title: WI Project Supervisor Signature /`% y Phone:659-7043 Date c14,27.., j,5---- Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -j – 33 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No I Subsequent Form Required: /0— q-i4F 7)1 �p g APPROVED BY V/—/ Approved by: p C o a� T r<1 montViols_thT�iFW IS ��e Val Date: 9(//S tEP mit Form and Form 10-403 Revised 5/2015 RBDM r �tt�c a sin Duplicate • • IIPV ConocoPhillips RFCEWED Alaska AUG 2 8 �0�5 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 '+ tACC August 24, 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-06A, PTD 203-088 conductor extension./ Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, .79/1/ L ,zr.c.../ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 3S-06A (PTD 203-088) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 24, 2015 This application for Sundry approval for Kuparuk well 3S-06A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 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 110 3S-06A ConocoPhillips ; Well Attributes Max Angle&MD TD ♦ AiKi,111:.:. Wellbore API/UWI Field Name Wellbore Status Inc!I') MD(ftKB) Act Btm(ftKB) [mnrnrhdlger 501032045401 KUPARUK RIVER UNIT INJ 56.78 3,116.73 8,907.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3S-06A,11/11/20147:45:46AM SSSV:NIPPLE Last WO: 33.60 5/12/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,264.0 11/10/2014 Rev Reason:TAG Iehallf 11/11/2014 11 Casing Strings HANGER;24.9 Casing Description OD(in) ID(in) Top(f(KB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(L..Grade Top Thread CONDUCTOR IV Casing Description 16 15.062 30.0 108.0 108.0 62.50 H-40 WELDED OD(in) ID(in) Top(ftKB) Set Depth(ftKB) :Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 9 5/8 8.835 29.6 3,071.7 2,606.5 40.00 L-80 BTC r Casing Description OD(i)) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION• • 7 6.276 27.1 8,568.6 6,133.4 26.00 L-80 BTCM Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 24.9 7,943.2 5,621.4 930 LOU EUE8RDMOD 1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Core (in) 24.9 24.9 0.20 HANGER FMC GEN 5 TUBING HANGER 3.500 506.8 506.0 6.60 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 �� ..►/.,..\.d - 7,856.8 5,553.5 38.54 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO 2.812 CONDUCTOR;30.0-108.0 7,894.6 5,583.1 3821 SEAL ASSY LOCATOR SUB 8 PBR 12 SEAL ASSEMBLY(SPACED 2.992 OUT) 7,896.6 5,584.7 38.19 PBR BAKER 80-40 PBR 2.990 7,910.3 5,595.5 38.07 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 2.992 NIPPLE;506.8 7,911.2 5,596.2 38.06 PACKER BAKER SAB-3 PACKER 3.250 7,916.1 5,600.1 38.02 MILL 80-40 MILL OUT EXTENSION 2.992 7,935.2 5,615.1 37.82 NIPPLE CAMCO D NIPPLE w/2.75"NO GO 2.750 7,942.3 5,620.7 37.75 WLEG WLEG w/SHEAR OUT SUB 3.000 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots% Top(ftKB) Btm(ftKB) (kKB) (kKB) Zone Date t) Type Com • SURFACE;29.6-3,071.7- 8,252.0 8,282.0 5,870.5 5,895.1' 5/25/2003 6.0 IPERF 2.5"HSD PJ Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com I. 7,812.3 5,518.8 CAMCO MMD 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/22/2003 GAS LIFT;7,812.3 Notes:General&Safety End Date Annotation 12/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE,7.856.8 -3 I SEAL ASSY',7,894.6 PBR;7,8966 ANCHOR;7,910.3 PACKER;7.911.2iii MILL;7,916.1 } I NIPPLE;7,935.2 M. M II WLEG;7,9423 IPERF;8,252.0-8,282.0 y PRODUCTION;27.1-8,568.6-+ Image ~ .hject Well History File C"Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~03- 038 Well History File Identifier Organizing (done) RESCAN Älor Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: Helen ~ Project Proofing BY: Helen c- Maria) Scanning Preparation BY: Helen '>4ì::~ Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria ~WO-Sided 11111111I1111111111 DIGITAL DATA ~ketles. NO.~ o Other, No/Type: I x30='30 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~escan Needed OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: ' /,) ~ Date: 7 t ö os 151 1- 1 Date: ~ I ff,.. 0!S1s1 wvP m-.Ð I , + t~ J.-- = TOTAL PAGES 6d-- (Count does no..~c{,de cover sheet) IAA .Q Date:""" t~.. D!57s1 r ~ ~/ 1 , YES NO Date: 151 11I1111111111111111 11I1111111111111111 1 Date: 151 Quality Checked 1111111111111111111 Page Count from Scanned File: S3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: / YE~ ( ~o , . Helen~~ Date: r-' ¡~ 05 /5/ J!l1/'!J If NO in stage 1, page(s) discrepancies were found: • • MEMORANDUM TO: Jim Regg ~~~~, ~ f ~ Z/ ; `1 J ~. P.I. Supervisor FROM: $ob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3 S-06A KUPARUK RIV UNIT 3S-06A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3S-06A API Well Number: s0-103-20454-01-00 Insp Num: mitRCN100809150126 Permit Number: 203-088-0 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 8/7/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S-06A- Type Inj. ~ ~'' TVD ss9~ IA 970 lsso 1810 ]s1o - P.T.D. zo3osao ~ TypeTest SPT TCSt pSl ~ 18s0- - OA ss0 600 600 600 Interval 4YRTST p~ P ~ Tubing ~ 247s 247s 247s 247s ~ Notes: ti~~ u1, (-Qc' ~C~ ~S~ [ 5 uvps~ ~.. ~'' ~_ Tuesday, August ] 0, 2010 Page 1 of 1 • ~ --~... -~ -.. MICROFILMED 03/01/2008 DO NOT PLACE m':_,. , ,.~;.- - ~. ~:. ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Miicrofilm_Marker. doc . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 . November 14, 2006 RE: MWD Formation Evaluation Logs: 3S-03, 3S-06, 3S-06A, 3S-08_3S-08A_3S-08B, 3S-14, 3 S-15 . The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 () 1 2001 sGAN'~EO F\:.B· . 1f: 3S-03: 'dD:3 -oDt I ¡~71~d Digital Log Images: 50-103-20458-00 3S-06: l> IC-- Go3 -()S-"9 ~ '-/'-/é93 Digital Log Images: 50-103-20454-00 3S-06A: u:r:c... QO'3-ö'iS''ð ~ l¿.jLI'ð1 Digital Log Images: 50-103-20454-01 3S-08 3S-08A 3S-08B: dD3 -öd:;,l j dó3 -03"+ I d03 -043 Digital Log Im~ges: fÍ 1'-( ¿,¡éìS 1'-14 Q(P I I..{¿/ d 7- 50-103-20450-00, 01, 02 3S-14: UI.~ dÓ~-d!O it IL.¡¿/~O Digital Log Images: 50-103-20439-00 3S-15: ;)Ó8-CJSL.( -tI. 1'-/L/fJ'-I Digital Log Images: 50-103-20444-00 t 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom 1 CD Rom MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg í<'tt11't' £{soIOG P.I. Supervisor l 1 DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3S-06A KUPARUK RIV UNIT 3S-06A 2.03-0g~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV UNIT 3S-06A API Well Number 50-103-20454-01-00 Inspector Name: Jeff Jones Insp Num: mitlJ060829125056 Permit Number: 203-088-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S-06A Type Inj. w TVD 5596 IA 1540 2820 2800 2800 P.T. 2030880 TypeTest SPT Test psi 1399 OA 550 560 620 620 Interval 4YRTST PIF P ,,/ Tubing 2225 2225 2225 2225 Notes 1.1 BBLS diesel pumped. 1 well house inspected; no exceptions noted. NON-CONFIDENTIAL SCANNED SEP 0 8200B Wednesday, August 30, 2006 Page I of I . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 :'.. ;-1t ~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 C~ ~oô-o qj~ ,.§." oloA 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, RG240 I, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18,2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~f~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 10, 2004 1 ~Lo?;5 RE: MWD Fonnation Evaluation Logs 3S-06A, AK-MW-2419826 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-06A: Digital Log Images 50-103-20454-01 o?0 3- 0<6'6 1 CD Rom c 0/dfl-ill~'ð) ?:JI?0!ú0 c1·- \ t7\ ') V V-v'~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 5¡t~/d / ~ ~ tOc.'.:1 API No. 50-103-20454-01-00 Permit to Drill 2030880 Well Name/No. KUPARUK RIV UNIT 3S-06A Operator CONOCOPHILLlPS ALASKA INC MD 8579 ~- TVD 6142./ . ./ Completion Date 5/25/2003 Completion Status WAGIN ------~-- --------- REQUIRED INFORMATION Mud Log No Samples No - - -- -- ----. -------- -- -- - ---- - .-._----- DATA INFORMATION Types Electric or Other Logs Run: GRlReslDens-Neutron,SCMT Well Log Information: Log/ Data Type Electr Digital Dataset Med/Frmt Number Name Log Log Scale Media Run No ------- Rpt 0 Asc Directional Survey Final LIS Verification 3 Log Asc Directional Survey Final ED 0 11818 1:.15 V~rifir.~tinn [,1(. E lN~ "\ \..N { S~.D I{~r' 3 -- - ------ --~--- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y G> Daily History Received? Chips Received? 'Y7'"N-- Formation Tops Analysis ~. Received? - -------- --- ---- ------~ ---- --- Comments: - -- --- - ------- ~ - -- ------ ---- Compliance Reviewed By: Current Status WAGIN ~ '\ .CUIC Y ~ Directional SU~ (data taken from Logs Portion of Master Well Data Maint) .~ Interval OH/ Start Stop CH Received Comments 66018 8579 Open 6/2/2003 MWD 3052 8547 Open 7/24/2003 6601 8579 Open 6/2/2003 3052 8547 Open 7/24/2003 Sample Set Number Comments ~/N @yN -- Date: f ^ J",~ h-DC- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS wINS -t:ð ýýI¿AJA-~ 1~Operations Perf()rm~d: Abandon tJ.· ··$u~Pl3l1d 0 QpEõ!ratio,n.$hutd()WI10 . ..... Pë~o~atI3O . Va Hance ·OA~nularþisp:.O . ....... ... .....Alter¡Cäsing·.·. .D·~epair'vvèll·O . ><PIUQPerforations····O.. . ·sHi'r1ulaté·O···.. . ...... .... ......... ..... . ..0 YDal1geApprpyedPr(Jgraro ...... .[J Pull Tubing: 0 ···¡P~rf()räteN¢w P90I)O ...... ·8~'"êl1trr.$lJ$p~~dl3ø.VVen .[] 2. Operator Name: ·4. Current WeIlStätus:· 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ··[)eVelôP'!'~rt.[].. .. ExplOratory·· D · 203-088/ 3. Address: .. ~tratiQ~Pbib<O·serV¡èè·..0 6. API Number: P. O. Box 100360 50-103-20454-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 57' 3S-06A ) ) 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk Oil Pool Effective Depth measured 8579' feet 6142' feet 8401 feet 5993 feet Size MD Plugs (measured) Junk (measured) Total Depth measured true vertical true vertical Casing Structural Length TVD Burst Collapse 7" 3071' 8568' 2606' 6113' SURFACE PRODUCTION 3042' 8541' 9-5/8" Perforation depth: Measured depth: 8252-8282 RECEIVED MAY 11 '2.004- " 0·,\ & Gas Cons. Commission ~'as"a ~nc"orage true vertical depth: 5871-5895 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7943' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 507' 12. StiriHJlation orcementsqueezesumrnary: Intërvals treated. (measured) N/A Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average.Production or Injection Data Gas-Met Water-Bbl 1928 Casinq Pressure 700 700 TubinqPressure 2422 3467 13. Prior to wen operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 1193 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Wen Status after proposed work: OilD GasD WAG0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Daily Report of Well Operations _X WDSPLO Contact James T. Rodgers @ 659-7226 Printed Nam~ ~~. ert D~"stensen Signature rr~~ Title Phone Production Engineering Technician 659-7535 Date Form 10-404 Revised 2/2003 · f~S Blf:l "'~ t 1 ~nn,q~ SUBMIT IN DUPLICATE ') 3S-06A ) DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/02l04Commenced WAG EOR Injection ) ) ) ~o.3-Dß(3 \ I ~ \~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tll Avenue, Suite 100 Anchorage, Alaska June 02, 2003 RE: MWD Formation Evaluation Logs 3S-06A, AK-MW-24 1 9826 1 LDWG· formatted Disc with verification listing. API#: 50-103-20454-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 ~~I\Ir=.D Anchohl\~~"Mft~ ~m JUL 24 2003 Alaet<a Oit & Gas Cons. Commieeion \. ~ Date: Anct1Of1'!Je Signed: C).~--r:;~ULO " ') Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 25, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-06A (APD # 203-088) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3S-06A. 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 CPAI Drilling RT/skad RECE~VED JUL 0 2 Z003 AI k 0·\ & .... r ., CI·\I·"I'~"1ii.'S·I"tl as a I.' bas von~, ~H¡"o,l \,;1. Am.:horage OR\G\NAL ) STATE OF ALASKA ,) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U GINJ D 2. Operator Name: WINJ D WDSPL D Plugged D Abandoned D 20 AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2483' FNL, 915' FEL, Sec. 18, T12N, R8E, UM At Top Productive Horizon: 2544' FSL, 1154' FEL, Sec. 7, T12N, R8E, UM Total Depth: 2558' FNL, 1119' FEL, Sec. 7, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476344 y- TPI: x- 476103 y- Total Depth: x- 476138 y- 18. Directional Survey: Yes 0 NoD 21. Logs Run: GR/Res/Dens-Neutron, SCMT 22. CASING SIZE WT. PER FT. 30"x16" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3072' Surface 8569' 5993933 5998960 5999137 Zone-4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 8252' - 8282' MD 5871' - 5895' TVD 6 spf r-;:;r)~'~'þ ¡):~ri;)frl I' . r:T~: E .... \ " ¡:; ~ ;'_.::i~.2~.. ~ ~/ .~ç,:~~~-;~ } i _!~~=-_I '".--... ··-"-.--.n..::J 26. Date First Injection June 21, 2003 Date of Test Hours Tested Flow Tubing Casing Pressure press. 27. psi 24-Hour Rate -> Suspended D WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., 2< Þ or Aband.: Mayß 2003 6. Date Spudded: . May./'f, 2003 Æ b 7. Date TD Reached: May 15, 2003 8. KB Elevation (ft): RKB 28' / 56' AMSL 9. Plug Back Depth (MD + TVD): 8401' MD / 5993' TVD 10. Total Depth (MD + TVD): 8579' MD / 6142' TVD 11. Depth where SSSV set: Land Nipple @ 506' feet MD 19. Water Depth, if Offshore: N/A feet MSL HOLE SIZE 1b. Well Class: Development D Exploratory D Service 0 Stratigraphic Test D 12. Permit to Drill Number: 203-088 / 13. API Number: 50-103-20454-01 14. Well Name and Number: 3S-06A 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 380106 17. Land Use Permit: ALK 4623 20. Thickness of Permafrost: 1565' MD 42" 66 sx ArcticCrete CEMENTING RECORD AMOUNT PULLED JUL ü ¿ 7.\)~TJNÔ RJG' K A L 7" 510 sx AS Lite, 300 sx LiteCrete 300 sx Class G w/GasBlok 12.25" 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 7943' PACKER SET (MD) 7911' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A WATER-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL CORE DATA OIL GRAVITY - API (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". " E ~(~ ifE" ,-.",.. RE', .¡: .~J . '" j ~ U :j'.\ -"......,." JUL 0 2 7003 Form 10-407 Revised 2/2003 m~ [þ)Ù ¡~.. ~J~ NONE Alaska Oil & Gas Com~. Co:rh¡¡:,ssion Anchorage Submit in duplicate r 28. GEOLOGIC MARKERS ) NAME 29. } MD TVD FORMATION TESTS Top C Sand Top A Sand 8255' 8279.5' 5873' 5893' Include and briefly summa",e test 'osu#s. list intervals tested, and attach detailed SUpporting data as necessary. If no tests were conducted, state "None". N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Direcbonal SUrvey 31. I he,eby ceoily Ihat thelo_Ing is true and co,,,,,,, to tile best 01 my knoWledge. RE(~EIVE:D JUL 0 2 Z003 I, O·¡ &' 1f"~lt. Cons. Comrnission AlasÞ\Œft! OUi) Am:horage Printed ~~,. ~s Signa'u~-t ~ ~ . Title: f\:j·,v,,;:¡ K!Jparuk Drillina Team leaç!m: Contact: Scott Lowry @ 265-6869 General: This form is designed for sUbmitting a complete and COfrect well completion report and log on all types of lands and reases in Alaska. INSTRUCTIONS '/. Date~ Prepared by Sharon AI/suP-Drake lfem 1 a: ClaSSification of Service wells: Gas injection, water iniectlon, Water-Altemating_Gas Injection, Salt water dispoSal, water SUPply for Injection, observation, or Other. Multiple completion is denned as a well prOdUcing from more than one Pool With producbon from each poot completety segregated. Each segregated pooJ is a Completion. 'tem 4b: TP¡ (Top of PrOducing Interval). Item 8: the Kelly BUShing e/evatlon In feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. 'tem 20: ¡rue vertical thickness. Item 13: The API number rePOrted to AOGCC mUsl be t4 digits (ex: 50-029-20123-00-00). Item 22: Attached SUpplemental records for this well should show the details of any multiple stage Cemenbng and the location of the cementing tool. lIem 23: If this Well is completed for separale production from more than One Inlerval (multiple complelion), so state in Item 1, and in ilem 23 show Ihe Producing intervals for oniy the interval reported in item 26. (Submit a separale fonn for each additional interval to be separately prOdUced, Showing the dala pertinent to such Inlerval). Item 26: MethOd of Ope",tion: Rowing, Gasl/fI, ROd Pump, HYdraulic Pump, Submersible. Wafer Injection, Gas/njecbon, Shut-in, Other (exPlain). Form 10-407 Revised 2/2003 lIem 29: Usl all tesl Information. If none, stale 'None". Item 27: If no Cores taken, indicate "none". ORIGINAL ') ) ConocoPhHlipsAlaska O.perationsSummaryReport Moved Mud Pits, Ball Mill & Injection Skid from 3S-17A Moved Rig Off 3S-17A and Set In Over Well and Leveled Spotted Mud Pits Lay Herculite and Set In Ball Mill & Injection Skid & RU NU 20" Riser and PU Tools & Equipment in Cellar, Hooked Up Inner Connects Between Pits & Rig, Took on Spud Mud Into Pits at 21 :30 Hrs ACCEPTED RIG AT 21 :30 HRS 5/4/03 Cut & Slip 105' of Drlg Line, Adjusted Brakes, Inspect all Brake Linkage and Service Rotary Driveline Serviced Top Drive, Lube Torque Tube Rails, C/O Bad Dies in Gripper Held PJSM on PU BHA PU BHA #1, Orient & Upload MWD, Tagged Ice at 82' RU HES Slickline for Gyro Survey's Fill Hole & Check Riser & Flowlines for Leaks, Press Test Surface Mud Lines to 4,000 Psi Cleaned Out Conductor F/82' to 108', Spud Well & Drill 12 1/4" Hole from 108' to 181', ART 1/2 Hr POOH, PU Non Mag Welded Blade Stab & RIH Run Gyro at 181' Drill 12 1/4" Hole from 181' to 272', ART 1 Hr Run Gyro at 272' Drill from 272' to 315', ART .5 Hrs Unplugged Possum Belly & changed Out Shaker Screens, Shakers Overloading with Cuttings RE-Ran Gyro at 272', Gyro & MWD Matched Drill, Slide & Survey from 315' to 1,340' MOl 1,332' TVD, (1,025'), ART 2.77 Hrs, AST 2.98 Hrs, 25-30K WOB, 80 RPM's, 137 SPM, 400 Gpm, Off Btm Press, 1,000 psi, On Btm, 1,200 psi, Off Btm Torque 2K Ft#'s, On Btm 4.5K Ft#'s, Rot Wt 77K, Up Wt 78K, On WT 75K 0.25 DRILL OTHR SURFAC Changed Out Shaker Screens 12.00 DRILL DRLG SURFAC Drill, Slide & Survey from 1,340' to 2,452' MOl 2,250' TVD, (1,112') ART 2.7 Hrs, AST 5.3 Hrs, 30-45K WOB, 80 Rpm's, 167 Spm, 495 Gpm's, Off Btm Press 1,600 Psi, On Btm 1,800 Psi, Off Btm Torque 4K Ft#'s, On Btm 7K Ft#'s, Rot Wt 89K, PU Wt 100K, ON Wt 80K, 8.9 MW with 180 Vis 6.25 DRILL DRLG SURFAC Drill, Slide & Survey from 2,452' to 3,083' MOl 2,612' TVD, (631') ART 3.04 Hrs, AST .85 Hrs, 40-45K WOB, 90 Rpm's, 190 Spm, 550 Gpm's, Off Btm Press 1,800 Psi, On Btm 2,100 Psi, Off Btm Torque 5K Ft#'s, On Btm 8K Ft#'s, Rot Wt 90K, PU Wt 11 OK, ON Wt 88K, 9.1 MW with 160 Vis Circ Weighted Sweep, Had 50% increase in Cuttings, Pumped 2nd Wt'd Sweep and had 10-20% Increase, Circ Hole Clean, Circ a Total of 4 Btms Up, Circ at 600 Gpm at 2,200 Psi and 100 Rpms Monitored Well-Static, POOH to 500', Pulled 20K Over at 2,150' and 1,280', Dropped Down Thru And PU & Ck Ok No Other Problems POOH Fin POOH Standing Back HWDP, LD BHA #1 and Cleaned Rig Floor RU Nabors Csg Equipment and Franks fill Up Tool, Changed Out Elevator Bails Held PJSM with Csg & Rig Crew MU 95/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 77 Jts of 9 5/8" Csg, (Total of 79 Jts Ran 3071.73'), Landed Csg in Head, Landed Csg Legal Well Name: 38-06 Common Well Name: 38-06 Event Name: ROT - DRILLING Contractor Name: N 1268 @ ppco.com Rig Name: Nabors 7E8 Date From~ To Hours Code Sub Phase Code 5/4/2003 14:00 - 15:00 1.00 MOVE MOVE DEMOB 15:00 - 17:30 2.50 MOVE MOVE MOVE 17:30 - 18:30 1.00 MOVE MOVE RIGUP 18:30 - 20:30 2.00 MOVE RURD RIGUP 20:30 - 00:00 3.50 MOVE RURD RIG UP 5/5/2003 00:00 - 01 :30 1.50 RIGMNT RSRV RIGUP 01 :30 - 03:00 1.50 RIGMNT RSRV RIGUP 03:00 - 03: 15 0.25 DRILL SFTY SURFAC 03: 15 - 08:00 4.75 DRILL PULD SURFAC 08:00 - 09:00 1.00 DRILL SURV SURFAC 09:00 - 10:00 1.00 DRILL OTHR SURFAC 10:00 - 10:45 0.75 DRILL DRLG SURFAC 10:45 - 11 :15 0.50 DRILL TRIP SURFAC 11:15 -11:30 0.25 DRILL SURV SURFAC 11 :30 - 12:30 1.00 DRILL DRLG SURFAC 12:30 - 13:00 0.50 DRILL SURV SURFAC 13:00 - 13:30 0.50 DRILL DRLG SURFAC 13:30 - 14:00 0.50 DRILL OTHR SURFAC 14:00 - 14:15 0.25 DRILL SURV SURFAC 14:15 - 23:45 9.50 DRILL DRLG SURFAC 5/6/2003 23:45 - 00:00 00:00 - 12:00 12:00 - 18:15 18:15 - 20:45 2.50 DRILL CIRC SURFAC 20:45 - 00:00 3.25 DRILL TRIP SURFAC 5/7/2003 00:00 - 03: 15 3.25 DRILL TRIP SURFAC 03:15 - 05:00 1.75 CASE RURD SURFAC 05:00 - 05:15 0.25 CASE SFTY SURFAC 05:15 -10:45 5.50 CASE RUNC SURFAC Page 1 of 6 Start: 5/4/2003 Rig Release: Rig Number: Spud Date: 5/5/2003 End: Group: Description of Operations Printed: 6/3/2003 4:24: 11 PM ) ) Page 2 öf 6 ConocOPhillipsAlaska Operations Summary Report wI FS @ 3071.73', FC @ 2993.26'. No Problems RIH with Csg Circ 1 Btms Up & Reciprocated Pipe Thru Fill Up Tool, Staged Pump up to 6 Bpm at 370 Psi LD Franks Fill Up Tool & MU Dowell's Cement Head Cont to Circ & Cond Mud for Cementing, Lowered YP from 42 to 25, Circ and Reciprocated Pipe at 6 Bpm, Final Circ Press 285 Psi Held Safety Mtg with Dowell, APC & Rig Crew on Cementing Csg (Cont to Circ During Mtg) Turned Over to Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lines to 3,000 Psi, Pumped 45 bbls CW 100 Chem Wash at 8.3 ppg @ 6 Bpm @ 190 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 7.0 bpm @ 300 Psi with Red Dye in CW 100 Spacer, Mixed & Pumped 388.7 bbls, 510 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 200 Psi, ,Observe Nut Plug at Shaker Switched to Tail Cmt, Pumped 300 sxs (119.6 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.24 Yield,Pumped @ 7.0 Bpm @ 240 Psi, 0.75 CEMENTDISP SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Wash Water, Turned over to Rig, Rig Pumped 206.0 bbls of 9.1 ppg mud, Ave Disp Rate 7.0 bpm @ 640 Psi, Reciprocated Pipe Until Lead Cmt was at surface -Landed Csg, Slowed to 3 bpm @ 420 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 200 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 16:05 Hrs 5/7103, Check Floats & Held RD Cement Head and Lines, LD Landing Jt. Flushed Out Riser & Flowline, ND Riser NU 11" 5M Gen V Csg Head & Tbg Spool, Tested M/M Seals to 1,000 psi, Tested Ok, NU 135/8" 5M BOP Stack LD Csg Elevators & Changed Out Elevator Bails RU and Began Testing BOP's, Note John Spaulding with AOGCC Waived Witnessing of Test Tested BOP's, Choke Manifold & Valves to 250 psi Low, 5,000 Psi High, Annular to 250/3,500 psi, Changed Out Isolation Valve on Test Pump, Note: John Spaulding with AOGCC Waived Witnessing of Test, RD Test Tools and Install Wear Bushing PU & Stood Back 72 Jts of 5" DP Held PJSM, Cut & Slip 335' of Drilling Line, Adjust Break Band Rollers Serviced Top Drive PU BHA #2, Uploaded MWD and Oriented Held PJSM with Sperry Sun on Loading Radioactive Sources Loaded Radioactive Sources and TIH BHA #2 and HWDP to 928' TIH with BHA #2 PU 60 Jts 5" DP from Pipe Shed, Washed Down & Tagged TOC at 2,951' Circ Btms Up and Evened MW In & Out at 9.2 ppg RU & Tested 9 5/8" Csg to 2,500 Psi for 30 Min, Good Test Drilled Out Fit Collar at 2,993', Med Cmt in Shoe Trac, Fit Shoe at 3,072' and 20' of New Formation to 3,103' MDI 2,624' TVD Displaced 9.2 ppg Spud Mud with New 8.8 ppg LSND Mud RU & Performed LOT to 17.5 ppg EMW, 1,180 Psi with 8.8 ppg Mud Drilled 8 1/2" Hole from 3,103' to 3,182', ART 1/2 Hr Circ Btms Up & Performed Base Line Test for PWD Drill 8 1/2" Hole from 3,182' to 3,277' MDI 2,716' TVD (95'), ART 1 Hr, Legal Well Name: 3S-06 Common Well Name: 3S-06 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES Date From-To Hours Code Sub Phase Code 5/7/2003 05:15 - 10:45 5.50 CASE RUNC SURFAC 10:45 - 11 :30 0.75 CASE CIRC SURFAC 11 :30 - 12:00 0.50 CASE RURD SURFAC 12:00 - 13:30 1.50 CEMENTCIRC SURFAC 13:30 - 13:45 0.25 CEMENT SFTY SURFAC 13:45 - 15:30 1.75 CEMENT PUMP SURFAC 15:30 - 16:15 16:15 - 17:30 1.25 CEMENT RURD SURFAC 17:30 - 18:30 1.00 WELCTL NUND SURFAC 18:30 - 19:15 0.75 WELCTL NUND SURFAC 19:15 - 22:15 3.00 WELCTL NUND SURFAC 22:15 - 23:00 0.75 CASE RURD SURFAC 23:00 - 00:00 1.00 WELCTL BOPE SURFAC 5/8/2003 00:00 - 06:00 6.00 WELCTL BOPE SURFAC 06:00 - 09:00 3.00 DRILL PULD SURFAC 09:00 - 10:30 1.50 RIGMNT RSRV SURFAC 10:30 - 11 :00 0.50 RIGMNT RSRV SURFAC 11 :00 - 14:00 3.00 DRILL PULD SURFAC 14:00 - 14:15 0.25 DRILL SFTY SURFAC 14:15 - 14:45 0.50 DRILL TRIP SURFAC 14:45 - 17:00 2.25 DRILL TRIP SURFAC 17:00 - 18:00 1.00 DRILL CIRC SURFAC 18:00 - 18:45 0.75 CASE DEaT SURFAC 18:45 - 20:30 1.75 CEMENT DSHO SURFAC 20:30 - 21 :30 1.00 CEMENT CIRC SURFAC 21 :30 - 22:00 0.50 CEMENT LOT SURFAC 22:00 - 22:30 0.50 DRILL DRLG INTRM1 22:30 - 23:00 0.50 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL DRLG INTRM1 Start: 5/4/2003 Rig Release: Rig Number: Spud Date: 5/5/2003 End: Group: Description of Operations Printed: 6/3/2003 4:24: 11 PM ) ') ConocoPhillipsAlaska Operations Summary Report 10-12K WOB, 100 Rpm's, 172 Spm, 500 Gpm's, Off Btm Press 1,325 psi, On Btm 1,600 psi, Off Btm Torque 7K Ft#'s, On Btm 8K Ft#'s, Rot Wt 95K, Up Wt 125K, Dn Wt 73K, 8.8 ppg MW with 10.0 ppg ECD Drill, Slide & Survey from 3,277' to 4,691' MD/3,533' TVD (1,414') ART 7.2 Hrs, AST .89 Hrs, 10-15K WOB, 100 Rpm's, 185 Spm, 548 Gpm's, Off Btm Press 1,750 Psi, On Btm 2,000 Psi, Off Btm Torque 6.5K Ft#'s, On Btm 6K Ft#'s, Rot Wt 100K, PU Wt 130K, DN Wt 90K, 9.4 ppg MW with 11.7 ECD, Pumping Wt'd Sweeps 2.5# Over Mud Wt with Barafiber every 300' with Good Results 12.00 DRILL DRLG INTRM1 Drill, Slide & Survey from 4,691' to 6,011' MDI 4,297' TVD (1,320'), ART 6.83 Hrs, AST .38 Hrs, 10-15K WOB, 110 Rpm's, 185 Spm, 548 Gpm, Off Btm Press 2,300 PSi, On Btm 2,450 Psi, Off Btm Torque 8.5K Ft#'s, On Btm 9K, Rot Wt 112K, PU Wt 150K, DN Wt 105K, Top of C-40 Sand 5,670' MDI 4,104' TVD, Ave BGG 80 Units, Max Gas 1,075 Units, 10.1 ppg MW, Ave 12.2 ECD 12.00 DRILL DRLG INTRM1 Drill, Slide & Survey from 6,011' to 7,450' MDI 5,160' TVD (1,439'), ART 6.45 Hrs, AST 1.12 Hrs, 25-30K WOB, 110 Rpm's, 175 Spm, 520 Gpm, Off Btm Press 2,600 Psi, On Btm 3,000 Psi, Off Btm Torque 1 OK ft#'s, On Btm 10K Ft#'s, Rot Wt 120K, UP WT 175K, DN Wt 125, Raised Mw per Wt Up Schedule to 11.4 ppg, ECD Ave 13.5 ppg, Ave Bgg 60 Units 12.00 DRILL DRLG INTRM1 Drill, Slide & Survey from 7,450' to 8,475' MDI 5,766' TVD (1,025') ART 6.66 Hrs, AST 1.59 Hrs 15-25K WOB, 110 Rpm's, 168 Spm, 500 Gpm's, Off Btm Press 2,720 Psi, On Btm 3,000 Psi, Off Btm Torque 9.5K Ft#'s, On Btm 10K Ft#'s, Rot Wt 130K, PU Wt 178K, Dn Wt 123K, Raised Mw to 11.8 ppg per Wt Up Schedule, ECD Ave 13.8 ppg, Max Gas from HRZ 975 Units, Ave Bgg 250 Units, Pumped Wt'd Sweeps Every 3-400', Est Tops Morraine Sand 7,485' MD/5, 177' TVD, Top HRZ 8,145' MDI 5,568' TVD, Base of HRZ 8,349' MDI 5,691' TVD 1.50 DRILL DRLG INTRM1 Drilled from 8,475' to 8,605' MDI 5,846' TVD, (130') ART 1.5 Hrs, Top of K-1 8,530' MD/5,804' TVD 1.50 DRILL CIRC INTRM1 Circ Hole for Wiper Trip to Shoe, Circ Btms Up, Max Gas F/K-1 450 Units, Pumped 25 bbl WT'd Sweep & Circ Out, Very Little Back F/Sweep, Circ at 180 Spm, 525 Gpm, 3,030 Psi, 110 Rpm's, Init BGG Ave 250 Units, Final Bgg 110 Units, Initial ECD's 13.4 Final 13.2 ppg Precautionary Backreamed Out from 8,605' to 7,609' at 450 Gpm, 105 Rpm's When BGG Began Increasing Circ Btms Up at 7,609', Max Gas 1,500 Units, Circ Out Large Amount of Cuttings, Circ Till Clean at Shakers & Gas Down to 200 Units, ECD Up to 13.6, Down to 13.1 after Btms Up Fin Backreaming Out from 7,609' to 7,232', to Above Morraine Sand with No Problems, BGG 300 Units Circ Btms Up, Max Gas 500 Units, Gas Dn to 250 Units Monitored Well-Static, POOH to 2,993' with No Problems Serviced Top Drive and Cleaned Rig Floor TIH, Washed 90' to Btm with No Problems Circ Btms Up After Wiper Trip, Max Gas 1,100 Units, Circ Wt'd Sweep Around & Circ Clean, Circ at 500 Gpm, 2,800 Psi at 110 Rpm's, Final ECD 12.8 ppg Drill from 8,605' to 8,907' MDI 6,030' TVD (302') T.D., ART 3.06 Hrs, AST -0-, Control Drilled KUP "C" Sand @ 1 OO'/Hr For Logs, 20-25K WOB, 100 Rpm's Top of KUP "C" at 8,651' MDI 5,873' TVD, Max Gas 465 Units, Dropped Out to Ave 200 Units, With 11.8 ppg MW at 500 Gpm, 3,000 Psi Ave 13.0 ECD and No Mud Loss, at TD Rot WT 143K, Legal Well Name: 3S-06 Common Well Name: 3S-06 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES Date From - To Hours Code Sub Phase Code 5/8/2003 23:00 - 00:00 1.00 DRILL DRLG INTRM1 5/9/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 5/10/2003 00:00 - 12:00 12:00 - 00:00 5/11/2003 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:45 1.75 DRILL REAM INTRM1 04:45 - 05: 15 0.50 DRILL CIRC INTRM1 05:15 - 06:00 0.75 DRILL REAM INTRM1 06:00 - 06:30 0.50 DRILL CIRC INTRM1 06:30 - 10:00 3.50 DRILL TRIP INTRM1 10:00 - 11 :00 1.00 RIGMNT RSRV INTRM1 11 :00 - 15:00 4.00 DRILL DRLG INTRM1 15:00 - 16:30 1.50 DRILL CIRC INTRM1 16:30 - 20:30 4.00 DRILL DRLG INTRM1 Page 30f 6 Start: 5/4/2003 Rig Release: Rig Number: Spud Date: 5/5/2003 End: Group: Description of Operations· . Printed: 6/3/2003 4:24: 11 PM ) ) Page 4 016 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 3S-06 Common Well Name: 3S-06 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors YES Date From ~ To Hours Code Sub Phase Code 5/11/2003 16:30 - 20:30 4.00 DRILL DRLG INTRM1 20:30 - 21 :30 1.00 DRILL CIRC INTRM1 21 :30 - 00:00 2.50 DRILL TRIP INTRM1 5/12/2003 00:00 - 04:00 4.00 DRILL TRIP INTRM1 04:00 - 04:15 0.25 DRILL SFTY INTRM1 04:15 - 07:30 3.25 DRILL TRIP INTRM1 07:30 - 07:45 0.25 ABANDI\ SFTY INTRM1 07:45 - 10:00 2.25 ABANDI\ PULD INTRM1 10:00 - 13:15 3.25 ABANDI\ TRIP INTRM1 13:15 - 15:15 2.00 ABANDI\ CIRC INTRM1 15:15 - 17:15 2.00 ABANDI\ CIRC INTRM1 17:15 - 17:30 0.25 ABANDI\ SFTY INTRM1 17:30 - 18:15 0.75 CEMENT PUMP INTRM1 18:15 - 19:00 0.75 ABANDI\ TRIP INTRM1 19:00 - 21 :00 2.00 ABANDI\ CIRC INTRM1 21 :00 - 21 :30 0.50 ABANDI\ TRIP INTRM1 21:30 - 22:15 0.75 ABANDI\ CIRC INTRM1 22:15 - 22:30 0.25 ABANDI\ TRIP INTRM1 22:30 - 23: 15 0.75 ABANDI\ CIRC INTRM1 23:15 - 00:00 0.75 CEMENT PUMP INTRM1 5/13/2003 0.75 ABANDI\ TRIP 1.25 ABANDI\ CIRC 4.00 ABANDI\ TRIP 0.75 ABANDI\ RURD 1.75 ABANDI\ PULD 0.50 ABANDI\ RURD 1.75 RIGMNT RSRV 0.75 WELCTL BOPE 3.75 WELCTL BOPE ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN 00:00 - 00:45 00:45 - 02:00 02:00 - 06:00 06:00 - 06:45 06:45 - 08:30 08:30 - 09:00 09:00 - 10:45 10:45 - 11 :30 11:30-15:15 15:15 - 16:00 0.75 WELCTL BOPE ABANDN Start: 5/4/2003 Rig Release: Rig Number: Spud Date: 5/5/2003 End: Group: Description of Operations PU Wt 200K, Dn Wt 118K, Off Btm Torque 15K Ft#'s, On Btm 14.5K Ft#'s. Decision was made to Sidetrack Well Pumped Weighted Sweep & Circ Out with Very Little Change in Cuttings, Circ Btms Up Gas Down from 250 Units to 115, ECD from 13.1 to 12.9, Circ at 500 Gpm at 2,450 psi Monitored Well-Static, POOH to 7,300' with No Problems, Pumped Dry Job & Cont POOH to 6,573', No Problems Cont POOH, Monitored Well @ Shoe & BHA-Static, POOH, Stood Back HWDP, LD 1 Flex DC & Stab Held PJSM with Sperry Sun on Removing Radioactive Sources Removed Radioactive Sources, Downloaded MWD and LD BHA #2 Held PJSM on PU 3 1/2" Tbg Stinger MU 3 1/2" 9.3# L-80 Tbg Stinger & RIH to 947', Changed Out Elevators TIH with 3 1/2" Stinger on 5" DP to 8,907' with No Problems Circ & Cond Mud for Setting Abandonment Plug, Circ at 425 Gpm at 1 ,100 Psi, Btm's up gas 160 units Circ & Cond Mud for Setting Abandonment Plug, Circ at 425 Gpm at 1,100 Psi, Circ Hole While W.O. Dowell, Dowell was Held Up Due to Rig Move in Deadhorse Held PJSM with Dowell & Rig Crew on Setting Cement Plugs RU Dowell, Pumped 5 bbls of 8.3 ppg CW 100, Tested Lines to 3,000 Psi & Ck Ok, Pumped Add 5 bbls 8.3 ppg CW 100 Followed by 43.3 bbls, 210 sxs of Class G Cmt W/Add @ 15.8 ppg & 1.16 Yield, Pumped 1.5 bbls of CW 100 Behind, Turned Over to Rig And Displaced Cmt with 136 bbls of 11.8 ppg Mud to Balance Plug, CI P @ 18:05 Hrs Est T.O.C @ 8,451' POOH Slow to 8,158' Circ Btms Up from 8,158', Had 30 bbls of Cement Contaminated Mud Back, Circ Hole and Evened MW to 11.6 ppg In & Out, POOH to 7,597' Circ Btms Up with 11.6 ppg MW In & Out, Circ at 420 Gpm at 875 psi, Pumped and Spotted 35 bb112.8 ppg Hi Vis Pill from 7,597' to 7,300' POOH to 7,315' Circ Btms Up at 7,315', No Sign of Wt'd Sweep at Btms up, 11.6 MW In & Out, Dowell Batch Mixed Kick-Off Plug RU Dowell, Pumped 5 bbls 8.3 ppg CW1 00 Spacer, Press tested Lines to 3,000 Psi, Pumped 10 bbls Add CW100, Pumped 58.2 bbls, 327 SXS of Class G Cmt @ 17.0 ppg and 1.00 Yield with Add, Follow with 3.5 bbls CW1 00, Turned over to Rig Pump and Displaced Cement with 103 bbls of 11.6 ppg Mud to Balance Plug, CI P @ 23:55 Hrs, Est TOC @ 6,700', RD Cement Line POOH to 6497'. Circulated and conditioned mud. POOH to tubing tail string. Cleaned off rig floor and rigged up to lay down tubing. Laid down tubing tail. Rigged down tubing tongs and elevators. Slipped and cut drilling line. Changed saver sub on top drive. Pulled wear bushing and set test plug. Tested BOP's, Choke Manifold & Valves to 250 psi Low, 5,000 Psi High, Annular to 250/3,500 psi, Note: Jeff Jones with AOGCC Waived Witnessing of Test. Pulled test plug and set wear bushing. Printed: 6/3/2003 4:24: 11 PM ) ) Page 5 of 6 ConocoPhillips Alaska Operations Summary Report Picked up and made up BHA loaded source in MWD. RIH to 6470', (CBU at casing shoe). Washed from 6470' to top of cement @ 6493', Dressed cement plug with 20,000 WOB to 6580'. Drill and kicked off well, time drill with oreinted motor from 6580' to 6601'. WOB 25 - 35 K, GPM 500. Up Wt. 235 K Down Wt. 105 K Rot Wt. 135 K. Torque on Btm. 14,000 Off Btm. 14,000 Ft. Lbs. Continue to kicked off well from 6601' to 8080' (Showing good signs of seperation from old well after 6601'). WOB 25 - 35 K, RPM 100, GPM 500. Up Wt. 235 K Down Wt. 105 K Rot Wt. 135 K. Torque on Btm. 14,000 Off Btm. 14,000 Ft. Lbs. ART 10.68 Hrs. AST 6.96 Hrs. Drilled 8.5" Directional hole from 8080' to 8221'. WOB 25 -35 K, TD RPM 100, GPM 500, PP 2400 PSI. Up Wt. 270 K, Down 115 K, Rot. 145 K. Torque On Btm. 17,000 Off Btm.16,000 Ft. Lbs. ART 1.23 Hrs. Circulated and lowered ECD to 13.1 EMW while monitoring for losses, Max gas 1185 I U. Drilled 8.5" Directional hole from 8221' to 8579'. WOB 25 -35 K, TD RPM 100, GPM 500, PP 2400 PSI. Up Wt. 270 K, Down 115 K, Rot. 145 K. Torque On Btm. 17,000 Off Btm.16,000 Ft. Lbs. ART 3.4 Hrs. Circulated hole clean with weighted sweep. POOH to 6198', Pumped out from 8579' to 7515'. RIH to 8489' and washed to 8579' No Problems. Circulated hole clean with weighted sweep. Max trip gas 1950 units. POOH SLM to 950'. Backreamed from 4990' to 4780', Dowell Displaced cement, 331.5 bbls of 8.5 ppg seawater pumped at an ave rate of 6 bpm at 1,000 psi at 285 bbls slowed rate to 4 bpm at 975 psi for 60 bbls then to 7.0 bpm at 1,400 psi until 305 bbls slowed rate to 4 BPM at 1900 psi & bumped plug w/ total of 331.5 bbls, Bumped plug w/ 2,400 psi, Checked Floats & Held, Bled back 2.75 bbls for a total of 328.75 total bbls displaced (Calculated 323 bbls), CIP @ 00:36 hrs 5/17/03, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. Good returns thooughout job. Rigged down cement head and flushed stack. Changed out bales and picked up tubing elevator. I nstalled and tested packoff. Rigged up to run completion. PJSM. PU and RIH with completion on 251 Jts 3 1/2" 9.3# L 80 EUE tubing to 7943'. PJSM, Rig & test 7" casing to 3500 psi f/ 30 min. -OK Perform injecttivity test on 7" x 9-5/8" annulus, EMW of 16.5 ppg using 11.8 ppg mud with 640 psi @ 9-5/8" shoe 3071' MD & 2606' TVD Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 7911.19', Slowly pressure 3-1/2" tbg. to 2500 psi. Wait 5 min. (Noticed packer stroke at 1500 psi- Noticed a 1500 psi drop in pressure at 2500 psi, indication of PBR shear), Bleed pressure to zero. Slack off to 40K (20K on pkr) to comfirm packer set, then pressure tbg string to 3000 psi and hold 5 min. Bleed pressure to 1500 psi. PU to 65K (PBR sheared), Slack back off to 40K. Check & tag locator w/ 15K. Pressure tbg to 3600 psi to shear ball seat- Very good indication of ball sheared. Bleed off all pressure. 0.50 CMPL TN SOHO CMPL TN Pull jt. #252 out of hole (pulling 12' out of PBR). M/U 3-1/2" FMC tubing hanger on jt. # 251, Use jt. #252 as landing jt., RIH & land tubing wI Legal Well Name: 3S-06 Common Well Name: 3S-06 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES Date From - To Hours Code Sub Phase Code 5/13/2003 16:00 - 20:00 4.00 DRILL PULD PROD 20:00 - 22:45 2.75 DRILL TRIP PROD 22:45 - 00:00 1.25 DRILL REAM PROD 5/14/2003 00:00 - 05:00 5.00 DRILL DRLG PROD 05:00 - 00:00 19.00 DRILL DRLG PROD 5/15/2003 00:00 - 01 :15 1.25 DRILL DRLG PROD 01 :15 - 03:00 1.75 DRILL CIRC PROD 03:00 - 08:00 5.00 DRILL DRLG PROD 08:00 - 10:00 2.00 DRILL CIRC PROD 10:00 - 13:00 3.00 DRILL WIPR PROD 13:00 - 14:15 1.25 DRILL WIPR PROD 14:15 - 17:30 3.25 DRILL CIRC PROD 17:30 - 00:00 6.50 DRILL TRIP PROD 5/17/2003 00:00 - 00:45 0.75 CEMENT DISP PROD 00:45 - 01 :30 0.75 CEMENT PULD PROD 01 :30 - 02:30 1.00 CASE RURD PROD 02:30 - 03:30 1.00 CASE DEaT PROD 03:30 - 04:30 1.00 CMPL TN RURD PROD 04:30 - 12:30 8.00 CMPL TN RUNT PROD 12:30 - 14:00 1.50 CMPL TN DEaT PROD 14:00 - 14:30 0.50 FRMTST OTHR CMPL TN 14:30 - 15:30 1.00 CMPL TN PCKR CMPL TN 15:30 - 16:00 Start: 5/4/2003 Rig Release: Rig Number: Spud Date: 5/5/2003 End: Group: Description of Operations Printed: 6/3/2003 4:24: 11 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From- To 5/17/2003 15:30 - 16:00 16:00 - 17:00 ) ) Page 6 ot6 . ConocoPhillipsAlaska Operations Summary.Report 3S-06 3S-06 ROT - DRILLING N1268@ppco.com Nabors 7ES H Sub ours Code Code Phase Start: Rig Release: Rig Number: 5/4/2003 Spud Date: 5/5/2003 End: Group: Description of Operations 0.50 CMPL TN SOHO CMPL TN locator 2' above fully located in PBR, RILDS. Rig pumping lines 1.00 CMPL TN DEQT CMPL TN Pressure 3-1/2" tubing to 3500 psi f/ 15 min. Bleed pressure to 1500 psi. Pressure 3-1/2" x 7" annulus to 3500 psi f/ 15 min (Pressure on tubing increase to 2000 psi). Bleed tbg pressure to zero. (RP valve did not shear until ann. press. increased to 3700 psi). Bleeding both sides to zero. All test were charted. Laid down landing Jt. and pumped 200 Bbl. water flush down 9 5/8" X 7" annulus. Installed 2 way check valve. PJSM Nippled down BOP. Nippled up and tested tree 250/5000 PSI. Pumped 60 Bbls. Diesel in 9 5/8" X 7" for freeze protection. Pulled 2 way check valve and installed mousehole. Pumped 120 Bbls. diesel freeze protection with Little Red while laying down DP. Laid down excess drill pipe from derrick. Rigged down Little Red, installed back pressure valve and secured well. Finish Laying down excess drill pipe from derrick. Slip and cut 74' drilling line, serviced rig and top drive. 17:00 - 17:30 0.50 CMPL TN RURD CMPL TN 17:30 - 19:30 2.00 CMPL TN NUND CMPL TN 19:30 - 21 :00 1.50 CMPL TN NUND CMPL TN 21 :00 - 21 :30 0.50 CMPL TN OTHR CMPL TN 21 :30 - 00:00 2.50 CMPL TN FRZP CMPL TN 5/18/2003 00:00 - 00:30 0.50 CMPL TN PULL CMPL TN 00:30 - 01 :30 1.00 CMPL TN FRZP CMPL TN 01 :30 - 03:30 2.00 CMPL TN PULL CMPL TN 03:30 - 05:30 2.00 RIGMNT RSRV CMPL TN RIG RELEASED @ 0530 HRS. 05/18/03 Printed: 6/3/2003 4:24:11 PM Date 05/22/03 05/23/03 05/25/03 ) ') 3S-06A Event History Comment DRIFTED TBG WI 22' X 2.625" DUMMY GUN. TAGGED FILL @ 8376' RKB. INSTALLED DV @ 7812' RKB. PT TBG & CSG TO 3000#. GOOD TESTS. [TAG, GLV, PT TBG-CSG] RAN SCMT CEMENT BOND LOG FROM 8347' TO 7850'. FOUND GOOD QUALITY CEMENT BOND FROM 8347' TO 7935' (TBG TAIL) [CEMENT-POLY SQUEEZE] PERFORATED: 8252' - 8282',6 SPF POWERJET, SBHP AT 8267'= 3411.6 PSIA, TEMP= 160.0 DEGF, AT 8067' PRESS= 3339.6 PSIA, TEMP= 151.9 DEGF [PERF] Page 1 of 1 6/5/2003 ) ) 29-May-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-06A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,601.87' MD Window / Kickoff Survey: 6,644.18 I MD (if applicable) Projected Survey: 8,579.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager d.03-D ~ß RECEIVED Attachment(s) JUN 0 2 2003 AJIIka Oit & Gel Cool. CoRIniIeim R AIdOIa.,e j~~. &'(- ,,/ Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 3S-06A Job No. AKZZ0002419826, Surveyed: 15 May, 2003 Survey Report 28 May, 2003 Your Ref: API 501032045401 Surface Coordinates: 5993932.58 N, 476344.38 E (70° 23' 40.3972" N, 150011'32.8940" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993932.58 N, 23655.62 W (Grid) Kelly Bushing: 56.60ft above Mean Sea Level Elevation relative to Project V Reference: 56.60ft Elevation relative to Project V Reference: 56.60ft Spe!r"I'Y-SUl'1 DRILLING SeRVices A Halliburton Company DEFN TIVE - .~. Survey Ref: svy2042 Sperry-Sun Drilling Services , Survey Report for Kuparuk 3S Pad· 3S-06A Your Ref: API 501032045401 Job No. AKZZ0002419826, Surveyed: 15 May, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6601.87 51.250 353.660 4593.39 4649.99 3938.97 N 414.93 W 5997872.85 N 475941.92 E 1525.08 Tie On Point 6644.18 51.060 351 .460 4619.93 4676.53 3971.64 N 419.19W 5997905.53 N 475937.76 E 4.074 1537.01 Window Point 6695.53 50.290 354.050 4652.48 4709.08 4011.04 N 424.21 W 5997944.94 N 475932.87 E 4.180 1551.51 6789.71 48.180 359.870 4714.00 4770.60 4082.21 N 428.04 W 5998016.12 N 475929.26 E 5.187 1582.27 6882.72 46.800 5.280 4776.87 4833.4 7 4150.65 N 425.00 W 5998084.56 N 475932.51 E 4.536 1617.77 - 6976.75 45.410 9.800 4842.08 4898.68 4217.80 N 416.15 W 5998151.67 N 475941.58 E 3.766 1657.74 ~' 7073.89 44.180 9.820 4911.01 4967.61 4285.24 N 404.49 W 5998219.07 N 475953.46 E 1 .266 1700.32 7168.32 43.550 9.000 4979.10 5035.70 4349.79 N 393.78 W 5998283.59 N 475964.36 E 0.898 1740.67 7260.99 42.910 9.400 5046.62 5103.22 4412.45 N 383.64 W 5998346.22 N 475974.71 E 0.751 1779.62 7357.53 41.770 11.540 5117.98 5174.58 4476.38 N 371.84 W 5998410.11 N 475986.71 E 1.903 1820.64 7450.23 41.640 11.530 5187.19 5243.79 4536.81 N 359.50 W 5998470.50 N 475999.23 E 0.140 1860.44 7545.33 41.090 11.860 5258.56 5315.16 4598.35 N 346.77 W 5998532.00 N 476012.17 E 0.622 1901.14 7637.31 40.770 12.600 5328.05 5384.65 4657.24 N 334.00 W 5998590.85 N 476025.12 E 0.632 1940.58 7731.24 39.960 13.100 5399.62 5456.22 4716.55 N 320.48 W 5998650.12 N 476038.83 E 0.929 1980.90 7823.93 38.830 11.940 5471.25 5527.85 4773.97 N 307.72 W 5998707.50 N 476051.77 E 1 .455 2019.63 7919.33 37.990 11.750 5546.00 5602.60 4831.98 N 295.55 W 5998765.47 N 476064.12 E 0.889 2058.13 8012.63 37.010 11.350 5620.02 5676.62 4887.63 N 284.18 W 5998821.08 N 476075.67 E 1.082 2094.80 8104.29 35.980 10.950 5693.71 5750.31 4941.11 N 273.63 W ·5998874.53 N 476086.39 E 1.153 2129.71 8197.69 35.370 11 .100 5769.58 5826.18 4994.58 N 263.22 W 5998927.96 N 476096.97 E 0.660 2164.49 8292.05 34.940 10.720 5846.73 5903.33 5047.92 N 252.93 W 5998981.28 N 476107.42 E 0.511 2199.10 8384.55 34.230 10.310 5922.88 5979.48 5099.55 N 243.35 W 5999032.87 N 476117.17 E 0.808 2232.27 8480.11 33.040 10.870 6002.44 6059.04 5151.58 N 233.62 W 5999084.87 N 476127.06 E 1.287 2265.75 .'-. 8510.84 32.810 11.230 6028.24 6084.84 5167.97 N 230.42 W 5999101.25 N 476130.31 E 0.983 2276.42 8579.00 32.810 11.230 6085.52 6142.12 5204.20 N 223.23 W 5999137.46 N 476137.62 E 0.000 2300.11 Projected Survey ~ All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.6' MSL. Northings and Eastings are relative to 2483' FNL & 915' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2483' FNL & 915' FEL and calculated along an Azimuth of 61.340° (True). Magnetic Decfination at Surface is 25.1 07°(05-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8579.00ft., The Bottom Hole Displacement is 5208.98ft., in the Direction of 357.544° (True). 28 May, 2003 - 9:16 Page 20f3 DrillQuest 3.03.02.005 .... Western North Slope Comments Measured Depth (ft) '- 6601.87 6644.18 8579.00 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-06A Your Ref: API 501032045401 Job No. AKZZ0002419826, Surveyed: 15 May, 2003 ConocoPhiflips Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4649.99 4676.53 6142.12 Comment 3938.97 N 3971.64 N 5204.20 N 414.93 W 419.19 W 223.23 W ~ Tie On Point Window Point Projected Survey Survey tool program for 3S-06A From Measured Vertical Depth Depth (ft) (ft) 0.00 179.00 28 May, 2003 - 9:16 0.00 179.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 179.00 8579.00 179.00 Tolerable Gyro (35-06) 6142.12 AK-6 BP _IFR-AK (35-06) ~-~,.. Page 3 of3 DrillQuest 3.03.02.005 ') ') 29-May-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-06A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 6,601.87' MD Window / Kickoff Survey: 6,644.18' MD (if applicable) Projected Survey: 8,579.00' MD Please call me at 273-3545 if you have any questions or concerns. Reg a rd s dvO 3-D ?Y l:> RECEIVED William T. Allen Survey Manager JUN 0 2 2003 AI_ Oil & G8& Con$. Con1118eion Aa1CthWgð 'B~~v <ð. &^-Cf- Attachment(s) Sperry-Sun Drilling Services ~. Western North Slope ConocoPhillips Kuparuk 35 Pad 35-06A MWD Job No. AKMW0002419826, Surveyed: 15 May, 2003 Survey Report 28 May, 2003 -- Your Ref: API 501032045401 Surface Coordinates: 5993932.58 N, 476344.38 E (700 23' 40.3972" N, 1500 11' 32.8940" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993932.58 N, 23655.62 W (Grid) Kelly Bushing: 56.6Oft above Mean Sea Level Elevation relative to Project V Reference: 56. 60ft Elevation relative to Project V Reference: 56. 60ft spe'-''-'y-sul! DRIL.L.ING seRVIc:es A Halliburton Company SlItvey Ref: 5vy2044 oc oc a .\0 CJ ~ DrillQuest 3.03.02.005 Page 20f3 28 May, 2003 - 9:26 ------------- Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-06A MWD Your Ref: AP/501032045401 Job No. AKMW0002419826, Surveyed: 15 May, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6601.87 51.250 354.410 4593.44 4650.04 3943.32 N 374.99 W 5997877.06 N 475981.87 E 1562.21 Tie On Point 6644.18 51.060 352.490 4619.98 4676.58 3976.05 N 378.75 W 5997909.81 N 475978.22 E 3.563 1574.61 Window Point 6695.53 50.290 353.740 4652.52 4709.12 4015.49 N 383.51 W 5997949.26 N 475973.58 E 2.407 1589.35 6789.71 48.180 359.980 4714.05 4770.65 4086.64 N 387.48 W 5998020.42 N 475969.84 E 5.494 1619.99 6882.72 46.800 5.350 4776.92 4833.52 4155.08 N 384.33 W 5998088.85 N 475973.20 E 4.506 1655.58 ~ 6976.75 45.410 9.760 4842.13 4898.73 4222.22 N 375.45 W 5998155.97 N 475982.29 E 3.688 1695.57 7073.89 44.180 9.920 4911.06 4967.66 4289.65 N 363.76 W 5998223.36 N 475994.20 E 1 .272 1738.18 7168.32 43.550 8.590 4979.15 5035.75 4354.23 N 353.23 W 5998287.91 N 476004.93 E 1.182 1778.39 7260.99 42.910 9.290 5046.67 5103.27 4416.93 N 343.37 W 5998350.58 N 476014.99 E 0.863 1817.11 7357.53 41.770 11.870 5118.03 5174.63 4480.84 N 331.45 W 5998414.45 N 476027.11 E 2.153 1858.22 7450.23 41.640 11.710 5187.24 5243.84 4541.21 N 318.85 W 5998474.78 N 476039.91 E 0.181 1898.24 7545.33 41.090 12.130 5258.61 5315.21 4602.71 N 305.87 W 5998536.23 N 476053.08 E 0.648 1939.12 7637.31 40.770 13.190 5328.11 5384.71 4661.50 N 292.66 W 5998594.98 N 476066.47 E 0.831 1978.90 7731.24 39.960 13.950 5399.67 5456.27 4720.63 N 278.39 W 5998654.07 N 476080.93 E 1.009 2019.78 7823.93 38.830 12.430 5471.30 5527.90 4777.90 N 264.96 W 5998711.30 N 476094.54 E 1.603 2059.04 7919.33 37.990 13.070 5546.06 5602.66 4835.71 N 251.88 W 5998769.06 N 476107.80 E 0.974 2098.24 8012.63 37.010 12.140 5620.08 5676.68 4891.14 N 239.48 W 5998824.45 N 476120.38 E 1.213 2135.70 8104.29 35.980 11.610 5693.76 5750.36 4944.48 N 228.26 W . 5998877.76 N 476131.77 E 1.175 2171.13 8197.69 35.370 12.030 5769.63 5826.23 4997.80 N 217.11 W 5998931.04 N 476143.09 E 0.704 2206.49 8292.05 34.940 11.380 5846.78 5903.38 5051.00 N 206.08 W 5998984.20 N 476154.28 E 0.604 2241.68 8384.55 34.230 10.600 5922.94 5979.54 5102.54 N 196.07 W 5999035.71 N 476164.46 E 0.905 2275.19 -- 8480.11 33.040 10.700 6002.50 6059.10 5154.56 N 186.29 W 5999087.70 N 476174.40 E 1.247 2308.72 8510.84 32.810 11 .420 6028.29 6084.89 5170.95 N 183.09 W 5999104.08 N 476177.66 E 1.477 2319.39 8579.00 32.810 11 .420 6085.58 6142.18 5207.15 N 175.77 W 5999140.26 N 476185.09 E 0.000 2343.17 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.6' MSL. Northings and Eastings are relative to 2483' FNL & 915' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2483' FNL & 915' FEL and calculated along an Azimuth of 61.340° (True). Magnetic Declination at Surface is 25.1 OT(05-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8579.00ft., The Bottom Hole Displacement is 5210.12ft., in the Direction of 358.067° (True). "'-- Western North Slope Comments Measured Depth (ft) ~. 6601.87 6644.18 8579.00 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-06A MWD Your Ref: API 501032045401 Job No. AKMW0002419826, Surveyed: 15 May, 2003 ConocoPhil/ips Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4650.04 4676.58 6142.18 Comment 3943.32 N 3976.05 N 5207.15 N Tie On Point Window Point Projected Survey 374.99 W 378.75 W 175.77 W Survey tool program for 3S-06A MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 179.00 ~. 28 May, 2003 - 9:26 0.00 179.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 179.00 8579.00 179.00 Tolerable Gyro (35-06 MWD) 6142.18 MWD Magnetic (3S-06 MWD) ------------ Page 3 0'3 DrillQuest 3.03.02.005 ') MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission ~ 7)/) TO: Randy Ruedrich Vi:)) DATE: June 27,2003 Commissioner .. i -'I ,--::;) . 1(Il\t¡,7SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder \ «1'[ Conoco Phillips P.I. Supervisor 3S Pad KRU FROM: Chuck Scheve Petroleum Inspector NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 3S-06A Type Inj. S TVD. 5596 Tubing 2050 2050 2050 2050 Interval I P.TD. 203-088 Type test P Test psi 1399 Casi ng 800 2000 1975 1975 P/F f Notes: Well 3S-17A Type Inj. S TVD. 5655 Tubing 2350 2350 2350 2350 Interval I P.T.D. 203-080 Type test P Test psi 1414 Casing 0 2100 2050 2050 P/F f Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casi ng P/F Notes: Well Type Inj. T.VD. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. TVD. Tubing Interval P.TD. Type test Test psi Casi ng P/F Notes: Type INJ. Fluid Codes Type Test I nterv al F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3S Pad in the Kuparuk River Field and witnessed the initial MIT on wells 3S-06 and 3S- 17. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with both wells demonstrating good mechanical integrity. M.I.T.ls performed: ~ Attachments: Number of Failures: º Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. 2003-0627 _MIT _KRU_3S-17 A_cs.xls 7/11/2003 I l } AIASIiA OILA5D GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR ~lJ~ìJŒ )1 ~l~~~~~ 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Field 3S-06A ConocoPhillips Alaska, Inc. Permit No: 203-088 Surface Location: 2483' FNL, 915' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 2609' FNL, 1104' FEL, Sec. 7, T12N, R8E, UM Dear Mr:' Thomas: Enclosed is the approved application for permit to drill the above referenced development 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, ~~tA ~and~ ~uedrich Commissioner BY ORDER OF THE COMMISSION DATED this IS" day of May, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section y'~..) ConocoPhillips '\ , Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com May 12, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Sidetrack well, 3S-06A p,.,,~ W4~ ConocoPhillips Alaska. Inc. hereby files this Application for Permit to Drill sidetrack well 3S-06A. i":J·e.LI-...,.-þ Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). Dear Commissioner: If you have any questions or require any further information, please contact Scott Lowry at 265-6869. . 17 Sine y, ,./ " // £' ;r¿/~ ~ 7i~ tt.~~> Randy Thomas ~ GKA Drilling Team Leader RECEIVED MAY 1 2 2003 Alaska Oil & Gas Cons. Commission Anchorage , OR:~G:NAL ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ~16 1a. Type of Work: Drill0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Redrill U 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surtace:2483'FNL,915'FEL,Sec. 18, T12N, R8E, UM Top of Productive Horizon: 2514' FSL, 1168' FEL, Sec. 7, T12N, R8E, UM Total Depth: 2609' FNL, 1104' FEL, Sec. 7, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surtace:x- 476344 16. Deviated wells: Kickoff depth: 7000 18. Casing Program Size Hole Casing y- 5993933 ft. Maximum Hole Angle: Weight Specifications Grade Coupling 8.5" L-80 BTC-M 7" 26# PERMIT TO DRILL 20 AAC 25.005 ExploratoryU Development Oil U Multiple Zone D Service 0 Development Gas D Single Zone 0 5. Bond: 1..0'. Blanket U Single Well 11. Well Name and Number: Bond No. þb 59-52-180 3S-06A 6. Proposed Depth: 12. Field/Pool(s): MD: 8557' TVD: 6119' Kuparuk River Field 7. Property Designation: A1>lr ~380106¿P 8. Land Use Permit: Kuparuk River Pool 13. Approximate Spud Date: 5/13/2003 ADL 4623 9. Acres in Property: 2560 14. Distance to Nearest Property: 2514' 10. KB Elevation 15. Distance to Nearest Well within Pool: Zone- 4 (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3463 psig Setting Depth 1 Max. Surtace Pressure: 2818 psig Quantity of Cement c. f. or sacks (including stage data) 52° Top Bottom Length MD TVD TVD MD 8529' 28' 290 sx Class G 8557' 6119' 28' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) 60301 67001 & 84511 Nooe Nooe Filing Fee 0 BOP SketchD Drilling Program~ Time v. Depth Plot D Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby cert~'fy that the fo egoing is true and correct to 9 best of my knowledge. Contact Scott Lowry@265-6869 Printed Name R. Tho ~ Title Kuparuk Drilling Team Lea7e ~ Signature -p // iiI? / 1{, Phone Date .f / 2, 0 ß V . "t:..a"]Å,1 / ~> . reDared bv Sharon AlIsuD-Drake c;:7 Commission Use Only Permit to Drill API Number: Permit Approval ~cOoVre~r le~er E D Number: 2b,3- 088 50-/ò3 - ;lDÝSc.(- D) Date: ¡-I/ J/ù3 ~J::' Conditions of approval: Samples required J YesÆ~o Mud log required J:¡.;'es No Hydrogen sulfide measures D Yes ~o Directional survey required )t5J.wrNf tJdJ03 S5èO~\ \~'^-\. IM-~ ~......... ßÛ\:, tt.-~ r- Other: M\' ~ c.<c~\......\--Q'-.)c.:,-- \\.'--( La') Alaska Oil & Gas Cons. Commission Anchorage J7Í~(D3 19 Total Depth MD (ft): 8901' Casing Structural Conductor Length Size 80' 30" x 16" 3043' 9.625" Surface Intermediate Production Liner Pertoration Depth MD (ft): 20. Attachments: ~Æ-~ Form 10-401 Revised 3/2003 · Approved by: 6700' Cement Volume MD TVD 109' 109' 3071' 2606' 66 sx ArcticCrete 510 sx AS Lite, 300 sx LiteCrete Perforation Depth TVD (ft): Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 BY ORDER OF J·R';'~.' ...I.~..I~.; ç,. .A .(HECOMMISSION . ~ ~ ,. :\ . . ¡ i ~ .~ . .1 I ~ .j j'~\ ~ 5] -..,..¡ q I . i '. '- Date: Submit in duplicate ) AppP '~on for Permit to Drill, We1l3S-06A J Revision No.O Saved: 12-May-03 Permit It - Kuparuk Well 3S-06A Application for Permit to Drill Document Mr:)ximizE We-II VgIUE; Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)... ............... ............. ..................... ....... ................ ....... ......... ........ ..... 2 2. Location Sum mary ........ ...... ....................... ... ........... ... ........ ... ........ ... ....... ........ ........ 2 Requirements of 20 AAC 25.005(e)(2) ........................... ...... ........... .............. ............. ........ ......... ........... 2 Requirements of 20 AAC 25. 050(b)............ ..... ......... ....... ................. ............. ....... ........ ........... .... ........... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(e)(3) .... ................. ....... ............ ....... .............. ............... .............. ......... 3 4. Dri II i ng Hazards Information ........................ ..... ....... ......... ..... ..... ... .... .... ... .............. 3 Requirements of 20 AAC 25.005 (e)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (e)(5) .................................................................................................. 3 6. Casi ng and Cementi ng Program ...................... ......... .... ... ............ ........... ...... .......... 4 Requirements of 20 AAC 25.005(e)(6) ...... ...... ...... .......... ..... .............. ....................... ........ ...... ............... 4 7. Diverter System Information .... .......... .......... ..... ....... ........... ... .... ................. ............ 4 Requirements of 20 AAC 25.005(e)(7) ........... .......... ........... ................................ ............ ....................... 4 8. Dri II i ng FI uid Program ... ................... ..... .... ... ............ ....... ....... ........... .......... ............ 4 Requirements of 20 AAC 25.005(e)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (e)(9) .................................................................................................. 5 10. Seismic Analysis ........ ..... ................... ......... ... .... ............ ....... ................... ................ 5 Requirements of 20 AAC 25.005 (e)(10) ... ................. .................. ...... ..... .......... ........ ...... ........... ............ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (e)(11) ................................................................................................ 5 12. Evidence of Bondi ng ... .............................. ................... ........... ........... .......... ........... 5 Requirements of 20 MC 25.005 (e)(12) ................................................................................................ 5 13. Proposed Drilling Program .....................................................................................5 0" ~ ~ "I:~ AL ' I' IÍ "I 1 1.] tl g ~i 4 I,~ ,t, , ' 3S-06A PERMIT IT. DOC Page 1 of 6 Printed: 12-May-03 ) Appl: iJ.on for Permit to Drill. Well 3S-06A , Revision No.O Saved: 12-May-03 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments .................................................................................... ......................... 6 Attachment 1 Directional Plan ........... ........... .......... ...... .......... ............... ...... .......... ....... .......... ...............6 Attachment 2 Drilling Hazards............................................................................................. 6 Attachment 3 Well Schematic.. ..... ." .... ..... ...... ....... ... ... ...... ..... ....... ...... ........ .... ........ ... ... .... ..6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name des~qnated by the operator and a unique API number assigned by the commission under 20 MC 2s'040(b). For a well with multiple well brancheS¡, each branch must similady be Identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The sidetrack well for which this application is submitted will be designated as 3S-06A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dlill mllst be accompanied by each of the following itemS¡, except {or an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the properfy's owners and Sl70wil7g (A)the coordinates of the proposed location of the well at the surface~ at the top of each oþjective f'ormation and at total deptl7, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surfacer referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) tfle proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,993,933 I 2483' FNL, 915' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,344 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,998,930 2514' FSL, 1168' FEL, Sec 7, T12N, R8E, UM Eastings: 476,089 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8257' 5871' 5815' Location at Total Depth 12609' FNL, 1104' FEL, Sec 7, T12N, R8E, UM NGS Coordinates Measured Depth, RKB: 8557' Northings: 5,999,086 Eastings: 476,153 Total Vertical Depth, RKB: 6119' Total Vertical Depth, 55: 6063' and (0) other information required by 20 MC 25. 050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a PermIt to Drill (Fom7 10-401) must (1) include a plat drawn to a sUItable scaler showing the path of the proposed wellbore/ including all adjacent wellbores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan ,. R'·'" "~ 1l .J '. ~',i ~;i € .~! ./,,:. 3S-06A PERMIT IT. DOC Page 2 of 6 Printed: 12-May-03 ) App': -~.ion for Permit to Drill, Well 3S-06A , Revision No.O Saved: 12-May-03 and (2) for all wells within 200 f-eet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been fumisl1ed a copy of the application by certified maN; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pennit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25. 035, 20 MC 25. 036, or 20 AAC 25.037¡ as applicable; Please reference BOP schematics on file for Nabors 7ES. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PermIt to Drill must be accompanied by each of the following Item5~ except for an item already on tile with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encounterect cl7teria used to detelmine if;, and maximum potential surface pressure based on a methane gradienf;,· A pressure build-up test performed on Palm lA (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). Due to pressure depletion, the predicted reservoir pressure for 3S-06A sidetrack is predicted at 3450 psi at 5870' tvd, 0.59 psi/ft or 11.3 ppg EMW. The maximum potential surface pressure (MPSP) while drilling 3S-06A sidetrack is calculated using above maximum reservoir pressure, a gas gradient of 0.11 pSi/ft, and the Kuparuk C sand target at 5870' tvd: MPSP =(5870 ft)*(O.59 - 0.11 psi/ft) = 2818 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, 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 Pem1it to Dnll must be accompanied by each of the following items, except for an item already on tile wIth the commission and Identified in the application: (5) a descripijon of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(t); A procedure is on file with the commission for performing LOT's. For 3S-06A, the 9 5/8" surface casing shoe has been tested to 17.5 ppg EMW on 5/8/03. 0, C'· ... .. .', : 11 L .~'.~, , I' '.,' , ,'~ ~t.\,'~ ." 9 ~ 4 \¡¡~~ ~ J .} ii' 3S-06A PERMIT IT. DOC Page 3 of 6 Printed: 12-May-03 ) App" "'~. ion for Permit to Drill, Well 3S-06A , Revision No.O Saved: 12-May-03 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 Items" except for an Item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 03Q, and a description of any slotted liner; pre- perforated liner; or screen to be installed; Casing and Cementin~ Pro~ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Ibltt) Grade Connection (tt) (tt) (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 3043' 28'/28' 3071'/2606' Cemented to surface as per APD 203-057 7 8-1/2 26 L-80 BTC-Mod 8529' 28'/28' 8557'/6119' 290 sx 15.8 ppg 'G' w/ add. Planned TOC= 7207' 3-1/2 9.3 L-80 EUE 8rd 7879' 28' / 28' 7907'/5581' SAB- 3 packer set at Mod 7907' MD. If 7" casing must be top-set above the Kuparuk C sand, 6 1/8" hole would be drilled to total depth and a 3 V2" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified 1i7 the application: (7) a diagram and desCliption of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20MC 25.035(h}(2);: Please reference diverter schematic on file for Nabors 7ES. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pem7lt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (B) a drilling fluid program, inc/udli7g a diagram and description of the drilling fluid !:'ystem, as required by 20 MC 25.033; Drilling will be done using mud systems having the following properties: Production Hole mud properties Top Morraine Top HRZ 10.6 10.8 42-58 42-58 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH API Filtrate(cc) Solids (%) Kuparuk 11.8 42-58 20-25 20-25 20-25 8-16 8-18 15-25 3-6 4-7 4-8 7-112 7-12 8-16 9-9.5 9-9.5 9-9.5 <6 <4 <4 1 0-15 1 0-15 15-19 O ~. "'", ~ ., , A' ~~\;: ~ "0 .. J \; . . i.:i ~~ * I i~jM'r- 3S-06A PERMIT IT. DOC Page 4 of 6 Printed: 12-May-03 ) App':-1{ion for Permit to Drill, Well 3S-06A , Revision No.O . Saved: 12-May-03 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill mu~t be accompanied by each of tIle following Item~ except for an item already on file with the commission and identified in the applìcation: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f}/ Nj A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Nj A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applìcation for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (11) for a well drilled from an offshore platforml mobIle bottom·founded structure, jack-up rigl or floating drilling ves.c;el, an analysis of seabed conditions as required by 20 MC 25.061(b); NjA - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicl~tion for a Permit to Drill must be accompanied by each of the following item~ except for an item already on fJle with the commission and Identified in the application: (12) eVidence showing that the requirements of 20 MC 25.025 (Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of tbe following items, except for an item a/ready on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. Drill off cement plug and sidetrack well with a planned kick-off point of 7000' MD. 2. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). 7. Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer 350' above top planned perforation, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. O c'·· ¡' ;'1'.:...,. . q" 1 \;¡~,~ \ 1 I L ,,' ;" rl, .. ¡I " ,'. 3$-06A PERMIT IT. DOC Page 5 of 6 Printed: 12-May-03 ) ¡. App"'1on for Permit to Drill, Well 3S-06A y Revision No.O Saved: 12-May-03 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items~ exæpt for an item already on file witll the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorizationu/7der 20 AAC 25.080 for an an/7ular disposal operatio/7 in the wel/./ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 3S pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 3S 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 3S-06A for annular pumping of fluids occurring as a result of future drilling operations on 3S pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. O '1r~,~: ~ J'" if ~ I J~/ .¡' I "-"I.J t..' .. ~. ~ ( \. .' .·'··-1 ,I f ~ w 'it'",,; .~<I '. ) " La 3S-06A PERMIT IT. DOC Page 6 of 6 Printed: 12-May-03 ~ ~ .~ "'- ¢:: o o o ~ I....- ~ ~ ð.) Q ~ cd () .~ ~ ð.) :> 0) e E-4 Y~ì~\~~~~ig R;.: IbI'.D;]lum: ) ) KuparµkRi verUIÜt Site: .. K~patuk3SPad Well:· .. Plan: 3S ~06 Wellpath:Plan:3S-06F Plan: .. 3S-06F (wp03) T ^M ¿ 5000- Azimuths to 1'l1le NOlth Magnetic NOIth: 25.46° Magnetic Field Strenf,rth: 57458n1' Dip Angle: 80.70" Date: 5/16/2002 Model: BGGM2002 C~tqt<."-' n}':,Gk-.lm AntJI'ow;" 'Ch~W: Plan:, ~S~)6il (\\1('03) (PI,IU\: )S·OMPlafl: ,~:;~.Q()P) Date: 5/1 212(X») ~~'vit:lwod: . Appro,¢<! : 6000- PIAN )ETAI¡"~ 3S·()t-,11 (wpm) Vcr.;¡"'m~ SII2!)X)J Ihh\:. t)al~~ ,,__.__.._ Dl\t;,: ~'an '-"inl MO 11"11.' lui TVD TN/·S +li;·W o I 1000 I 2000 I 3000 Rl!.!'¡;J{I~("r: J..'1kJN.MA110N 7()XHX:() S4.JS 35:1.46 .UNI.24~ 4254.2..~ 44tLU')ti ,..·..:i.Ii¡L4-:-¡I\:/nIl'A'r,'1-:"1\.... \\,..." """1-I¡-' 1'1'11' .¡'J1'I..lrucN...)1'111 . '11. ~I. ì' i I .: "I , \..... 1..".1.. , "'t· f' \I.". . ".." \:11 " I "'i ,.' I' . ....... ,.. II:.. ~ '1·L'....J~''f''I...·"........, ......[:';, '\bL ~'¡.800 ('.1l,d)Jli\1Q M~II..."'¡,j: Mu~in\l,nll t\tr\~lr(' Vertical Section at 61.340 [1 OOOft/in] \\'EI.I.PSru L">HAIl.S SECTION DETMLS s...·~ MD 11\<" Mj Tvn +NI·5 +Er·W m.<'g 11'.1'·0 VS<'C T:ugct 7(~)(lJxRI 543~ 353.-16 4..~<)1.292 4254.284 ·+I6.mti (I. (x) U'<~I 16·1').24S 7560.277 3·t19 22.06 5294.223 4634.03\ -412.2~2 ~.(:XJ 145.Uti 1~61.1(XJ S;:'''7.:'4f> 34.\') 22.1.16 5S70.8lXJ ·N'J7.lu(Ì ·265.14(\ I)Ù.I O.Ul) 2 I MY;/) 3S·(Il'>F 8557.:'46 34.19 22.06 6118.944 5153.3b4 ·201.S35 n.m O.I)() 229.:1.841 ~.In\"::' )S.o~F SS70.S00 -IY"17.Wtj. -.":fi.5.14f, c...~ ,}QJÌJ~: lSù,¡ 1'\,1) +Sr.~ .,.E/.W Skirt' Pbn: ':¡S.t)(IF PL;.n:-.;S-l)6 'iX)().mo ~7h.'" RKß . 55.S· MSI. :;5.~)(1tì V.S;xÙ.m ~k~.~ S)\t ~:tfVl) An~'" o\J4 ' 0.(1).1 o.om (UOJ C ~~ .(1""\\ ,"', "L ~;I'·.~J,n ¡1 ¡ [ ·,1 .i J ¡I.: , . r \..'. I I .~ J ' TAIWt:!' DST AILS ) Sperry-Sun Planning Report - Geographic ') Corn'pany: Field: ,site:' , Well:, ' Wellp,nth: Phillips Alaska Inc. Kuparuk AiverUnit Kuparuk3S Pad Plan:3S~06 ' Plan: 3S-0sF Date.: .~/12/2003 ,....' .. Tiß1~:,13:4Q:()7 Co·ordinatc{NE} Referenêe:· Well: Plan: 3S·06, True North Vertical (TVD) Reference: RKB.::: 55~8' MSL. 55.8 Section (VS) Reference:' . Well ,(O:qoN;0:OOE,6l.34A2i) Plan: '3S-06F! (wp03) , ~age: I 1 Field: Kuparuk River Unit North Slope Alaska United States Map S)stem:US State Plane C·:,,:·r.-l;n,::.lo:- Sv~t¿m 1927 Gt.'o Datum: NAD27 (Clarke 186G) S)S Datum: Mean Sea Level ------.-.---------- -----------. ~-----_._-- Map Znllé: Alaska, Zone 4 Coordinate S)stl'm: Well Centre Gcumagnetil' Mudel: BGGM2002 - .----.-------.-- ----~_.- .----.- ----- -. .~ -------------- Plan: 3S-06 Slot Name: - -----.---.---- .---.----------.---- ----_._---........-_._._-----_.__.._----~--------_._-'-.-_._---- -------------- -------,-"----..----------------- Wellpath: Plan: 3S-06F Drilled From: Tie-on Depth: Height 55.800 ft Above System Datum: Declination: Dip Angle: Plan: 3S-06 7000.000 ft Mean Sea Level 25.46 80.70 0.000 Plan: 3S-06F (wp03) PrinCipal: Yes PlanS~ction Information MD Inel Azim TVD +N/·S +E/·W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10Oft deg/100ft deg/100ft deg 7000.000 $4.38 353.46 4891.292 42$4.284 -446.096 0.00 0.00 0.00 0,00 7560.277 34.19 22.06 5294.223 4634.031 -412.252 5.00 ':3.60 5.10 145.06 8257.346 34.19 22;06 5870.800 4997.106 -265.146 0.00 0.00 0.00 0.00 3S-03F 8557.346 34.19 22.06 6118.944 5153.364 -201.835 0.00 0.00 0.00 0.00 .....---------- Section 1 : Start DLS 5.00 TFO 145.06 MD Incl Azim TVD +N/·S +E/·W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg.t100ft deg/100ft deg.t100ft deg 7000.000 54.38 353.46 4891.292 4254.284 -446.096 1649.248 0.00 0.00 0.00 0.00 7100.000 50.34 357.17 4952.365 4333.157 -452.630 1681.349 5.00 -4.04 3.72 145.06 7200.000 46.43 1.35 5018.784 4407.864 -453.677 1716.265 5.00 -3.91 4.17 142.78 7300.000 42.69 6.09 5090.045 4477.834 -449.229 1753.731 5.00 -3.74 4.74 140.01 7400.000 39.18 11.52 5165.604 4542.535 -439.320 1793.461 5.00 -3.51 5.44 136.63 7413.120 38.74 12.29 5175.806 4550.607 -437.618 1798.826 5.00 -3.36 5.89 132.52 7500.000 35.96 17.80 5244.886 4601.476 -424.026 1835.153 5.00 -3.20 6.34 131.92 7560.277 34.19 22.06 5294.223 4634.031 -412.252 1861.100 5.00 -2.93 7.06 127.54 Section 2 : Start Hold MD Ind Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/1OOt deg 7600.000 34.19 22.06 5327.079 4654.721 -403.869 1878.380 0.00 0.00 0.00 0.00 7616.590 34.19 22.06 5340.801 4663.362 -400.368 1885.597 0.00 0.00 0.00 0.00 7700.000 34.19 22.06 5409.794 4706.807 -382.766 1921.881 0.00 0.00 0.00 0.00 o "'1 'f' · , i ~ L IW¡~ ' .j ~, 'j. . I ., :. I" \-.,¡ ~ ! " ~i4- ""':, ' ) ') Sperry-Sun Planning Report - Geographic Çompàny: PhillipsAlaskalhc. Field: Kuparuk Hiver.Unit . Sitè Kuparuk3Spad Well:', Plan: 3S-06 . w~npath: Plan: 3S-06F , Í)ate: 5/12/2003 ... ... Tiine:.13:45:07 Co·ordil1ate(NE} ReCerence: . Well:' Plan: :i!S~06, True North Verticâl (TVJ») Reference: RKB;:: 55$ M$LS5:8 ~ction (VS) Reference: Wel!(O.OON;.o;ooE,61.34Azi)· Plan: 3S-06f(yvp03)' 2 Section M[j ft 7800:000 7828.150 7900.000 .8000.000 8051.810 8100.000 8172.700 8200.000 8257.346 Section MO, ·ft. 8281.500 8300.000 8400 .000 8500.000 8557.346 Survey 1\1D .Jt 7000.000 71.o0.QOO ?200:oo0 73QO;oQO 7400..000 74;13.J20 7500.000 7560.277 7600..OQO 7616,590 7700.000 7800.000 7828.150 7900.000 8000.000 8051.810 8100.000 8172.700 8200.000 8257.346 8281.500 8300.000 8400.000 8500.000 8557.346 Targets 2 : Start Hold .nel. . peg 34.19 34.19 34.19 34.19 34.19 34.19 34.19 34.19 34.19 PLS . ..ßuild.. . .1'urn ..' degl1 ,OQftdegl1 ÒOftd$gI1 OOft' 0,00 0.00 0.00 0.00 IJOQ (foo 0:00 0.00 O.()() 0:00 0.00 0.00 Q.Op 0.00 O.Op 0.00 0,00 0.00 0.00 O.ÖO O.qo 0,00 0.00 0.00 0.00 0.00 0.00 ,1VO ft 5492.508 5515.792 5575.223 5657.937 5700.792 5740.652 5800.785 5823.366 sa70.Mo Azim , 'dëg 22.06 22.06 22.06 22.06 22.06 22.06 22.06 22..06 22.06 ··TFQ deg 0.00 0.00 Q:QO 0.00 0.00 0.00 0.00 0.00 0.00 +N/~S ·1t 4758.893 4773.555 4$10.979 4869,065 489p.()51 4915.151 4~?a.017' 4967.237 4997.106 fE/oW 1f· "361.662 ~355.7:21 ~340.$$$ ."319.41)5 "SQß·p21 -?9ß,3151 -283.pO~ '-277.248 ~265.146 VS. ft 1965;383 1977.629 2008.885 ?q52.~~6 2()74,9?4 2()9$.e88 2127.518 2139.389 2164.336 3 : Start Hold . bid . .AzIOl, TVD il-NI.S +IÚ·W . ·vs i>~_s ............ .~uiId . ...... " iTtÙ~Il.. .' .'TF'o..·,'·· deg çJeg ft; 'ft ft . ·ft ~eg¡lpott . d~llQ()n'deg¡tOOft ..cjeg..'.. 34.19 22.06 5890.779 5009.687 -260.048 2174.843 0.00 0.00 0.00 0.00 34.19 22.06 5906.081 5019.323 -256.144 2182.891 0.00 0.00 0.00 0.00 34.19 22.06 5988.795 5071.409 -235.040 2226.393 0.00 0.00 0.00 0.00 34.19 22.06 6071.510 5123.495 -213.937 2269.894 0.00 0.00 0.00 0.00 34.19 22.06 6118.944 5153.364 -201.835 2294.841 0.00 0.00 0.00 0.00 ^,I~p .'. ,....':'"-·'T:7:--:-~..,,..-::, I¿~.~ J.iatitude.~"~>·. <~~';,L()¡lgiïud~~-.> · , " !Map" Inel 4ZI,rQ ·'+NPS" +E(~W . Northixtg E~stil* ' D~g i~i~i ~~c .. ·~~~'Min.'.~c, . .. deg ·deg. ' , .. 'ft ft __~·ft~L-"~ It I :",.,'"'. . .1,' " '.'" ,:,' ','" ',', I -_.._-,-_....--_...._~-~ -.....-------.---..---- ---'... 54.38 353.46 4254,284 -446.096 5998187.83 475911.79 70 24 22.237 N 150 11 45.967 W 50..34 357.17 4333.157 -452.630 5998266.72 475905.51 70 24 23.013 N 150 11 46.158 W 46;43 1.35 4407.864 -453.677 5998341.42 475904:70 70 24 23.748 N 150 11 46.189 W 42A3Q 6~09 4477.834 -449.229 5998411.37 475909.37 70 24 24.436 N 150 11 46.059 W 39.18 11.52 4542.535 -439.320 5998476.03 475919.48 70· 24 25.072 N 150 11 45.769 W 38.74 12.29 5175.806 4550.607 -437.618 5~98484.10 475921.21 70·.··24 25.152.N 150 11 45.719W 35.96 17.80 5244.886 46010476 -424.026 5998534.92 475934:96 70,24 25.652N 150 11 45.321·W 34.19 22~06 5294.223 4634;031 "412.252 5998$67.43 475946.83 70· 24 25.912 N 150 11 44.916W 34.19 22.06 5327.079 4654.721 "493.869 599ß$88.09 475955;28 70 24 26. 176 N 150 11 44.730W 34.19 22.06 5340,801 4663.362 -400.368 5998596.72 475958.81 70 24 213.261 N 150 11 44.627 W 34,19 22.06 5409.794 4706.807 "382.766 5998640..11 475976.55 7024 26.688 N 150 11 44.112 W 34.19 22.06 5492.508 4758.893 -361.662 5998692.12 475997.81 7024 27.200N 150 11 43.493·W 34.19 22.06 5515.792 4773.555 -355.721 5998706.76 476003.80 70 24 27.344· N 150 11 43.319 W 34.19 22.06 5575.223 4810.979 -340.558 5998744.13 476019.08 70 24 27.712 N 150 11 42.875W 34,19 22.06 5657.937 4863.065 -319.455 5998796.15 476040.35 70 24 28.225 N 150 11 42.256 W 34.19 22.06 5700.792 4890.051 -308.521 5998823.10 476051.36 70 24 28.490 N 150 11 41.936 W 34.19 22.06 5740.652 4915.151 -298.351 5998848.16 476061.61 70 24 28.737 N 150 11 41.638 W 34.19 22.06 5800.785 4953.017 -283.009 5998885.98 476077.07 70 24 29.109 N 150 11 41.188 W 34.19 22.06 5823.366 4967.237 -277.248 5998900.18 476082.88 70 24 29.249 N 150 11 41.019 W 34.19 22.06 5870.800 4997.106 -265.146 5998930.00 476095.07 70 24 29.543 N 150 11 40.665 W 34.19 22.06 5890.779 5009.687 -260.048 5998942.57 476100.21 70 24 29.667 N 150 11 40.515 W 34.19 22.06 5906.081 5019.323 -256.144 5998952.19 476104.14 70 24 29.761 N 150 11 40.401 W 34.19 22.06 5988.795 5071.409 -235.040 5999004.20 476125.41 70 24 30.274 N 150 11 39.783 W 34.19 22.06 6071.510 5123.495 -213.937 5999056.22 476146.68 70 24 30.786 N 150 11 39.164 W 34.19 22.06 6118.944 5153.364 -201.835 5999086.04 476158.87 70 24 31.080 N 150 11 38.809 W Name Description Dip. Dir. Map Map Northing Easting ft ft 5998930.00 476095.07 <--- Longitude ___> Deg Min See <---- Latitude ----> Deg Min See TVD ft 5870.800 +N/-S ft 4997.106 +E/-W ft -265.146 70 24 29.543 N 150 11 40.665 W 3S-06F -Circle (Radius: 150) -Plan hit target O . r"'" . ï , ,1 If, .J 'J ""'11 " ",I , ~" J \...i.'·'" v. ,,¡ ~- ~~I ) ) Sperry-Sun Planning Report - Geographic 7"!---"-'-7.T C()nipahY~ Field ~ ; S~te; , , Well:,' ., .WeUpath: Philljps Alåskålnc~ Kuparuk River.Unit Kuparuk 3$ .Pad Plan': 3S~06 ' Plah: 3S-Û6J= Date~, 5/12/2003' Time: Ú:45:úi Co.ordÙ1ate(~mYReference: VVell: Plan:3S~06,· TrueNorth ,Vertical (TVD)Referel,\c~: RKB = 55~8'M$L55.8 Sßctìon (VS).Reterence: WeH(O.OON;O.OOE,61.34Azi) Plan: 3S-06F' (wp03) , ., Formations MD 1t 7413.120 7616.590 7828.150 8051.810 8172.700 8257340 8281.500 ¡V)) ft 5175.806 5340.801 5515.792 5700.792 5800.785 5870.795 5890.779 C ... l') · r1' \.;1 '\ .,.J 11.,. L ~ ~ .~'. ~ I l~ § . ~ ConocoPhillips Alaska, Inc. 3S-06F {wp03} MD Inc Azim. SSTVD TVD N/S DLS v.s. Comment (ft) (De g) (Deg) (ft) (ft) (ft) e/100ft) (ft) 7000 54.38 353.456 4835.483 4891.283 4253.432 N 451.967 W 5998187 N 475905.9 E 0 4268.184 Begin Dir @ 5/100ft (Sidetrack) 7050 52.344 355.264 4865.321 4921.121 4293.352 N 455.917 W 5998227 N 475902.1 E 5 4308.232 7100 50.337 357.174 4896.556 4952.356 4332.305 N 458.501 W 5998266 N 475899.6 E 5 4347.257 7150 48.363 359.197 4929.128 4984.928 4370.215 N 459.712 W 5998304 N 475898.5 E 5 4385.185 7200 46.427 1.346 4962.976 5018.776 4407.011 N 459.548 W 5998341 N 475898.8 E 5 4421.944 7250 44.534 3.636 4998.034 5053.834 4442.622 N 458.011 W 5998377 N 475900.4 E 5 4457.464 7300 42.69 6.084 5034.237 5090.037 4476.981 N 455.101 W 5998411 N 475903.4 E 5 4491.678 7350 40.901 8.706 5071.515 5127.315 4510.021 N 450.827 W 5998444 N 475907.8 E 5 4524.52 7400 39.177 11.52 5109.797 5165.597 4541.681 N 445.194 W 5998476 N 475913.6 E 5 4555.927 I 7413.121 38.736 12.293 5120 5175.8 4549.753 N 443.492 W 5998484 N 475915.3 E 5 4563.924 Top Moraine -- 7450 37.525 14.545 5149.01 5204.81 4571.901 N 438.215 W 5998506 N 475920.6 E 5 4585.841 7500 35.956 17.8 5189.08 5244.88 4600.621 N 429.901 W 5998535 N 475929 E 5 4614.203 a 7550 34.482 21 .303 5229.931 5285.731 4627.789 N 420.27 W 5998562 N 475938.8 E 5 4640.961 7560.27 34.192 22.054 5238.411 5294.211 4633.172 N 418.131 W 5998567 N 475940.9 E 5 4646.253 =~:-.] 7560.351 34.19 22.06 5238.478 5294.278 4633.214 N 418.114 W 5998567 N 475940.9 E 5 4646.295 End Dir; Start Sail 7600 34.19 22.06 5271.275 5327.075 4653.863 N 409.746 W 5998588 N 475949.4 E 0 4666.59 7616.592 34.19 22.06 5285 5340.8 4662.504 N 406.244 W 5998596 N 475952.9 E 0 4675.084 Base Moraine !.:" 7650 34.19 22.06 5312.634 5368.434 4679.903 N 399.193 W 5998614 N 475960 E 0 4692.184 7700 34.19 22.06 5353.993 5409.793 4705.943 N 388.641 W 5998640 N 475970.6 E 0 4717.778 7750 34.19 22.06 5395.352 5451.152 4731.983 N 378.088 W 5998666 N 475981.3 E 0 4743.372 ...._-<-~., - ..... 7800 34.19 22.06 5436.711 5492.511 4758.023 N 367.535 W 5998692 N 475991.9 E 0 4768.966 "'" i~ 7828.155 34.19 22.06 5460 5515.8 4772.686 N 361.593 W 5998706 N 475997.9 E 0 4783.377 Top HRZ r--- 7850 34.19 22.06 5478.07 5533.87 4784.063 N 356.983 W 5998718 N 476002.5 E 0 4794.559 7900 34.19 22.06 5519.429 5575.229 4810.103 N 346.43 W 5998744 N 476013.2 E 0 4820.153 7950 34.19 22.06 5560.788 5616.588 4836.143 N 335.878 W 5998770 N 476023.8 E 0 4845.747 8000 34.19 22.06 5602.147 5657.947 4862.183 N 325.325 W 5998796 N 476034.4 E 0 4871.341 8050 34.19 22.06 5643.505 5699.305 4888.223 N 314.773 W 5998822 N 476045.1 E 0 4896.935 8051.807 34.19 22.06 5645 5700.8 4889.164 N 314.391 W 5998823 N 476045.5 E 0 4897.86 Bottom HRZ 8100 34.19 22.06 5684.864 5740.664 4914.263 N 304.22 W 5998848 N 476055.7 E 0 4922.529 8150 34.19 22.06 5726.223 5782.023 4940.303 N 293.667 W 5998874 N 476066.3 E 0 4948.122 8172.7 34.19 22.06 5745 5800.8 4952.125 N 288.877 W 5998886 N 476071.2 E 0 4959.742 K1 8200 34.19 22.06 5767.582 5823.382 4966.343 N 283.115 W 5998900 N 476077 E 0 4973.716 ~ 8250 34.19 22.06 5808.941 5864.741 4992.383 N 272.562 W 5998926 N 476087.6 E 0 4999.31 8257.34 34.19 22.06 5815.013 5870.813 4996.206 N 271.013W 5998930 N 476089.2 E 0 5003.067 Target Top Kuparuk 8281.503 34.19 22.06 5835 5890.8 5008.79 N 265.913 W 5998942 N 476094.3 E 0 5015.436 Base Kup 8300 34.19 22.06 5850.3 5906.1 5018.423 N 262.01 W 5998952 N 476098.3 E 0 5024.904 8350 34.19 22.06 5891.659 5947.459 5044.463 N 251.457 W 5998978 N 476108.9 E 0 5050.498 8400 34.19 22.06 5933.018 5988.818 5070.503 N 240.904 W 5999004 N 476119.5 E 0 5076.092 8450 34.19 22.06 5974.377 6030.177 5096.543 N 230.352 W 5999030 N 476130.2 E 0 5101.685 8500 34.19 22.06 6015.736 6071.536 5122.583 N 219.799 W 5999056 N 476140.8 E 0 5127.279 8550 34.19 22.06 6057.095 6112.895 5148.623 N 209.247 W 5999082 N 476151.4 E 0 5152.873 8557.34 34.19 22.06 6063.166 6118.966 5152.446 N 207.698 W 5999086 N 476153 E 0 5156.63 ) ) 3S-06A Drillina Hazards Summary 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ, K-l, and Miluveach High ECD and swabbing with higher MW's required Risk Level Low Moderate Barite Sag Differential Sticking Low Moderate Abnormal Reservoir Pressure Moderate Lost Circulation Moderate 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. 3S-06A Drilling Hazards Summary. doc prepared by Scott Lowry 5/12/03 O ""," !.., \. ~ .~ , . .~ 'I~' \.~;r ¡ ,~ .~ I l ~',:;r.J Page 1 of 1 KRU - 3S-06A InJ_,btor Proposed Completion Schematic Single Completion cø~lPhillips 16"x30" I ¡;¡ ~ r ~ insulated r I ~ ~ ~ ~ z I conductor @ ~ I ~ ~ ~ I +/- 108' MD ~ I ~ ~ Ii I I I ~ I ~ I ~ I ~ ~ I I ~ I ~ L... I ~ ~ I I ~ ~ I I ~ I ~ ~ Ii I ~ ~ ~ I ~ ~ ~ I ~ ~ z I ~ ~ ~ I ~ ~ I I ~ ~ ~ Surface csg. ~ ~ ~ Ii 9-5/8"40# L-80 ~ ~ ~ ~ ~ BTC (3071' MD / ~ ~ ~~ ~ ~ 2606' TVD ~ ~ Cemented to ~ ~ ~ ~ surface) ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ n,,,.~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ I ~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ =. ~ ~ ~ ~ ~ ~ ~ ~ ~ ..J ~ C ...--"-"'~ ~~j:; Sand peñs .. ':..:-:~ r (to be done J after rig moves t-m off) I:I ..-- -, ~ r-- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .. ~ ~ ~ 1 ~ ~ ~ þ~~~ ~ Production csg. ~ ~ 7" 26# L -80 ~ ~ BTCM (+/- 8557' MD) 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Cameo DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. 3-1/2" x 1-1/2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo "DS' nipple w/2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SA B-3' Permanent Packer set +/- 350' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'D' nipple w/2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide w/ shear out sub. Tubing tail 320' above top planned perforation. TD @ 8,557' MD / 6,119' TVD Scott L Lowry 05/12/03 OFut...;,¡ ,J I , ,.'I!)!;I . ) "I ~"~,.'I'" ""fë,~~"I:"!1"·~'~"r.''''''iffi\tl\'''''''I\,.:mt,';¡"Ið,.,\~I.!;¡''';jl'l~!!:'~\n~',I' "I,r~ 11'''\ "'.',;<;." "''''''I!I'>~~.;:¡:i!~¡¡~''I/' (';",¡'" ~1"1>.~..'.". ,,.,'"'" ,.", "'r:'" iP", "JI,'!,?,,¡ ""';\M', \I -'1'" ql~""" ,"" -." ".,..~ i S. K. ALLSUP-DRAKE 1 041 ~~ ~' CONOCOPHILLlPS [J ~ 711 G STREET - A T01530 LI ~.~. ~ ANCHORAGEAK 99501 DATE IZ-r(i 2fXJ3 62-14/311 ~1 I ~~~~~¡;~E S'íP1íE or ALl/sþ1/~ I $ ¡co. 00 1 I -- ~ ~ do ~ () /k-' ~OD a =~"' '\.'1.:.·.',·. ~ C/t ~ I ( DOLLARS L!J 0."11,.,,0,,,. ~ ~ ~.... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars i: I\!\;.' "-, .,."".,,".",,_...œ,"" ~ J j/ 7) ¡ \I·.:.~.' . MEMO 35 -1%.4 ------~dff~~ J.. "~':, ?~, :..~,"~".~,~" ~I'~"'~':""~'.I:"?'~ ~:"?~ 1. 2 7 ~i,,:,~~,~,I'~'~'~'~::'~~'~I" 'i. .". ,., t~ " ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER KRtL ~<; -ðb 2-03- D~23 WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production. should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 aj ody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Company .Gº-t-.lQ.CQeHtLLJeS_ðJ~~.s~8Jt-.I.c Well Name: J:(Ue8ß!JJ~-':~I.~,LU~JI_._3.s-=-OJ:i8 Program .S.EB Well bore seg D PTD#: 2030880 Field & Pool J~lJPARl!~ RIVER, KUPARUK RV OIL - 4~illJ)0 Initial ClassfType __SER / WAGIN GeoArea Ji.9_0 Unit 11160 On/Off Shore .on Annular Disposal D Administration 11 Permit fee attached. . . . . .. ..... _ . . _ Y.ßs . _ . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . _ . . . . . ,2 .Leas.ß .number _appropriat.e. . . . . . . . . . . _ _ . _ _ . . . . . . . . . . . . . . . . Y.ßS _ . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . 3 Uni.que welt nal11.ß .and oumb.er . . . . . . . . . . . . _ _ . . . . _ . . . . . . . . _ . _ . . _ _ Y.ßs . . _ . _ . _ . . _ . _ _ . _ . . . . . . _ . . . . . _ . . . . _ . . . . . . . . . _ _ . _ _ _ . _ _ _ _ . . _ . . 4 .We.1I JQcat.ßd i.n_a. d.efil1e.d .pool. . . . . . . . _ . . _ . . _ . . . . _ . _ . . . . . . _ _ . . . Y.ß$ _ . . . _ _ . . . . . _ _ _ . _ . . . . . . . . . . . . . . _ . . _ . _ . _ _ . _ . _ . . . . . . . . . . _ . . . _ . _ . . _ _ _ . . . _ . _ . . . . 5 Well JQcat.ßd pr.oper .di.stanceJrom. driJling unit. b.ound.ar:y. . . . . . _ _ . . _ . . _ . . . Y.ß$ . _ . . . . _ _ . . . _ _ . . . . . . _ . _ _ _ _ _ _ _ _ . . . _ _ . . . . . . . . _ . 6 .We.1I JQcatßd prpper .di.stance. from. Qtbe.r wßlIs.. _... _ _ . . _ _ . .. ......... _ . _ . Y.ßs _ _ . . _ . . . . _ . . _ . _ _ _ . . _ _ . . . . . . . . . _ . . . _ . _ . . . . _ _ . _ . . . . . . . . . _ . . _ _ _ _ _ . _ _ . . . _ . . . 7 .S.ufflçient.açrßage.ayailable i.n_d.ritliog un.it. . _ . . . . . _ . _ _ . . _ . . . . . . . . . _ _ _ _ . . . . Y.ß$ . . . _ _ . . _ . . . _ _ . . . . . . . _ . . . . . . . . _ . _ . _ _ _ . _ _ _ _ _ . _ _ . _ _ . . . . . _ _ _ . _ . . . _ _ . _ . . . . . . . _ . . 8 H.d.ßyiated. .is. weJlbQre plaUl1cJuded . . . . . _ . . . _ _ . . . . . . . . . . . . . Yß$ . . _ . _ . . . . . . _ . _ . _ . . _ _ _ . . _ . _ . . _ . .. . . _ _ _ . _ . . . . _ . . _ . _ . _ . . 9 .Opßr:.ator only affeçtßd party _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ . _ _ . _ Yßs _ _ . . _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ . . _ . _ . _ . . _ . . _ . . _ . _ _ . _ _ _ _ _ _ . _ _ . _ . _ . . _ _ . . 10 _OPßr:.ator bas.appropri.ate_Qond i.nJQrçe. . . . . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ . _ _ . _ . . _ . _ Y.ß$ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ _ . . _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ . 11 Pßrmit. C8(1 be i.ssueÒ witbQut co.nserva.tion order. . . . . _ _ _ . . _ . . _ . . _ . . . _ . _ _ _ . . _ Y.ß$ _ . _ . _ . . . _ . . . _ _ . _ . _ _ . _ _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ . . . . . _ _ . . . _ _ . _ _ . _ _ . . _ _ . . . . . . Appr Date 12 P.ßrmit. C8(1 be i.ssueÒ witbQut admil1istr:.ati'le_approval _ _ _ . _ _ _ _ . _ _ . . . _ _ . . _ _ _ . _ _ _ Yes - - - - - - - . - - . - - - - - - - - - - - . . - . . - - - . - . _ _ . _ _ . _ _ - _ - . . .. . . . . . _ . _ - _ - - - - - . . _ _ _ . _ . _ . SFD 5/14/2003 13 .C.a(l permit.be apprQv~d beforß _15-òay. wa.it. _ . _ . . _ _ . . . _ . . _ . . . . . . . . _ _ _ . . . . - Y.ß$ . . . . - . . . - . . . . - . . . . . - - . . - - - - - . - - - - - - - . - - - - - - . . - - - . - . - . - - - - - - - - - - . - - - - - . - - . . - 14 _We.IIJQcat~dwi.thinareaand_strata~uthori.zedbY-'(ljectiooOrd.ßr:.#(put.IO#in.C9r:nrn.ßots).(For_ Y.ß$.... _. .AIO.2.B.dated_De_cembe.r.12,.2002 _.. _. _ _ _ _. _... _. _.... _ _. _ _. _ _ _.. _. _ _ _. _. _. _ _ _.. 15 .AJlw~l)s_within.1l4-''tlite_are.a.ofr:.eyi~wid.ßoti.fied(Fpr:~ervjc.ßwellonly)..... _ _ _ _ _ _ _ _ _ _ Y.ß$_ _ _.. _ .~QQtberwells.wit.hi.n_1/4_ITIi!e.oHnjeçtionjnJervak. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _... _... 16 Pre.-produ.cedinjßctor; d\Jrat.iQn_ofpr~-producti0I1I.ß$s.tban.3months_(For_s~r:.vi.cewell. QnJy) .. NA. _ _... _ _. _. _ _ _. _ _ _ _ _ _ _.... _ _ _.... _.......... _. _ _ _... _ _ _ _ _. _ _.. _ _. _ _.. _ _ _ _.. 17 .A.GMP_F:ïnding_ofCQn_sißt.e(lcy.ha$ bee.nj~sued.forJbis prpiect_ _ _ _ _ _ . _ . . _ . . _ _ . _ _ _ . NA . _ . _ . _ . _ _ . _ _ _ _ _ _ . _ _ . _ _ _ . _ . . . _ _ _ . _ . . . _ . _ _ . . . _ _ . . . . _ . _ . . . _ _ . _ _ _ _ . . _ _ _ . _ _ . . . Engineering 18 _C_o(ldu.ct.or $tr:ing.prQvidßd _ _ _ _ _ _ _ _ . _ . _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ . . _ _ _ Y.ß$ _ _ _ _ _ _ _ Thi~ i$ a geQIQgjcatsJd.etrack_of a. pr~$e.ntly driJling welt. _ _ _ _ _ _ . . . . _ . . _ _ _ . _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ 19 _S_ur:fac.ß_ca~ir19_p.rQtec.t~all_k!1Qwn.USQWs...... _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . . _ . . _ . . . . NA. _ _ . _ _ _ _AlI.aquife.r$ex.ßr:npt.ßd..40_C.FR.1~7.jQ2.(ÞH3). _ _ _ . _ _ . . _ . . _ . _ _ _ . . _ _ _ _ . _ _ _ . . _ _ . . . . _ . 20 .CMT.v.otad~qu_ate.to çircutate.o!1_cOl1d.uçtor.& $UJf.C$g _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ Y.ß$ _ _ _ _ _ _ _ $uriaçe C8ßing çeme.ntedJQ $u_rface_Qn_3_S:-0_6, _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ . . . _ _ _ . _ _ . _ . _ . _ _ . _ _ _ _ _ . 21 _CMT.vptad~qu_ate.totie-tnJQngßtriogto.s!Jr::f~g_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ .. _. _ _ _ No_ _ _ _ _ _ _ _Al1nµl~rdi$p.osal !JltimÇltßlypl.aOl'1eÒ._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ 22 _CMT. will coyer .a)l koown -pro_ductiye bQri~Qn.s. . . . . _ . _ _ _ _ _ _ _ _ _ _ . _ _ . _ . . _ . . _ .. _ Y.ß$ _ _ _ _ _ _ _ _ _ _ . _ _ _ .. _. _ . _ _ _ _ _ _ . _ . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . . . . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . _ 23 .Gasi(lg de.si.go$ adequate. for: C,_T~ B _&_ Rermafrpst . _ _ _ _. _ . _ _ _ . . . . _ . _ _ . _ _ _ _ _ _ Y.ß$ _ _ _ _ _ _ _ . _ _ _ _ _ . . . _ . _ _ . _ . . . . . . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ . . _ . . _ . . _ _ _ . . . _ _ _ . 24 .A.Òequate.tan.kage.o.rre.seryepit _ _ _ _ _... _ _ _ _ _ _. _.. _. _.... _.. _ _. _. _ _. _. Y.ß$. _. _.. .~Qr:e$erve.pitpJa.noed...Rigequi-pped.wit.h_ste~tRit$..OrjllingW~steto_an!1lJlus.Qr.CJa.s$IJWßII._. _ _ _ _... _ __ 25 Jf.a.re-drill.. béJs_a. 1.0:-4.03 fQr abanÒon.me.nt be.ßO apPJQv~d _ _ _ _ _ _ _ . _ . . . _ _ . _ . . . . . . Y.ß$ _ _ . _ _ _ . 30_3:H4._v~r:bal_approyaJ by. WGA_5f12lO3... _ _ _ _ _ . _ _ . . _ . _ . . . . _ . _ _ . _ _ _ _ _ . . _ _ . _ . . _ . _ . . . . 26 _Adequatewellb.ore. ~epa.ratjon .propos.ed _ _ _ _ . _ _ _ . . _ _ _ _ . _ _ _ _ . . _ . _ . _ . _ _ _ _ _ _ Y~$ _ _ _ _ _ _ . I.n .thi~ s.e.ctjo.n_of thß w~lIbo(e. t.her.ß .are_ n_o_clo~e apprQaçhe_s.. _ _. . . . _ . _ _ . _ . _ _ _ _ _ _ . . _ _ _ .. 27 Jf.div~r:.ter Je.quired. dQe~ jt .m.eßt. rßguJa.tiOl1s_ _ _ _ _ _ . . . . . . . . _ _ . . . _ _ _ _ _ _ _ _ _ _ . . NA . _ _ _ . . _ _ . . _ _ _ _ _ _ _ _ _ . _ _ . . . . . . . _ _ . . . . . . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . . _ _ _ _ _ _ _ _ . . . _ . . Appr Date 28 .DJitliOgfJuid.RrogralT)$ChßlJlatic.&.eqµipJist.aÒequat.ß... _ _ _ .. _ _ _. _ _..... yes.... _. .Calcu.laJed.SHP.e.st@.1.1.3.EMW.. PI.aonedMWj1.6.... _.... _.... _ _....... _ _ _ _... _.. _.._ TEM 5/15/2003 29 _BOPEs._d_o Jhey .m.e~t. rßguJaJiOI1 . _ . _ _ . . _ _ _ . _ _ _ _ _ _ _ . . . . _ _ . . . _ . . _ . . _ Y.ß$ . _ _ _ _ _ _ _ . _ . _ . _ _ _ . . . _ . _ _ _ . . _ _ _ _ . . _ _ . . _ _ . _ . . . . . _ . _ . _ . . . _ _ . _ _ . . . . _ _ _ JØ!V!. Ýtçöì 30 .BQPE.pre.ssra_tiogappropriéJte;.tesHo_(pu.tps.igin.coITIIJlßnt$)- -..... -. - - - - - - - -.. - Y.ßs_..... .MASf>e~t@2818.psi.. 35QO_p~Lte~tpr.e$~ure.ad~qu.ate_..pp.GpJilseJy_tote_stto.5QQO_P.st._ - - - - - - -.. - - -.. ( 31 .C.hoke_manifold CQmpJies. w/APtR~-53 (May 84)_ . . . _ . . . . . . . _ . _ _ _ _ _ _ .. _ . _ . . . . Y.ßs. _ . . . . _ . . _ _ _ _ . . . . _ _ .. . . . _ _ . _ _ . _ . . . . . . . . . . _ _ . _ _ _ _ _ _ _ . . . _ _ _ _ . _ _ _ _ _ _. _ . . . 32 .WQrk will occ_ur without.operatio!1_sbutdQwn_ _ _ . _ . _ _ _ . . . _ _ _ _ _ . . _ _ _ _ . _ _ . _ . _ . Y.ßs. . _ . . . _ . _ _ .. _ _ _ _ _ _ _ . _ _ . _ _ . . . . _ _ _ . . . . . . . _ . . . _ . _ _ _ . . _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ . . 33 J~ pre~ence_ Qf H2S gas. prob_ablß _ _ _ _ _ _ . . . _ . . . _ . _ . . _ _ . _ _ _ _ _ _ _ _ _ . . _ _ . . _ NA . _ . . _ _ _ . _ _ . _ _ . _ _ _ _ . .. _ _ _ .. _ . . . _ . . _ _ . . . _ _ . . . . . . . . . _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ . . . _ _ 34 Meçha_ni.cç¡l_cpodjtlonpt we.lI$ wi.thil1 AQR yerified (fpr_s.ßr:vi.cß w~IJ on.ly') _ _ . _ . . . . . _ . .. . _ Y.ß$ _ _ . _ _ _ _ Accpr_di.ng to_ tbe ge.ologi.cal_mapL tbe pl'1ly. we.llþQre wi.thin 1/4 mjle i$ .3$:0!3 ptug bac.k, P&A pl.ao açc~ptç¡b.le.. 35 P.ßrmit. c.ao þe i.s$ueÒ wlo_ hyÒr_oge.n_ s_utfide meaS.\.J(e$. . _ _ _ _ _ _ _ _ _ . _ . _ _ . _ . . _ . . . . Y.ßs _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . . _ _. _ _ _ _ _ _ _ _ . _ . _ . . . . . _ _ _ _ _ _ _ _ . _ _ . . . _ _ _ _ _ _ . . 36 .D.ata_presßoted on.potentiéJl pverpres_sur.ß.zone$. _ . . . . . _ . _ . _ . _ _ _ _ . _ _ _ . . _ . . _ . Y.ß$. _ . _ . . _I?r~dicted r:eservoJr.pre.ssure i.s.11..3.ppg EMW_. _Mitig.atiQn.me.asures. ad_dre$se.d.in Drjlling.H.a¡a.zard.S.ul11rn.ary, . 37 _S.ßi$r:nic.analysJs. Qf $baJlow gas_zpoe.s. _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ . . _ _ . _ . . . _ _ _ NA . _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ _ . . _ _ _ _ _ _ _ _ _ _ . _ . . _ . _ _ _ _ . _ . _ _ . _ . . _ . _ . _ _ _ _ _ 38 _S.ßab.eO _cOl1d.itipo survey.(if oft-s.hpr:e) . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . _ _ NA . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _. _ _ _ _ _ _ _ _ _ . _ _ . . _ . _ _ _ _ _ . . _ _ . . . _ . . _ . _ _ _ . . . . _ .. 39 . CQnta.ct nam.elphone.forwe~lsly progre~s.reports [exploratory _oOly]. _ _ _ _ _ _ _ _ . . . _ . _ . . NA _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ . _ _ . _ _ _ _. . _ _ _ _ _ _ _ . _ . . . . _ _ _ _ _ _ _ . _ . . _ . . . _ .. _ . . _ . . .. Geology Appr SFD Date 5/14/2003 Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date Proposed WAG injection well. OTS OJ"( I..sJCJJ ~ o/'Í17~ ) ) We 1/ H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun D~ "ling services LIS Scan Utility ') ,/ $Revision: 3 $ LisLib $Revision: 4 $ Fri May 30 13:14:02 2003 ~D3 - D83 \125\"3 Reel Header Service name.... . . . . . . . . .LISTPE Date.................... .03/05/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/05/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3S-06A 501032045401 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 30-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002419826 P. SMITH M. THORNTON MWD RUN 3 MW0002419826 P. SMITH M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2483 915 MSL 0) 56.60 27.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3070.0 # REMARKS: ) ) 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS SIDETRACKED OFF OF A CEMENT PLUG IN THE 3S-06 WELLBORE AT 6600'MD/4648'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); ACOUSTIC CALIPER (ACAL); AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. 7. MWD RUNS 1 - 3 REPRESENT WELL 3S-06A WITH API#: 50-103-20454-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8579'MD I 6142'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW- COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVAL ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 11.5 - 11.8 PPG MUD SALINITY: 600 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: $ ..... .bSTONE ) File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/30 Maximum Physical Record. .65535 File Type...... . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NPHI NCNT FCNT PEF RPX RPS RPM RPD FET GR RHOB DRHO ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2996.5 2996.5 2996.5 3009.0 3044.5 3044.5 3044.5 3044.5 3044.5 3052.0 3068.5 3068.5 3083.5 STOP DEPTH 8490.0 8490.0 8490.0 8503.5 8539.0 8539.0 8539.0 8539.0 8539.0 8547.0 8503.5 8503.5 8579.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO 2 3 MERGED MAIN PASS. $ MERGE TOP 2996.5 6600.5 MERGE BASE 6600.0 8579.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM )4 1 68 20 6 ) RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2996.5 8579 5787.75 11166 2996.5 8579 ROP MWD FT/H 2.25 3051.15 183.164 10992 3083.5 8579 GR MWD API 43.4 414.47 119.803 10991 3052 8547 RPX MWD OHMM 0.12 2000 4.34939 10990 3044.5 8539 RPS MWD OHMM 0.06 171.5 3.94734 10990 3044.5 8539 RPM MWD OHMM 0.11 2000 6.27863 10990 3044.5 8539 RPD MWD OHMM 0.07 2000 12.6485 10990 3044.5 8539 FET MWD HOUR 0.1569 120.782 1.3531 10990 3044.5 8539 NPHI MWD PU-S 14.08 58.81 33.1622 10988 2996.5 8490 FCNT MWD CNTS 573.8 2509.5 996.095 10988 2996.5 8490 NCNT MWD CNTS 113125 194820 137690 10988 2996.5 8490 RHOB MWD G/CM 1.972 3.225 2.32533 10871 3068.5 8503.5 DRHO MWD G/CM -0.145 0.394 0.0565802 10871 3068.5 8503.5 PEF MWD BARN 1.02 12.91 3.31158 10990 3009 8503.5 First Reading For Entire File......... .2996.5 Last Reading For Entire File.......... .8579 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/30 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/05/30 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT 2 header data for each bit run in separate files. 2 .5000 START DEPTH 2996.5 2996.5 STOP DEPTH 6600.0 6600.0 NPHI 2996. ) 6600.0 PEF 3009.0 6600.0 RPD 3044.5 6600.0 FET 3044.5 6600.0 RPM 3044.5 6600.0 RPS 3044.5 6600.0 RPX 3044.5 6600.0 GR 3052.0 6600.0 DRHO 3068.5 6600.0 RHOB 3068.5 6600.0 ROP 3083.5 6600.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet ') ll-MAY-03 Insite 66.37 Memory 6600.0 3083.0 6600.0 51.3 56.8 TOOL NUMBER 155790 136749 59952 105918 8.500 3070.0 LSND 11.80 45.0 9.0 350 3.0 3.000 1.780 3.200 4.100 76.0 132.8 76.0 76.0 Data Reference Point. . . . )....... . Undefined ) Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 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 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2996.5 6600 4798.25 7208 2996.5 6600 ROP MWD020 FT/H 24.4 3051.15 202.266 7034 3083.5 6600 GR MWD020 API 43.4 203.52 115.139 7097 3052 6600 RPX MWD020 OHMM 0.12 2000 4.82138 7112 3044.5 6600 RPS MWD020 OHMM 0.06 171.5 4.17805 7112 3044.5 6600 RPM MWD020 OHMM 0.11 2000 7.78025 7112 3044.5 6600 RPD MWD020 OHMM 0.07 2000 17.5038 7112 3044.5 6600 FET MWD020 HOUR 0.1569 120.782 1.73059 7112 3044.5 6600 NPHI MWD020 PU-S 14.08 58.81 34.8824 7208 2996.5 6600 FCNT MWD020 CNTS 573.8 2509.5 918.473 7208 2996.5 6600 NCNT MWD020 CNTS 113125 194820 134984 7208 2996.5 6600 RHOB MWD020 G/CM 1.972 2.916 2.26464 7064 3068.5 6600 DRHO MWD020 G/CM -0.145 0.335 0.063268 7064 3068.5 6600 PEF MWD020 BARN 1.02 12.91 2.33629 7183 3009 6600 First Reading For Entire File......... .2996.5 Last Reading For Entire File.......... .6600 File Trailer Service name............ .STSLIB.002 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/30 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 RPM PEF ROP GR RPS RPD FET NPHI FCNT NCNT RHOB DRHO RPX $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 6600.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 8539.0 8503.5 8579.0 8547.0 8539.0 8539.0 8539.0 8490.0 8490.0 8490.0 8503.5 8503.5 8539.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 15-MAY-03 Insite 66.37 Memory 8579.0 6600.0 8579.0 32.8 51.1 TOOL NUMBER 155790 136749 120993 179954 8.500 3070.0 LSND 11.80 49.0 10.1 600 4.4 1.800 1.070 1.300 2.500 78.0 136.4 78.0 78.0 HOLE CORRECTION (IN) ~ ) ) # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6600.5 8579 7589.75 3958 6600.5 8579 ROP MWD030 FT/H 2.25 287.4 149.217 3958 6600.5 8579 GR MWD030 API 58.19 414.47 128.302 3894 6600.5 8547 RPX MWD030 OHMM 0.93 34.39 3.4838 3878 6600.5 8539 RPS MWD030 OHMM 0.96 36.9 3.52424 3878 6600.5 8539 RPM MWD030 OHMM 1.02 34.4 3.52477 3878 6600.5 8539 RPD MWD030 OHMM 1.05 33.81 3.74432 3878 6600.5 8539 FET MWD030 HOUR 0.1678 93.4084 0.660814 3878 6600.5 8539 NPHI MWD030 PU-S 16.18 40.61 29.882 3780 6600.5 8490 FCNT MWD030 CNTS 813.8 2274.7 1144.11 3780 6600.5 8490 NCNT MWD030 CNTS 125688 183959 142851 3780 6600.5 8490 RHOB MWD030 G/CM 2.108 3.225 2.43795 3807 6600.5 8503.5 DRHO MWD030 G/CM -0.052 0.394 0.0441707 3807 6600.5 8503.5 PEF MWD030 BARN 2.16 10.84 5.15175 3807 6600.5 8503.5 First Reading For Entire File......... .6600.5 Last Reading For Entire File.......... .8579 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 ) ) Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/05/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/05/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File