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Home My WebLink About203-080 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-17A 50-103-20448-01 203080_3S-17A_IBC-CBL_23Jul2023 203080_3S-17A_IBC-CBL_25Apr2023 203080_3S-17A_Perf_07May2023 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 2560' 7" L-80 6076' 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 12-1/4" 82 sx ArcticCrete Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: Gas-Oil Ratio:Choke Size: 68 bbls 15.8 ppg Cement (milled for log) Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 115 bbls 15.8 ppg PermaFrost CementSurface- 3275' 9-5/8" x 7" 22 bbls 15.8 ppg Cement 223 bbls 15.8 ppg Class G Cement (milled top 56')Surface-5273' (7" casing) 9.5 bbls 15.8 ppg Class GOA Top off 2 bbls CementPC top off 5273'-5874' Perforations: 8643-8666' MD and 5876-5891' TVD (Cemented) 30' 3275'29' 30' 5498'-5874' Plugged and Abandoned 8938' SIZE DEPTH SET (MD) 27' 62.5# 40# 108' 27' 8311' MD/ 5655' TVD PACKER SET (MD/TVD)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 5995483 SETTING DEPTH TVD 5995356 TOP HOLE SIZE 8344'3-1/2" 29'465 sx AS Lite, 326 sx AS 42" AMOUNT PULLED 470978 470793 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 1639' MD/ 1534' TVD 6160' MD/ 4285' TVD CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, CASING 2533' FNL, 1130' FEL, Sec. 18, T12N, R8E, UM 1077' FNL, 1666' FEL, Sec. 13, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476130 5993883 951' FNL, 1482' FEL, Sec. 13, T12N, R7E, UM SURFACE 8949' MD/ 6084' TVD ADL0025544, ADL0380107 ALK 2639 50-103-20448-01-00 KRU 3S-17A April 29, 2003 May 1, 2003 9. Ref Elevations: KB: 56' 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 9/25/2023 203-080/ 323-190 TUBING RECORD 300 sx GasBlok8-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 12:22 pm, Oct 20, 2023 Abandoned 9/25/2023 JSB RBDMS JSB 110323 xGDSR-11/16/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1639' 1534' 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 Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Formation Name at TD: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Plugged and Abandoned Authorized Name and INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Plugged and Abandoned Authorized Title: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2023.10.17 11:41:05 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC) 8,323.0 3S-17A 3/22/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pump 223 BBL CMT PLUG TO SURFACE 3S-17A 9/5/2023 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 40.0 3,275.0 2,560.2 40.00 L-80 BTC PRODUCTION 7 6.28 40.0 8,937.8 6,075.9 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 29.1 Set Depth … 8,343.7 Set Depth … 5,676.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 29.1 29.1 0.17 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 498.8 497.6 6.84 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 8,211.9 5,589.9 49.14 GAS LIFT 5.968 CAMCO MMG 2.920 8,257.2 5,619.6 49.06 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 8,295.0 5,644.4 48.97 SEAL ASSY 5.875 LOCATOR SUB & PBR 12 ' SEAL ASSEMBLY (SPACED OUT) 2.970 8,297.0 5,645.7 48.96 PBR 5.875 BAKER 80-40 PBR BAKER 80-40 2.970 8,310.1 5,654.3 48.88 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 3.250 8,311.3 5,655.1 48.87 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 8,316.5 5,658.5 48.85 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.710 8,335.7 5,671.2 48.74 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 8,342.7 5,675.8 48.70 WLEG 4.530 WLEG w/ SHEAR OUT SUB 2.982 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 40.0 40.0 0.23 MARKER PLATE 9/25/2023 0.000 54.4 54.4 0.31 CIBP 5.61" CIBP MID-ELEMENT AT 55.2', OAL 1.6' LEGACY HPBP 000- 5610- 002 9/17/2023 0.000 5,882.2 4,124.7 54.58 CIBP 5.61" CIBP MID-ELEMENT AT 5883', OAL 1.6' LEGACY HPBP 000- 5610- 002 5/4/2023 0.000 8,273.0 5,630.0 49.03 CUT WELLTEC MECHANICAL TUBING CUT, TATTLE-TAIL INDICATED 3.62" BLADE TRAVEL 3/24/2023 2.992 8,333.0 5,669.4 48.75 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/30/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,211.9 5,589.9 49.14 1 GAS LIFT OPEN 3/22/2023 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,707.0 5,732.5 4,022.1 4,037.1 5/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,734.0 5,774.0 4,037.9 4,061.5 5/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,775.5 5,815.5 4,062.4 4,085.8 5/6/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,817.0 5,857.0 4,086.7 4,110.1 5/6/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 8,643.0 8,666.0 5,875.7 5,891.2 UNIT D, 3S-17A 5/7/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg phase, random orient Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,324.0 8,343.0 5,663.5 5,676.0 Cement Plug Pumped 29 bbls of 15.8 ppg cement. 27 bbls below retainer and 2 bbls on top. 7/30/2022 40.0 56.0 40.0 56.0 Plug – Plug Back / Abandonment Plug 2 bbls from CIBP to surface 56.0 5,273.0 56.0 3,762.6 Plug – Plug Back / Abandonment Plug 223 BBL OF 15.8 PPG CEMENT 9/5/2023 5,273.0 5,873.0 3,762.6 4,119.4 Plug – Plug Back / Abandonment Plug 22 BBL OF 15.8 PPG CEMENT 9/2/2023 3S-17A, 10/17/2023 11:20:34 AM Vertical schematic (actual) PRODUCTION; 40.0-8,937.8 IPERF; 8,643.0-8,666.0 Plug – Plug Back / Abandonment Plug; 8,343.0 ftKB CEMENT RETAINER; 8,333.0 Cement Plug; 8,324.0 ftKB PACKER; 8,311.3 CUT; 8,273.0 CIBP; 5,882.2 APERF; 5,817.0-5,857.0 APERF; 5,775.5-5,815.5 Cement Squeeze; 5,707.0 ftKB APERF; 5,734.0-5,774.0 APERF; 5,707.0-5,732.5 Plug – Plug Back / Abandonment Plug; 5,273.0 ftKB SURFACE; 40.0-3,275.0 CONDUCTOR; 40.0-108.0 Plug – Plug Back / Abandonment Plug; 56.0 ftKB CIBP; 54.4 MARKER PLATE; 40.0 Plug – Plug Back / Abandonment Plug; 40.0 ftKB KUP INJ KB-Grd (ft) 33.46 RR Date 5/4/2003 Other Elev… 3S-17A ... TD Act Btm (ftKB) 8,949.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044801 Wellbore Status INJ Max Angle & MD Incl (°) 55.63 MD (ftKB) 2,539.17 WELLNAME WELLBORE3S-17A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,343.0 8,766.0 5,676.0 5,958.6 Plug – Plug Back / Abandonment Plug Pumped 29 bbls of 15.8 ppg cement. 27 bbls below retainer and 2 bbls on top. 7/30/2022 5,707.0 5,857.0 4,022.1 4,110.1 Cement Squeeze PWC - 68 bbls 15.8ppg cement 6/30/2023 3S-17A, 10/17/2023 11:20:35 AM Vertical schematic (actual) PRODUCTION; 40.0-8,937.8 IPERF; 8,643.0-8,666.0 Plug – Plug Back / Abandonment Plug; 8,343.0 ftKB CEMENT RETAINER; 8,333.0 Cement Plug; 8,324.0 ftKB PACKER; 8,311.3 CUT; 8,273.0 CIBP; 5,882.2 APERF; 5,817.0-5,857.0 APERF; 5,775.5-5,815.5 Cement Squeeze; 5,707.0 ftKB APERF; 5,734.0-5,774.0 APERF; 5,707.0-5,732.5 Plug – Plug Back / Abandonment Plug; 5,273.0 ftKB SURFACE; 40.0-3,275.0 CONDUCTOR; 40.0-108.0 Plug – Plug Back / Abandonment Plug; 56.0 ftKB CIBP; 54.4 MARKER PLATE; 40.0 Plug – Plug Back / Abandonment Plug; 40.0 ftKB KUP INJ 3S-17A ... WELLNAME WELLBORE3S-17A SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-17A Plug and Abandonment October 9, 2023 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-17A, commencing operations on April 25, 2023 and completing the Plug and Abandonment on September 25, 2023. After successful suspension of the Kuparuk formation and rig operations to remove tubing, a bond log was run to determine top of cement in the 7” x OH annulus and to establish intervals for Perf/Wash/Cement operations. A CIBP was set at 5,883ft KB, the production casing was perforated from 5,707 to 5,857ft KB, then wash and cement operations performed across the interval. Cement in the production casing was milled to the CIBP and a bond log run to validate that adequate cement had been placed in the 7” x OH annulus. After this step, the well was cemented to surface inside both the 7” production casing and 7” x 9-5/8” annulus. The well was then excavated below original ground level and the tree and wellhead removed. Due to elevated gas/LEL readings inside the production casing after wellhead removal, cement was drilled out of the production casing to a depth of 56ft below the well stub, then a CIBP was installed. After the CIBP was set, a cement top job was performed to bring cement back to surface. 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. DTTMSTART JOBTYP SUMMARYOPS 4/24/2023 ACQUIRE DATA SLB ELINE MOVE EQUIPMENT FROM 3S-10 TO 3S-17A, PREPARE AND RIGUP TO RUN JUNK BASKET, TAG TUBING TOP AT 8269' ***JOB CONTINUED*** 4/25/2023 ACQUIRE DATA SLB ELINE POOH WITH JUNK BASKET/GUAGE RING, LOG IBC-CBL FOR CEMENT EVALUATION, MAIN AND REPEAT PASSES FROM 8260'-5400', UPLOAD DATA FOR RUSH PROCESSING ***LOG COMPLETE, WAIT ON PERF INTERVALS TO BE PICKED FROM TOWN*** 5/4/2023 ACQUIRE DATA SET 7" LEGACY CAST IRON BRIDGE PLUG AT 5883' (MID-ELEMENT) JOB COMPLETE, READY FOR CASING PERFORATIONS 5/6/2023 ACQUIRE DATA SLB E-LINE PERFORATING W/ 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE. GUN 1 PERFORATED INTERVAL = 5837' - 5857'. CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5829.7'. GUN 2 PERFORATED INTERVAL = 5817' - 5837'. CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5809.7' GUN 3 PERFORATED INTERVAL = 5795.5' - 5815.5'. CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5788.2' GUN 4 PERFORATED INTERVAL = 5775.5' - 5795.5'. CCL TO TOP SHOT = 7.3', CCL STOP DEPTH=5768.2' GUN 5 PERFORATED INTERVAL = 5754'-5774'. CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5746.7' OPERATIONS CONTINUED 5/7/2023 ACQUIRE DATA OPERATIONS CONTINUED FROM PREVIOUS DAY GUN 6 PERFORATED INTERVAL = 5734' - 5754'. CCL TO TOP SHOT = 7.3'. CCL STOP DEPTH = 5726.7' GUN 7 PERFORATED INTERVAL = 5712.5' - 5732.5'. CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5705.2' GUN 8 PERFORATED INTERVAL = 5707' - 5712.5'. CCL TO TOP SHOT = 11.7', CCL STOP DEPTH = 5695.3'. DRIFT CLEANLY W/ JUNK BASKET AND 5.90" GAUGE RING TO TOP OF CIBP AT 5882.2'. JOB COMPLETE, READY FOR COIL TUBING 5/18/2023 ACQUIRE DATA PERFORM DOWN SQUEEZE ON 9 5/8" X 7" ANNULUS, LRS PERFORMS INJECTIVITY TEST (.1,2,3 & 4 BPM), HES PUMPS 115 BBLS OF 15.8# PERMAFROST CEMENT (SURFACE TO CASING SHOE), JOB COMPLETE. 6/29/2023 ACQUIRE DATA CUT 5111' OF COIL. MIRU. CHANGE PACK OFF'S. STACK UP LUBRICATOR. 6/30/2023 ACQUIRE DATA R/U. PT HARDLINE AND SURFACE EQUIPMENT. DRIFT AND TAG 5858' CTMD / 5874' RKB. PERFORM PERF WASH PASSES WITH HYDRAWELL TOOL. PUMPED 68 BBLS OF 15.8 PPG CEMENT AT 1.65 BPM AT 5 FPM ACROSS PERF'S WITH HYDRAWELL. TOOL. TOOL PLUGGED UP DURING CLEANOUT. POOH TO P/U A NOZZLE. RBIH TO FREEZE PROTECT 120 BBLS OF DIESEL. RDMO 7/4/2023 ACQUIRE DATA PRE STATE WITNESSED TAG TOC @ 5498' SLM.PERFORM PASSING MIT TO 1500 PSI. READY FOR SW TEST. 7/9/2023 ACQUIRE DATA STATE WITNESSED (ADAM EARL) TAG TOC @ 5513' SLM. PERFROM STATE WITNESS MITT TO 1500 PSI. READY FOR COIL. 7/14/2023 SUPPORT OTHER OPERATIONS MIRU. HARDLINE CREW RIG UP TO WELL HEAD R/U COIL UNIT #6 AND M/U BHA #1 TCC 25000K, ALL GOOD SECURE WELL FOR THE NIGHT 7/14/2023 ACQUIRE DATA MIRU. HARDLINE CREW RIG UP TO WELL HEAD R/U COIL UNIT #6 AND M/U BHA #1 TCC 25000K, ALL GOOD SECURE WELL FOR THE NIGHT 7/15/2023 ACQUIRE DATA R/U,M/U MILL.STAB ON PT/4500 PSI RIH TAG UP 5525' CMT MILL F/ 5525' T/ 5762' TOT 237' POOH L/D MILL AND INSTALL NIGHT CAP 3S-17A Plug and Abandon Summary of Operations 7/15/2023 SUPPORT OTHER OPERATIONS R/U,M/U MILL.STAB ON PT/4500 PSI RIH TAG UP 5525' CMT MILL F/ 5525' T/ 5762' TOT 237' POOH L/D MILL AND INSTALL NIGHT CAP 7/16/2023 ACQUIRE DATA PJSM M/U BHA # 2 W/ MILL RIH TAG UP @ 5756' AND MILL T/ 5852 'CTM DUE TO STALLS POOH L/D BHA #2 M/U BHA #3 W /UNDERREAMER 6.25 OD AND JUNK MILL 3.80 OD RIH DRY TAG UP @ 5852' ATTEMPT TO MAKE HOLE NO GO BACK REAM F/5852' T/SURF F/P 2000' L/D BHA INSTALL NIGHT CAP 7/16/2023 SUPPORT OTHER OPERATIONS PJSM M/U BHA # 2 W/ MILL RIH TAG UP @ 5756' AND MILL T/ 5852 'CTM DUE TO STALLS POOH L/D BHA #2 M/U BHA #3 W /UNDERREAMER 6.25 OD AND JUNK MILL 3.80 OD RIH DRY TAG UP @ 5852' ATTEMPT TO MAKE HOLE NO GO BACK REAM F/5852' T/SURF F/P 2000' L/D BHA INSTALL NIGHT CAP 7/21/2023 ACQUIRE DATA JOB PREP FOR IBC/DSLT. SPOT IN EQUIPMENT, MU 7" PCE AND LAY DOWN 7/22/2023 ACQUIRE DATA DRIFT WITH 5.91" GAUGE RING JUNK BASKET. TAGGED HIGH AT 5844' (CIBP AT 5882'). RECOVERED CEMENT SHAVINGS IN JUNK BASKET. JOB IN PROGRESS 7/23/2023 ACQUIRE DATA LOG IBC/DSLT FROM 5,834' TO 4,800'. PERFORM LOGGING PASSES AT 5DEG 6", 5DEG 3" AND 5DEG 1.5" RESOLUTIONS. DOMAIN CHAMPION REQUESTS TO LOG 5 DEG 0.6" RESOLUTION DUE TO STICK AND SLIP. IBC SUB STOPPED ROTATING WHILE ATTEMPTING 5 DEG 0.6" REPEAT PASS. POOH. DATA SENT IN FOR FULL-IMAGE RUSH PROCESSING. JOB COMPLETE 9/2/2023 ACQUIRE DATA MIRU CTU 6, PERFORM BOP TEST. TAG CIBP @ 5852' CTMD (5873' RKB). PUMP 22.0 BBL 15.8 PPG CEMENT. TOC @ 5280' (5301' RKB). FREEZE PROTECT FROM 3200' W/ 122 BBL S. DIESEL. WAIT PER PROCEDURES FOR CEMENT TAG & TEST. RD & MOVE TO 3S-06. JOB IN PROGRESS. 9/4/2023 ACQUIRE DATA STATE WITNESS TAG TOC @ 5273' RKB, STATE WITNESS MIT TO 1500 PSI (PASSED) 9/4/2023 ACQUIRE DATA WAIT FOR HARDLINE CREW TO REMOVE FLOW TEE & X-OVERS FROM 3S-06 AND RU SAME ON 3S-17. MIRU & CALL OUT CEMENT CREW.. 9/5/2023 ACQUIRE DATA TAG TOC AT 5269' CTMD, CORRECT DEPTH TO 5280' RKB. LAYED IN 223 BBLS, 15.8 PPG, CLASS G CEMENT IN 7" CASING F/ 5280' RKB TO SURFACE. SAW GOOD CEMENT AT TANKS, SAMPLE WAS 15.6 PPG. WASH UP LUBE, BOP'S, TREE, SURFACE LINES WITH 10 BBLS OF POWERVIS FOLLOWED BY FRESH WATER UNTIL CLEAN RETURNS AT TANKS. READY FOR DHD IN 48 HRS. 9/8/2023 SUPPORT OTHER OPERATIONS (P&A) T/I AND OA DDT TO 0 PSI COMPLETE, TUBING/IA TOC = ~5' 7", OA TOC UNKNOWN. 9/9/2023 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS. NES REMOVED DOUBLE SWAB, EVACUATED FLUID FROM TOP OF CEMENT IN WELL BORE. TOC 13'-11". REMOVED IA VALVES. PREPARE OA FOR CEMENT TOP JOB. 9/10/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- OA TOPPED OFF WITH 9.5 BBLS OF 15.8 PPG CLASS G PORTLAND CEMENT. REFERENCE MARK ON WELL HEAD IC FLANGE SHOWS DOWN 2' TO ORIGINAL TUNDRA. REFERENCE MARK TO BOTTOM OF STEEL CELLAR IS 6'-2". 9/11/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- OA TOC @ SURFACE. READY FOR WELLHEAD REMOVAL. CEMENT TRAILER MAINTENANCE (COMPLETE) 9/12/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- CUT AND REMOVED 10'1" OF WELLHEAD & CONDUCTOR. TOP OF WELL STUB IS 42" BELOW OG. ENCOUNTERED WATER ISSUES DURING CELLAR PREPARATION FOR REMOVAL. JOB ON HOLD UNTIL WATER ISSUE IS MANAGED COMPLETELY. 9/13/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- DEWATER STEEL CELLAR, REMOVED 50 BBLS OF GROUND WATER. APPEARED TO BE SLOWING DOWN. WAIT FOR COIL & HARDLINE TO MOVE OFF OF 3S-18 FOR CAN INSTALLATION. 9/14/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- INSTALLED 8' Dx16' L SHORE CAN AROUND 6' STEEL CELLAR TO `13' DEPTH. NEXT STEP - REMOVE WATER AND STEEL CELLAR , BEGIN EXCAVATION WITHIN SHORE CAN. 9/15/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- REMOVED FLUID/WATER FROM CELLAR. JOB POSTPONED FOR PATH FORWARD DUE TO LELs IN THE PC. AWAITING AOGCC APPROVAL TO PROCEED WITH AIR DRILL TO DRILL OUT PC CEMENT. 9/16/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- DRILLED OUT PC CEMENT TO 56' BELOW WELL STUB. AWAITNG AOGGC APPROVED PLAN FORWARD. AOGGC INSPECTOR BOB NOBLE WITNESS MEASUREMENT AND GAS READINGS. 9/17/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS - ELINE DRIFTED W/ 5.935" GR, SET 7" CIBP @ 56', OBTAINED GAS READING PRE AND POST PLUG SET. GAS READING 20.9% O2, 0% LELs, 0 PPM SUBMITTED AOGCC WITNESS NOTIFICATION FOR PLUG DEPTH. WIRE WHEELED 8' D SHORE CAN FOR INSPECTION BY MISTRAS, PRIOR TO FUTURE CAN EXTRACTION. WAIT FOR PLAN FORWARD FROM TOWN. 9/17/2023 ACQUIRE DATA DRIFT WITH CCL AND 5.935" GAUGE RING TO 56', LOCATE CASING COLLAR AT 38' SET 7" CIBP MID-ELEMENT AT 55.2' (TOP OF PLUG AT 54.4', BOTTOM OF PLUG AT 56.0') JOB COMPLETE 9/18/2023 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- STAND BY FOR APPROVED PLAN AND CONFIRMATION TO PROCEED FROM AOGCC. APPROVAL GRANTED VIA EMAIL @1555 PM. RETURN IN AM TO CEMENT UP PC FROM CIBP TO SURFACE. 9/19/2023 ACQUIRE DATA (P&A) IN-PROGRESS,TOPPED OFF PRODUCTION CASING W/2 BBL CEMENT, CUT & REMOVED STEEL CELLAR. BEGIN EXCAVATION FOR WELL STUB REMOVAL 9/20/2023 ACQUIRE DATA (P&A) IN-PROGRESS, EXCAVATE 14' DOWN FROM TOP OF SHORING CAN. PREP FOR CUT. 9/21/2023 SUPPORT OTHER OPERATIONS (P&A) CUT THE WELLHEAD BELOW OG (IN PROGRESS) 9/22/2023 SUPPORT OTHER OPERATIONS (P&A) CUT WELL BELOW OG (IN PROGRESS) 9/23/2023 SUPPORT OTHER OPERATIONS (P&A) CUT THE WELL BELOW OG (COMPLETE) 9/24/2023 SUPPORT OTHER OPERATIONS (P&A) AOGCC (GUY COOK) WITNESS THE TOC (COMPLETE) WELD MARKER PLATE (COMPLETE) REMOVE SHORING AND BACKFILLED THE EXCAVATION (COMPLETE) 9/25/2023 SUPPORT OTHER OPERATIONS (P&A) AOGCC BRIAN BIXBY APPROVED THE FINAL SITE CLEARANCE 2023-0924_Location_KRU_3S-17A_bb Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: September 26, 2023 P. I. Supervisor FROM: Brian Bixby SUBJECT: Site Clearance Petroleum Inspector KRU 3S-17A ConocoPhillips Alaska Inc. PTD 2030800; Sundry 323-190 9/24/2023: Final site clearance inspection. Stopped by location and took pictures of site after well had been buried. Everything looked good. Location was verified by using the pad map. Attachments: Photos (4)    2023-0924_Location_KRU_3S-17A_bb Page 2 of 3 Location Inspection – KRU 3S-17A (PTD 2030800) Photos by AOGCC Inspector B. Bixby 9/24/2023 2023-0924_Location_KRU_3S-17A_bb Page 3 of 3 2023-0924_Surface_Abandonment_Final_KRU_3S-17A_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 9/24/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-17A ConocoPhillips Alaska Inc PTD 2030800; Sundry 323-190 9/24/2023: I traveled to location with AOGCC Petroleum Inspector Josh Hunt to witness the casing cut-off and the identification plate installation on KRU 3S-17A. We met with CPAI representative Brennen Green and discussed the job. We confirmed the casing was full to surface with good hard cement. We also confirmed the information on the identification plate was correct. We then took measurements and confirmed the casing was cut approximately 8.5 feet below tundra level. We gave Mr. Green the approval to bury the casing/well after we witnessed the installation of the identification plate and ensured it was welded onto the casing without any breaks in the weld. Attachments: Photos (6)     2023-0924_Surface_Abandonment_Final_KRU_3S-17A_gc Page 2 of 4 Surface Abandonment (Final) – KRU 3S-17A (PTD 2030800) Photos by AOGCC Inspector G. Cook 9/24/2023 2023-0924_Surface_Abandonment_Final_KRU_3S-17A_gc Page 3 of 4 2023-0924_Surface_Abandonment_Final_KRU_3S-17A_gc Page 4 of 4 2023-0922_Surface_Abandon_LEL-concerns_KRU_3S-17A_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 9/22/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment – LEL Concerns Petroleum Inspector KRU 3S-17A ConocoPhillips Alaska Inc. PTD 2030800; Sundry 323-190 9/21/2023: I traveled out to location with AOGCC Petroleum Inspector Josh Hunt to check the status of the weld-let valves on the casing of KRU 3S-17A since high LEL levels were again found in the well and reported to AOGCC. I requested the weld-let valves be shut; CPAI representative Brennen Green said CPAI Wells Group Engineer Jill Simek told him to leave the valves open to atmosphere all night. I called and spoke to AOGCC Engineer Victoria Loepp and informed her about what was going on with the well and asked her contact Jill Simek about closing the valves for the night and not to be opened until my arrival in the morning. Victoria Loepp requested the valves be closed, via email to Jill Simek, so we could witness the LEL levels this morning. This is so we could see if the LEL level had come back up after the well had been left open to atmosphere and been purged with nitrogen. The valves had not been closed and were open to atmosphere when we arrived. 9/22/2023: Upon arrival at KRU 3S-17A the weld-let valves were found open, and the casing had been purged with nitrogen the night before. In addition, there were fans circulating the air in the cellar via heater hoses from the pad level. I again requested CPAI to shut in the valves after the confined space entry permit was put into effect. The LEL level was to be captured prior to the valves being shut. At 08:00 AM the LEL level from the three weld-lets were: 45.5%, 30.4% and 6.8%. After speaking with Victoria and telling her what we had found this morning, we explained that we would like to have low pressure gauges installed on all three weld- lets. After Victoria approved of the idea, we instructed Brennen Green to install the gauges. This is so the gauges could be monitored to see if the gas builds pressure. We left location after instructing Mr. Green to not proceed with the P&A until he heard back from us on what would be the next step taken to deal with the LEL issue. After leaving location I received a call from CPAI’s Jill Simek. We spoke about the LEL issue discussing possibilities of the origin of the gas and concerns regarding the gas. I       2023-0922_Surface_Abandon_LEL-concerns_KRU_3S-17A_gc Page 2 of 4 told her, as I had told Victoria Loepp, that I believe using a cutting torch to cut the casing is not a good idea with the history of LELs with this well. I told her I felt a saw for cutting casing would be a safer approach. I also told her, as I had told Victoria, I thought there was a possibility that the gas was not entrained in the cement, as CPAI has been suggesting, and could be coming from below the cast iron bridge plug. The bridge plug was previously set to isolate LELs so the P&A could proceed. According to CPAI’s Roger Mouser (Brennan Green’s alternate) who was present before the bridge plug was installed, the LEL level was over the limit of the gas detection device (the device showed 99.9% LEL). Roger Mouser had also told me that after the bridge plug was in place that the LEL level was at zero, which is partly why I think the gas is now migrating past the bridge plug and into the cement above it. Victoria granted permission for CPAI to check the pressure and the LEL level and if they were at zero psi and zero percentage to move forward with the casing cut. The pressure and percentage were checked at 13:00 PM, three hours after the gauges were installed. The gauges showed zero pressure, but the LEL level was over-limit for the gas detection device again which detects percentages up to 99.9%. Victoria called me and told me CPAI would be sending a plan forward to complete the P&A and she would discuss it with me and Jim Regg, my supervisor, before giving CPAI the approval to proceed. Attachments: Photos (5)   2023-0922_Surface_Abandon_LEL-concerns_KRU_3S-17A_gc Page 3 of 4 Surface Abandonment – LEL Concerns KRU 3S-17A (PTD 2030800) Photos by AOGCC Inspector G. Cook 9/22/2023 2023-0922_Surface_Abandon_LEL-concerns_KRU_3S-17A_gc Page 4 of 4 2023-0916_Surface_Abandon_KRU_3S-17A_bn Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 9/16/2023 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-17A ConocoPhillips Alaska Inc PTD 2030800; Sundry 323-190 9/16/2023: I traveled to CPA’s KRU 3S-17A well to inspect cement removal (for remedial surface cementing) and a LEL reading on the well. I met with CPA representative Roger Mouser and we went over what they had done and what they wanted me to inspect. They had a high gas LEL reading in the 7-inch production casing. CPA was instructed by AOGCC to drill 50 feet of cement out of the production casing. They ran a tape measure down inside the 7-inch production casing and top of cement was found to be 56 feet from surface. The LEL reading was still found to be high in the production casing. All other strings of pipe looked to be full of hard cement. Attachments: Photos (2)       2023-0916_Surface_Abandon_KRU_3S-17A_bn Page 2 of 2 Surface Abandonment – KRU 3S-17A (PTD 2030800) Photos by AOGCC Inspector B. Noble 9/16/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:8949 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@ 3275 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8938 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 8344 Feet Tbg Cut@ 8273 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 5882 ft 5273 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1670 1565 1535 IA OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: John Hansen Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to KRU 3S-17A to witness a wireline tag and pressure test for P&A operations. John Hansen was the CPAI rep. on location. Tagged top of cement @ 5,273 ft MD with a tool string consisting of 10 feet of 1 7/8-inch weight bar, oil jars, spanges, 2 1/2-inch centralizer, and sample bailer. Hanging wt was 175lbs. Bailer produced a good sample of setup cement. Pressure test went as per chart above. September 4, 2023 Adam Earl Well Bore Plug & Abandonment KRU 3S-17A ConocoPhillips Alaska Inc. PTD 2030800; Sundry 323-190 none Test Data: P Casing Removal: rev. 3-24-2022 2023-0904_Plug_Verification_KRU_3S-17A_ae              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:8949 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@ 3275 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8911 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 8344 Feet Tbg Cut@ 8273 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 5887 ft 5513 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1660 1600 1570 IA OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to KRU 3S-17A to witness a tag and pressure test for P&A. The wireline tag was first with the tool srting consisting of weight bar, spangs, and a 2-inch sambler bailer. Hanging weight was 200lbs. Top of cement was tagged @ 5,513 ft MD. The sample bailer brought back a good sample of mostly set-up cement. Pressure test went as per chart above. July 9, 2023 Adam Earl Well Bore Plug & Abandonment KRU 3S-17A ConocoPhillips Alaska Inc PTD 2030800; Sundry 323-190 none Test Data: P Casing Removal: rev. 3-24-2022 2023-0709_Plug_Verification_KRU_3S-17A_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 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 2560' 7" L-80 6076' 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 12-1/4" 82 sx ArcticCrete Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 30' 3275'29' 30' SUSPENDED Perforations: 8643-8666' MD and 5876-5891' TVD (Cemented) 8938' SIZE DEPTH SET (MD) 27' 62.5# 40# 108' 27' 8311' MD/ 5655' TVD PACKER SET (MD/TVD)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 5995483 SETTING DEPTH TVD 5995356 TOP HOLE SIZE 8344'3-1/2" 29'465 sx AS Lite, 326 sx AS 42" AMOUNT PULLED 470978 470793 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 1639' MD/ 1534' TVD 6160' MD/ 4285' TVD CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, CASING 2533' FNL, 1130' FEL, Sec. 18, T12N, R8E, UM 1077' FNL, 1666' FEL, Sec. 13, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476130 5993883 951' FNL, 1482' FEL, Sec. 13, T12N, R7E, UM 8324' MD/ 5663' TVD 8949' MD/ 6084' TVD ADL0025544, ADL0380107 ALK 2639 50-103-20448-01-00 KRU 3S-17A April 29, 2003 May 1, 2003 9. Ref Elevations: KB: 56' 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 4/13/2023 TUBING RECORD 300 sx GasBlok8-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 14. Permit to Drill Number / Sundry: 203-080/ 323-087 RECEIVED by James Brooks on 5/10/2023 at 5:45 PM Suspended 4/13/2023 JSB RBDMS JSB 051823 xGDSR-6/1/23 KRU 3S-17A 4/13/2023 WCB 2023-07-17 Suspended Kuparuk River Field/ Kuparuk River Oil Pool Susp 203-080/ 323-087 Permit to Drill Number / Sundry Service Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1639' 1534' 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 Senior 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 - Suspended 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 - Suspended 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: RKB (TOC) 8,323.0 3S-17A 3/22/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Add Perforations 3S-17A 5/7/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/21/2010 ninam General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / WKM / GEN 5 / 5M TREE CAP CONNECTION: TO 5.75"" ACME with 3.5"" EUE 8RD THREAD 5/3/2003 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 29.4 3,275.0 2,560.2 40.00 L-80 BTC PRODUCTION 7 6.28 26.9 8,937.8 6,075.9 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.7 Set Depth … 8,343.7 Set Depth … 5,676.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.7 24.7 0.14 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 498.8 497.6 6.84 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 8,211.9 5,589.9 49.14 GAS LIFT 5.968 CAMCO MMG 2.920 8,257.2 5,619.6 49.06 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 8,295.0 5,644.4 48.97 SEAL ASSY 5.875 LOCATOR SUB & PBR 12 ' SEAL ASSEMBLY (SPACED OUT) 2.970 8,297.0 5,645.7 48.96 PBR 5.875 BAKER 80-40 PBR BAKER 80-40 2.970 8,310.1 5,654.3 48.88 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 3.250 8,311.3 5,655.1 48.87 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 8,316.5 5,658.5 48.85 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.710 8,335.7 5,671.2 48.74 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 8,342.7 5,675.8 48.70 WLEG 4.530 WLEG w/ SHEAR OUT SUB 2.982 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) 5,882.2 4,124.7 54.58 CIBP 5.61" CIBP MID-ELEMENT AT 5883', OAL 1.6' LEGACY HPBP 000- 5610- 002 5/4/2023 0.000 8,273.0 5,630.0 49.03 CUT WELLTEC MECHANICAL TUBING CUT, TATTLE-TAIL INDICATED 3.62" BLADE TRAVEL 3/24/2023 2.992 8,324.0 5,663.5 48.80 TUBING PLUG Pumped 29 bbls of 15.8 ppg cement. 27 bbls below retainer and 2 bbls on top. 7/30/2022 0.000 8,333.0 5,669.4 48.75 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/30/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,211.9 5,589.9 49.14 1 GAS LIFT OPEN 3/22/2023 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,707.0 5,732.5 4,022.1 4,037.1 5/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,734.0 5,774.0 4,037.9 4,061.5 5/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,775.5 5,815.5 4,062.4 4,085.8 5/6/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,817.0 5,857.0 4,086.7 4,110.1 5/6/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 8,643.0 8,666.0 5,875.7 5,891.2 UNIT D, 3S-17A 5/7/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg phase, random orient 3S-17A, 5/10/2023 9:44:46 AM Vertical schematic (actual) PRODUCTION; 26.9-8,937.8 IPERF; 8,643.0-8,666.0 TUBING PLUG; 8,324.0 CEMENT RETAINER; 8,333.0 PACKER; 8,311.3 CUT; 8,273.0 CIBP; 5,882.2 APERF; 5,817.0-5,857.0 APERF; 5,775.5-5,815.5 APERF; 5,734.0-5,774.0 APERF; 5,707.0-5,732.5 SURFACE; 29.4-3,275.0 CONDUCTOR; 30.0-108.0 KUP INJ KB-Grd (ft) 33.46 RR Date 5/4/2003 Other Elev… 3S-17A ... TD Act Btm (ftKB) 8,949.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044801 Wellbore Status INJ Max Angle & MD Incl (°) 55.63 MD (ftKB) 2,539.17 WELLNAME WELLBORE3S-17A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / WKM / GEN 5 / 5M TREE CAP CONNECTION: TO 5.75"" ACME with 3.5"" EUE 8RD THREAD 5/3/2003 Admin 3S-17, 5/10/2023 9:44:47 AM Vertical schematic (actual) KUP INJ KB-Grd (ft) 33.46 RR Date 5/4/2003 Other Elev… 3S-17 ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044800 Wellbore Status INJ Max Angle & MD Incl (°) 55.63 MD (ftKB) 2,539.17 WELLNAME WELLBORE3S-17A Annotation End DateH2S (ppm) DateComment Page 1/1 3S-17 Report Printed: 5/10/2023 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) 4/12/2023 00:00 4/12/2023 01:00 1.00 MIRU, MOVE MOB P Pull off 3S-10 0.0 0.0 4/12/2023 01:00 4/12/2023 03:00 2.00 MIRU, MOVE MOB P Spot over 3S-17 0.0 0.0 4/12/2023 03:00 4/12/2023 06:00 3.00 MIRU, MOVE MOB P Spot in pits and complete pre- acceptance checklist. 0.0 0.0 4/12/2023 06:00 4/12/2023 08:30 2.50 MIRU, MOVE RURD P Accept rig at 6:00 AM loadi pits with 9.6# NaCl. RU to Kill well. Tiger tank line frozen at tank. Replace hose to tiger tank. 0.0 0.0 4/12/2023 08:30 4/12/2023 09:00 0.50 MIRU, MOVE SVRG P Service top drive drawworks and handling eq. 0.0 0.0 4/12/2023 09:00 4/12/2023 11:00 2.00 MIRU, WELCTL KLWL P Load well with 340 BBL's 9.6# NaCl at 8 BPM CP=2500 PSI. 9.6# in and out. Blow down lines. 0.0 0.0 4/12/2023 11:00 4/12/2023 11:30 0.50 MIRU, WHDBOP OWFF P OWFF at tree. 0.0 0.0 4/12/2023 11:30 4/12/2023 12:30 1.00 MIRU, WHDBOP MPSP P Set 3" HP-BPV and test from below to 1000 PSI for 10 minutes. 0.0 0.0 4/12/2023 12:30 4/12/2023 16:30 4.00 MIRU, WHDBOP NUND P N/D adapter and tree N/U BOP's. 0.0 0.0 4/12/2023 16:30 4/12/2023 20:30 4.00 PROD1, RPCOMP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, W/3-1/2" test joint. Test blinds rams. Choke valves #1 to #16, upper IBOP and lower top drive well control valves. Test 3 1/2" HT-38 safety valve, FOSV, and IBOP. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea. 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3050 PSI, after closure=1500 PSI, 200 PSI attained =12 sec, full recovery attained = 136 sec. UVBR's= 5 sec, Annular= 25 sec. Simulated blinds= 5 sec. LVBR’s=5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2025 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sean Sullivan. 0.0 0.0 4/12/2023 20:30 4/12/2023 21:30 1.00 PROD1, RPCOMP THGR P Rig down test equip // suck out stack // Pull BPV // Install landing jt // BOLDS // PUll hanger to rig floor PU wt. 105K 8,275.0 8,255.0 4/12/2023 21:30 4/13/2023 00:00 2.50 PROD1, RPCOMP PULL P Lay down completion 8,255.0 6,500.0 4/13/2023 00:00 4/13/2023 06:30 6.50 COMPZN, WHDBOP PULL P Lay down 3.5" completion F/6500' T/surface. 6,500.0 0.0 4/13/2023 06:30 4/13/2023 07:00 0.50 COMPZN, WHDBOP FRZP P Freeze protect casing with 12 BBL's diesel 0.0 0.0 4/13/2023 07:00 4/13/2023 07:30 0.50 COMPZN, WHDBOP SVRG P Service rig tubing tongs, adjust turnbuckles. 0.0 0.0 4/13/2023 07:30 4/13/2023 08:30 1.00 DEMOB, MOVE NUND P N/D BOP's DSA, kill line and BD all lines rack back stack and secure. 0.0 0.0 4/13/2023 08:30 4/13/2023 10:00 1.50 DEMOB, MOVE NUND P N/U tubing head and 7" dry hole tree. 0.0 0.0 4/13/2023 10:00 4/13/2023 12:00 2.00 DEMOB, MOVE DMOB P Perform end of well ops. prep to move rig. rig released at 1200 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/13/2023 DTTMSTART JOBTYP SUMMARYOPS 3/24/2023 SUPPORT OTHER OPERATIONS YELLOWJACKET ELINE HOISTING WELLTEC CUTTER, CUT DEPTH = 8273' RKB, CCL TO CUTTER = 18', CCL STOP = 8255' RKB, TATTLE- TAIL INDICATED 3.62" BLADE TRAVEL, CORRELATED TO TUBING TALLY DATED 5/3/2003. JOB IS READY FOR DHD 3/25/2023 SUPPORT OTHER OPERATIONS (P&A) T X IA CDDT TO 0 PSI IN PROGRESS. 3/26/2023 SUPPORT OTHER OPERATIONS (P&A) T X IA CDDT TO 0 PSI (PASSED). 4/12/2023 RECOMPLETION Move off 3S-10 over to 3S-17, spot in and rig up. Load well W/9.6# NaCl. N/D Tree and adapter, N/U BOP and test. Verbal test witness waived by AOGCC representative Sean Sullivan. pull hanger off seat 105K , lay down pipe to 6500' 4/13/2023 RECOMPLETION Completed laying down 3.5" completion , freeze protect and install dry hole tree, RDMO to 3S-26 3S-17A Re-Enter Suspended Well Summary of Operations Completed laying down 3.5" completion YELLOWJACKET ELINE HOISTING WELLTEC CUTTER, CUT DEPTH = 8273' RKB pull hanger off seat 105K , lay down pipe to 6500' SFD 4/7/2023 SFD 4/7/2023GCW 04/12/23JLC 4/12/2023 04/12/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.12 16:53:46 -08'00' RBDMS JSB 041323 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 2560' 7" L-80 6076' 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 TUBING RECORD 300 sx GasBlok8-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/13/2022 203-080/ 322-151 2533' FNL, 1130' FEL, Sec. 18, T12N, R8E, UM 1077' FNL, 1666' FEL, Sec. 13, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476130 5993883 951' FNL, 1482' FEL, Sec. 13, T12N, R7E, UM 8324' MD/ 5663' TVD 8949' MD/ 6084' TVD ADL0025544, ADL0380107 ALK 2639 50-103-20448-01-00 KRU 3S-17A April 29, 2003 May 1, 2003 9. Ref Elevations: KB: 56' Kuparuk River Field/ Kuparuk River Oil Pool AMOUNT PULLED 470978 470793 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 1639' MD/ 1534' TVD 6160' MD/ 4285' TVD CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, CASING If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE CEMENTING RECORD 5995483 SETTING DEPTH TVD 5995356 TOP HOLE SIZE 8344'3-1/2" 29'465 sx AS Lite, 326 sx AS 30' 3275'29' 30' SUSPENDED Perforations: 8643-8666' MD and 5876-5891' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: 8938' SIZE DEPTH SET (MD) 27 bbls 15.8 ppg Cement below retainer, 2 bbls 15.8 ppg Cement above retainer 8324' -8666' MD 27' 62.5# 40# 108' 27' 8311' MD/ 5655' TVD PACKER SET (MD/TVD) 42" 12-1/4" 82 sx ArcticCrete Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:04 am, Feb 21, 2023 Suspended 8/13/2022 JSB RBDMS JSB 022823 xG Kuparuk River Field/ Kuparuk River Oil Pool WCB 2023-08-04 DSR-3/3/23 Susp Suspended KRU 3S-17A Permit to Drill Number / Sundry: 8/13/2022 203-080/ 322-151 Service Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1639' 1534' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email: jill.simek@conocophillips.com Contact Phone:(907) 263-4131 Staff Well Integrity Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Suspended TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Signed for Jill Simek Digitally signed by Allen EscheteDN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.comReason: I have reviewed this documentLocation:Date: 2023.02.20 15:22:51-09'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag TOC 3S-17A 8/13/2022 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/21/2010 ninam General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / WKM / GEN 5 / 5M TREE CAP CONNECTION: TO 5.75"" ACME with 3.5"" EUE 8RD THREAD 5/3/2003 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 29.4 3,275.0 2,560.2 40.00 L-80 BTC PRODUCTION 7 6.28 26.9 8,937.8 6,075.9 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.7 Set Depth … 8,343.7 Set Depth … 5,676.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.7 24.7 0.14 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 498.8 497.6 6.84 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 8,211.9 5,589.9 49.14 GAS LIFT 5.968 CAMCO MMG 2.920 8,257.2 5,619.6 49.06 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 8,295.0 5,644.4 48.97 SEAL ASSY 5.875 LOCATOR SUB & PBR 12 ' SEAL ASSEMBLY (SPACED OUT) 2.970 8,297.0 5,645.7 48.96 PBR 5.875 BAKER 80-40 PBR BAKER 80-40 2.970 8,310.1 5,654.3 48.88 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 3.250 8,311.3 5,655.1 48.87 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 8,316.5 5,658.5 48.85 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.710 8,335.7 5,671.2 48.74 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 8,342.7 5,675.8 48.70 WLEG 4.530 WLEG w/ SHEAR OUT SUB 2.982 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) 8,324.0 5,663.5 48.80 TUBING PLUG Pumped 29 bbls of 15.8 ppg cement. 27 bbls below retainer and 2 bbls on top. 7/30/2022 0.000 8,333.0 5,669.4 48.75 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 7/30/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,211.9 5,589.9 49.14 1 GAS LIFT DMY RK 1 1/2 0.0 5/6/2003 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,643.0 8,666.0 5,875.7 5,891.2 UNIT D, 3S-17A 5/7/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg phase, random orient IPERF; 8,643.0-8,666.0 TUBING PLUG; 8,324.0 CEMENT RETAINER; 8,333.0 PACKER; 8,311.3 GAS LIFT; 8,211.9 SURFACE; 29.4-3,275.0 CONDUCTOR; 30.0-108.0 DTTMSTART JOBTYP SUMMARYOPS 5/1/2022 SUPPORT OTHER OPERATIONS DRIFTED TBG W/ 2.75" DMY CA2 PLUG DOWN TO D NIPPLE 8335' RKB. PERFORM INJECTIVITY TEST DOWN TBG UP TO 3 BPM @ 2900 PSI PERFORM INJECTIVITY TEST DOWN OA UP TO 1.5 BPM @ 975 PSI(SEE ATTACHMENT FOR PUMP REPORT) READY FOR CTU PENDING WELL INTERVENTION ENGINEER REVIEW (UNABLE TO RIG UP ON 3S-26 DUE TO X-RAY CREW) 7/29/2022 ACQUIRE DATA (Pre SW) DEGAS AND LOAD IA FOR UPCOMING SW MITIA 7/29/2022 SUPPORT OTHER OPERATIONS RDMO 3S-26 TO 3S-17 WELL RU F/ CMT JOB 7/30/2022 SUPPORT OTHER OPERATIONS MIRU ON 3S-17. SET CEMENT RETAINER @ 8333' RKB. PUMPED 29 BBLS OF 15.8 PPG CEMENT PUMPED 27 BBLS BELOW RETAINER AND 2 BBLS ON TOP OF RETAINER DRESSED OFF TOP OF CEMENT TO 8103' POOH RDMO 8/1/2022 SUPPORT OTHER OPERATIONS (PRE STATE WITNESS) TAG TOP OF CEMENT W/ 2" BAILER @ 8307' RKB (204' LOWER THAN PLANNED TOC @ 8103' RKB); MITT TO 1500 PSI (PASS) 8/13/2022 SUPPORT OTHER OPERATIONS STATE WITNESS TAG TOP OF CEMENT @ 8324' SLM, RECOVER CEMENT IN BAILER, LRS PEFORM STATE WITNESS MITT & MITIA (PASSED) 3S-17 Suspend Summary of Operations As per 25.112 (c)(1)(D), the retainer was set between 50' and 500' above the perforated interval, as it was set at 8333', and the uppermost perfs are at 8643'. The 3-1/2" tubing has a capacity of .00870 bbl/ft and extends below the retainer by 7753'-7742'=11', containing only .1 bbls cement. 7" casing length from the tubing tail to the perfs is 8643'-8344'=299'. Casing cap is .0382 bbl/ft. So the casing contains (299ft)*(.0382 bbl/ft) =11.4 bbls cement. 27 bbls were pumped through the retainer, so roughly 15.5 bbls cement (27-11.4=15.6) were squeezed into the perfs. -WCB STATE WITNESS TAG TOP OF CEMENT @ 8324' SLM AOGCC witnessed pressure testing passed. -WCB PUMPED 27 BBLS BELOW RETAINER AND 2 BBLS ON TOP OF RETAINER **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 SET CEMENT RETAINER @ 8333' RKB@ TAG TOP OF CEMENT W/ 2" BAILER () @ 8307' RKB (204' LOWER THAN PLANNED TOC @ 8103' Tagged TOC is @8307', 26' above the retainer (8333'-8307'=26'), though the plan was to have ~230' of cement above the retainer. -WCB MITT TO 1500 PSI (PASS)() @( Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Other StimulatePerforate Change Approved ProgramPull TubingSuspend Perforate New Pool Re-enter Susp Well Other:Alter CasingPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoWill planned perforations require a spacing exception? Yes 10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None8949' CollapseCasing Structural Conductor Surface Intermediate Production Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLWINJOILCommencing Operations:Suspended WAGGASDate:16. Verbal Approval:SPLUGGSTOR AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? NoYes Spacing Exception Required? Subsequent Form Required:NoYes APPROVED BY Date:COMMISSIONERApproved by:THE AOGCC Sr Res EngSr Pet GeoSr Pet EngComm.Comm. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Workover Engineer Tubing MD (ft):Tubing Grade: 8331' MD and 5655' TVD 499' MD and 498' TVD Tubing Size:Perforation Depth TVD (ft): 8344'L-80 Packer: Baker SAB-3 Packer SSSV: Camco Nipple w/ NoGo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 203-080 P.O. Box 100360, Anchorage, AK 99510 50-103-20448-01-00 ConocoPhillips Alaska, Inc. KRU 3S-17A Kuparuk River Field N/A SizeLength BurstTVD PRESENT WELL CONDITION SUMMARY 8324'1440 psi5663'8324'6084' MD 108' 2560' 108' 3275' 6076'8938' 16" 9-5/8" 78' 3246' Perforation Depth MD (ft): 8643-8666' 8911' 3-1/2"5876-5891' 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 3/23/2023 Current Pools: N/A Proposed Pools: N/A By Samantha Carlisle at 11:01 am, Feb 13, 2023 323-087 X VTL 02/15/23 X X X VTL 02/16/2023 DSR-2/13/23DLB 02/15/2023 BOP test to 2500 psig Annular preventer to 2500 psig 10-407 GCW 02/22/23 JLC 2/22/2023 2/22/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.22 15:26:31 -09'00' RBDMS JSB 022323 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 25, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 3S-17A (PTD# 203-080). Well 3S-17A was drilled and completedas a Kuparuk Injector in May 2003. The well has been slated to be P&A'd for development of the Coyote formation. If you have any questions or require any further information, please contact me at +1503-476-2519. After a traditional Kuparuk P&A that has already had sundry approval, the tubing will be cut above tubing cement retainer/top of cement. Then a rig will come and pull the 3.5" tubing and stack two 7-1/16" valves on the wellhead. This will give eline and coiled tubing access to the 7" casing. The OA cement and final P&A deatils of the well will be submitted in a separate sundry. This sundry is just for the rig portion of the work that requires pulling the 3.5" tubing. This sundry is just for the rig portion of the work that requires pulling the 3.5" tubing. 3S-17A RWO Procedure Kuparuk Injector Suspend PTD # 203-080 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Cut the tubing above tagged top of cement. 3. Prepare well for rig 48-72 hours before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3S-17A. (No BPV will be install pre-rig due to internal risk assessment for N7ES for MIRU/RDMO without a BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut. a. On POOH with tubing, circulate well over to diesel freeze protect as necessary. 6. Perform 30 minute NFT. ND BOP, NU Tree 7. ND BOPE. NU two 7-1/16” tree valves and any adapter spool. 8. RDMO. Post-Rig Work - Post-rig scope will be submitted as a separate sundry for OA cement job and final P&A. 3S-17A RWO Procedure Kuparuk Injector Suspend PTD # 203-080 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 3/23/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in the lower Kuparuk is P&A’d. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Stack two 7-1/16” valves for Eline and coil unit OA cement operations post-rig. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed to 1500 psig on 8/13/2022. (Well is P&A’d and tubing will be cut for RWO.) MIT-IA Passed to 1500 psig on 8/13/2022. MIT-OA N/A IC POT & PPPOT PASSED – None Recent. TBG POT & PPPOT PASSED – None Recent. MPSP: 1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Rig work should be done over P&A’d well and not exposed to formation pressure during Rig portion of work. 3S-17A Proposed Suspended Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 108 108 16 15.06 62.5 H40 Welded Welded Surface 3275 2560 9.625 8.92 40 L80 BTC BTC Production/ Intermediate 8938 6076 7 6.28 26 L80 BTCM BTCM PROPOSED COMPLETION 3.5" Completion REMOVED Install two 7-1/16" Gate Valves (Freeze Protect when pulling 3.5" out of hole.) REMAINING COMPLETION LEFT IN HOLE P&A'd lower Kuparuk (Already done.) 3.5" Tubing Stub Top Approximately ~8280' RKB Surface Casing 7" Production Casing Conductor C and A-sand perfs Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,324.0 3S-17A 8/13/2022 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag TOC 3S-17A 8/13/2022 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/21/2010 ninam Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ft… 108.0 Set Depth … 108.0 Wt/Len (lb/ft) 62.50 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.4 Set Depth (ft… 3,275.0 Set Depth … 2,560.2 Wt/Len (lb/ft) 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.9 Set Depth (ft… 8,937.8 Set Depth … 6,075.9 Wt/Len (lb/ft) 26.00 Grade L-80 Top Connection BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.7 Set Depth … 5,676.4 String Ma… 3 1/2 Tubing Description TUBING Set Depth (ftKB) 8,343.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.7 24.7 0.14 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 498.8 497.6 6.84 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 8,211.9 5,589.9 49.14 GAS LIFT 5.968 CAMCO MMG 2.920 8,257.2 5,619.6 49.06 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.812" NO GO CAMCO DS 2.812 8,295.0 5,644.4 48.97 SEAL ASSY 5.875 LOCATOR SUB & PBR 12 ' SEAL ASSEMBLY (SPACED OUT) 2.970 8,297.0 5,645.7 48.96 PBR 5.875 BAKER 80-40 PBR BAKER 80-40 2.970 8,310.1 5,654.3 48.88 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 3.250 8,311.3 5,655.1 48.87 PACKER 5.956 BAKER SAB-3 PACKER BAKER SAB-3 3.250 8,316.5 5,658.5 48.85 MILL 4.500 80-40 MILL OUT EXTENSION 80-40 3.710 8,335.7 5,671.2 48.74 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75" NO GO CAMCO D 2.750 8,342.7 5,675.8 48.70 WLEG 4.530 WLEG w/ SHEAR OUT SUB 2.982 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Make Model SN ID (in) 8,324.0 5,663.5 48.80 TUBING PLUG Pumped 29 bbls of 15.8 ppg cement. 27 bbls below retainer and 2 bbls on top. 0.000 8,333.0 5,669.4 48.75 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,211.9 5,589.9 49.14 1 GAS LIFT DMY RK 1 1/2 0.0 5/6/2003 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,643.0 8,666.0 5,875.7 5,891.2 UNIT D, 3S-17A 5/7/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg phase, random orient 3S-17A, 8/13/2022 6:12:00 PM Vertical schematic (actual) PRODUCTION; 26.9-8,937.8 FLOAT SHOE; 8,936.4-8,937.8 FLOAT COLLAR; 8,783.0- 8,784.3 IPERF; 8,643.0-8,666.0 TUBING PLUG; 8,324.0 WLEG; 8,342.7 NIPPLE; 8,335.7 CEMENT RETAINER; 8,333.0 MILL; 8,316.5 PACKER; 8,311.3 ANCHOR; 8,310.1 PBR; 8,297.0 SEAL ASSY; 8,294.9 NIPPLE; 8,257.2 GAS LIFT; 8,211.9 SURFACE; 29.4-3,275.0 FLOAT SHOE; 3,273.3-3,275.0 FLOAT COLLAR; 3,195.8- 3,197.2 NIPPLE; 498.8 CONDUCTOR; 30.0-108.0 HANGER; 29.4-32.5 HANGER; 26.9-29.3 HANGER; 24.7 KUP INJ KB-Grd (ft) 33.46 RR Date 5/4/2003 Other Elev… 3S-17A ... TD Act Btm (ftKB) 8,949.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044801 Wellbore Status INJ Max Angle & MD Incl (°) 55.63 MD (ftKB) 2,539.17 WELLNAME WELLBORE3S-17A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 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: 8949 Lease No.: ADL 0380107 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3275 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8938 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8344 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer 8333 ft 8324 ft 7.1 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1670 1620 1610 IA 210 220 220 OA 380 380 380 Initial 15 min 30 min 45 min Result Tubing 575 600 600 IA 1675 1620 1610 OA 475 450 440 Remarks: Attachments: Brent Rodgers P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Suspension plug. I arirved on location; talk with S/L unit operator then witnessed run in the hole with a bailer for plug tag. Pick up and set down 3 times after initial tag - call depth 8324 ft MD. Waivered well T X IA - MITT & MITIA went well. Location was in August 13, 2022 Kam StJohn Plug Verification KRU 3S-17A ConocoPhillips Alaska Inc. PTD 2030800; Sundry 322-151 Photo of Bailer Sampler Returns Test Data: P Casing Removal: rev. 11-28-18 2022-0813_Plug_Verification_KRU_3S-17A_ksj ! 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~oô-D80 Organizing (done) Well History File Identifier ø<:O-Sided 11I1111111111111111 ~scan Needed RESCAN ~Ior Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: NOTES: D Other:: ' BY: Helen C Maria) _ Date: 7 I J ~ ö5 151 I . 1 I Date: p-A j. ~ 'tl~/SI n+0 Project Proofing BY: Helen ~ () V11 BY: Helen (Maria ),_ '3 X 30 = Off) + {~ = TOTAL PAGES C a , 1 (Count doe~l)O~c,!de cover steet) IAA :0 Date: 7 I W' fJ.S1SI VY~I 1 Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: q If (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO ¡ , Helen (Maria) Date: 7, J ~ ,os Is! If NO in stage 1, page(s) discrepancies were found: YES· NO rn¡J BY: Stage 1 BY: Helen Maria Date: 151 II! 1111111111111111 1111111111111111111 1 n Date: 151 Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • MEMORANDUM To: Jim Regg `` )P,~, ~~, 3~~:~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3S-]7A KIJPARUK RIV UNIT 3S-17A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3S-17A API Well Number: 50-103-20448-O1-00 Insp Num: mitRCN100809152042 Permit Number: 203-080-0 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-17A Type Inj. o ~ TV~_ s6ss ~ IA 6zo taso ~ 1820 18IO P,T.D zo3os°° " TypeTest~PTTTest psi I 18s0 QA 410 ~ 430 430 430 IriterVal 4YRTST p~ P ~ TUbing ~ 30s0 30s0 30s0 ~ 30s0 Notes: ul~n...k~~ !•~~~`ot /SGu~s; ~,~ ~~. Tuesday, August 10, 2010 Page 1 of I • • _~~. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .," . J F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 3S-16, 3S-17, 3S-17A, 3S-18. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-16: u XC- 903 - Obi- tt ! !../3?5'd-- Digital Log Images: 50-103-20445-00 1 CD Rom 3S-17: U:r.~ .;)ö3 -blS- jf l.(3iJ3 Digital Log Images: 50-103-20448-00 1 CD Rom U:I.0. 3S-17A: 903-015D .;1/'-/3"'61 Digital Log Images: 50-103-20448-01 SCANNED fEB 0 1 2007 1 CD Rom ......~.~ 3S-18: QÓd -dOCo ~ IL{3'?50 Digital Log Images: 50-103-20433-00 1 CD Rom /- W MEMORANDUM . State of Alaska .. Alaska Oil and Gas Conservation Commiss. TO: Jim Regg Kêdt: 0/3D I C~ P.I. Supervisor I ( · DATE: Wednesday, August 30,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3S-17A KUPARUK RIV UNIT 3S-17A J..03-0fðO FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUKRIVUNIT3S-17A API Well Number 50-103 -20448-01-00 Inspector Name: Jeff Jones Insp Num: mitlJ060829123030 Permit Number: 203-080-0 Inspection Date: 8/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3S-17A Type Inj. w TVD 5655 IA 1175 1800 1780 1780 P.T. 2030800 TypeTest SPT Test psi 1500 OA 380 400 400 400 Interval 4YRTST PIF P ../ Tubing 2350 2350 2375 2340 Notes 0.8 BBLS diesel pumped. I well house inspected; no exceptions noted. SCANNED SEP 0 82005 Wednesday, August 30, 2006 Page I of I "., . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 !it :';;, Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~b3- 0 ~/O' òg- 17 A "{', ....NNt:f" ,\11C! ':;1!ò<ri,. .(,;.... ..1.) \, }) Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18, 2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~: C--/ ConocoPhillips W ell 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 prD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 13, 2004 I DLQ~dì RE: MWD Formation Evaluation Logs 3S-17A, AK-MW-2401952 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-17A: Digital Log Images 50-103-20448-01 :)Ö5-0õ() 1 CD Rom ~0 ? ~1?910{p 7 J~~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Current Status WAGIN -Sf~ À' ~"t<tèJ API No. 50-103-20448-01-00 ~ .-------- Permit to Drill Well Name/No. KUPARUK RIV UNIT 3S-17A Operator CONOCOPHILLlPS ALASKA INC 2030800 MD 8949 ,,/ 6084/ Completion Date 517/2003 ./ --- Completion Status ~~ TVD ----~ ------ ------- ------ REQUIRED INFORMATION Mud log No Samples No -- -- ---- -- --------- ----- -- --------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens-Neutron, CBl Well Log Information: Log/ Data Type 1"- /. .Rpt '-r ~t Electr Digital Dataset Med/Frmt Number Name Directional Survey Directional Survey Log Log Scale Media Run No 1 (Rpt Ç"'1991 LIS Verification : ED D 11991 I nd uction/Resistivity e,/ ,/ : ED D 11991 Neutron ; l11991 ¡ED D Density _: ~' Pressure J.dg Perforation tyfg Cement Evaluation 2,3 2,3 2,3 2,3 5 Blu 5 Blu 5 Blu ----~ Well Cores/Samples Information: Name Interval Start Stop Received Sent Directional surve~ (data taken from logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 6121 8949 Open 5/13/2003 6121 8949 Open 5/13/2003 MWD 3250 8949 Open 6/2/2003 6160 8916 Open 6/2/2003 MWD-GR, EWR4, CNP, SlD, ROP-MD 6160 8916 Open 6/2/2003 MWD-GR, EWR4, CNP, SlD, ROP-MD 6160 8916 Open 6/2/2003 MWD-GR, EWR4, CNP, SlD, ROP-MD 8122 8751 Case 6/27/2003 Static Bottom Hole Pressure Survey - PSP: PressurefT emperature 8122 8720 Case 6/27/2003 Perforating Record 2 1/2" - HSD Powerjet HMX, 6 SPF 8265 8740 Case 6/27/2003 Cement Bond log - SCMT- BB/PSP: Press-Temp Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030800 Well Name/No. KUPARUK RIV UNIT 3S-17A Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20448-01-00 MD 8949 TVD 6084 Completion Date Sn/2003 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? . Y / N Daily History Received? t£: Formation Tops Analysis Received? ~ -- -- ----. ----- -" ----- _._---------~ Comments: --- , ( Compliance Reviewed By: ~ Date: ') J \f)S Àò~ ¡ - - ~- - ------- --- - ---- ------ . . . . Çhånøe Approved Progr~m· 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 56' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. .Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: ) STATE OF ALASKA ' ). ALAclKA OIL AND GAS CONSERVATION COMMISt>lùN . ~bandon 0 Alter C~sing 0 o RECEIVED MAR J. 7 2005 Stimulate D ii{.· Oil &liswC~n~~~åffim¡ ssior Wa~ver D. . .T1m,e,::Extensi,on-:·· '--.ch'o· r , . , .:.., ..:.. d1. au., Rs-enter .susp~ildedWell 5. Permit to Drill Number: 203-080 6. API Number: 50-103-20448-01 REPORT OF SUNDRY WELL OPERATIONS . Rëpair Well 0 Pull T~bi~g' 0:· Ope rat. ShutdowriO Plug Perforations 0 .: Perforate New Pool .0 . Perforate,· ·:0 4. Current Well Status: '. : Developmønt· 0·· StråtiQraPhiC : ':: 0 :' Exploratory Service O· 0' 9. Well Name and Number: 3S-17 A 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool measured 89491 feet true vertical 6084' feet measured 8783 feet true vertical 6276' feet Length Size MD 108' 16" 108' 3219' 9-5/8" 3275' 8882' 7" 8938' Plugs (measured) Junk (measured) TVD Burst Collapse 1081 2560' 6076' Measured depth: 8643' - 8666' true vertical depth: 5876' - 5891' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8344' MD. RBDMS BFL MAR 1 7 2005 Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 499' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Cópies of Logs and Surveys run_ 1085 15. Well Class after proposed work: . EXploratoryD Development D SerVice 0 16. Well Status after proposed work: oilD GasD WAG 0 GlNJ 0 WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1059 1150 10 CasinQ Pressure TubinQ Pressure 2601 3340 Daily Repórt of Well Operations _X WDSPLD Contact Robert Christensen @ 659-7535 Printed Namf} /J ~PJ q1istenser Signatur~ ~~~ Title Phone P.. roo duction Engineering T eChniCi~;: 659ÃSr Date :Y;6/&~ :RqFJ~JK ~~L:, ';/'\,' ~ 1 2005 Submit Original Only Form 10-404 Revised 04/2004 R8DM~:' : 'l ) . 3S-17A ) DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Sum~ary 12123/2004ICommenced WAG EOR Injection STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL *Freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~, ~ Printed Name: Randy Thomas Title: 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 1 2nd 4559 2003 1 3rd 2133 2003 14th 0 2004 I 1st 0 20041 2nd 4403 Total Ending Volume 11095 (bbls): 100 100 o o 100 300 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil D Gas 0 WAG0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 303-155 (h)(3) Other Commission approved substances (include descriptions in block 12) 6/3/2003 Volume (bbls): Number of days disposal occurred 361* 361 0 4659 0 2233 0 0 0 0 0 4503 361 11756 17 Step Rate Test 0 Date: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-080 38-17 A 50-103-20448-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 5 6/26/2003 38-19 6/30/2003 3 7/1/2003 38-19 7/3/2003 o o 9 4/27/2004 ____d 5/5/2004 38-24A Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7/~ (ocr Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL *Freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ < Signature: ,~ \ ~ ~...... - ,) ì \1-~ -- '"'- f' 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 2nd 4559 2003 / 3rd 2133 2003 / 4th 0 2004 /1 st 0 Total Ending Volume 6692 (bbls): 100 100 o o 200 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 303-155 (h)(3) Other Commission approved substances (include descriptions in block 12) 6/3/2003 Volume (bbls): Number of days disposal occurred 361* 361 0 4659 0 2233 0 0 0 0 361 7253 Step Rate Test D Date: Title: ~ \ {ll~-0 ~~..- L -=_..1 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-080 38-17 A 50-103-20448-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .~' 5 6/26/2003 38-19 6/30/2003 3 7/1/2003 38-19 7/3/2003 o o ----' 8 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. '-T1lb(O'-{ Phone Number: ¿& S- ~"8 $ D Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL *Freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. , \.. ~_. .~~ \ L----- ~,.,lì ~",,~..:s. 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 3rd 6792 100 2003 / 4th 2004/1st 2004 / 2nd Total Ending Volume (bbls): 6792 100 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 303-155 (h)(3) Other Commission approved substances (include descriptions in block 12) 6/3/2003 Volume (bbls): Number of days disposal occurred 361* 361 o 6892 361 7253 Step Rate Test 0 Date: Title: '~lÙ ~- Lf¿_J INSTRUCTIONS ON REVERSE SIDE 8 8 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-080 38-17 A 50-103-20448-01 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: -- 6/26/2003 7/312003 38-19 c~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \(-¿6 (~y Phone Number: 2.Gs 6 ß 3 C Submit in Duplicate ) y ConocoPhiiii ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 f ) ~~C!2J· C.. 111~D ~4ìIka~ . . 0 .1200J dGas~ ~, Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. :~ ~~I MJ:¿( / ConocoPhillips Problem Well Supervisor Attachment J:.+,- ~~~c<.. ~c:::'O~~" ~''-<t~~\-. +D Cr ~ \ \ 'o~c... ~" ö..~~, ~~ ~~ ~~<!:.. ."s~ \ \...., '-<!:.. ""'.'- ,,~d -\0 '>~~. À\\ o~-\-~ "T~<...'t ~~"S~~ \::>Q~'1 f\QG\ +"'<ë. <:>u~~. ~o.Çù'~~<L\ Q.<:.~\o~ t'\Q.ct.~<J..''{ ft-5!-¥(ld-Á-a-S ' ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well TOC Volume Sacks Name PTO# Type ft BBLS Cement 3S-03 2030910 Prod 8 0.6 3.6 3S-07 2021870 Prod 8 1.5 9.1 38-09 2022050 Inj 14 2.5 15.1 38-10 2022320 Prod 12 1.5 9.1 38-14 2022210 Inj 3 1.5 9.1 3S-15 2022540 Prod 8 0.8 4.8 38-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 3S-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 38-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0.3 1.8 Annular Disposal during the third quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes .19., CD2-4l 19560 100 0 19660 377 4000 24037 June 2003 July 2003 CD2-20, CD2-55 O~O 38-17 A 2133 100 0 2233 361 4659 7253 June 2003 July 2003 35-19 Hansen 1 2498 100 0 2598 0 115278 117876 January July 2003 Hansen 1, Hansen 1 A 2002 CD2-38 29522 100 0 29622 389 0 30011 July 2003 Sept 2003 CD2-40, CD2-30, CD2-55 lB-20 36655 100 0 36755 0 0 36755 July 2003 Sept 2003 1B-102, 1B-101 \ CD2-23 22140 100 0 22240 377 0 22617 Sept 2003 Sept 2003 CD2-18, CD2-55 Total Volumes into Annulifor which Disposal Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 371 380 Start Date Well Name CD2-46 CD2-22 Total h(l) Total h(2) Total h(3) V olume V olume Volume 31393 100 0 30773 100 0 31864 31253 Status of Annulus Open, Freeze Protected Open, Freeze Protected April 2003 February 2003 December 2002 CD2-48 31525 o 32000 Open, Freeze Protected 100 375 End Date May 2003 March 2003 February 2003 Source Wells CD2-51, CD2-12 CD2-08, CD2-36, CD2- 51 CD2-45, CD2-35, CD2- 08, CD2-28 ( RE,CEI\lE OCT 01 3 I'~()r]~~ ç ¿. .' ~}~)' ¡'Iaska Oil & Gas Cons. Commission Anchorage Schlumbel'gel' NO. 2879 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Well Job# Log Description Field: Date BL Color 05/07/03 1 OS/25/03 1 OS/24/03 1 05/10/03 1 05/14/03 1 05/09/03 1 05/08/03 1 05/19/03 1 04/04/03 1 05/07/03 1 OS/23/03 1 35-17A !9O'.:j -()Ci'J 5BHP SURVEY 35-06 ~ð. ~ -0.&:5 T PERF RECORD W/5BHP & JEWELRY LOG 3S-08B :510,'9-04-3 PROD PROFILE WITEMP SURVEY 35-23 ~Q3 'ûtJ&J' PRODUCTION PROFILE 1H-17 \qd.... 1?rJ PRODUCTION PROFILE 2U-08 \<ï$,S _·O~ \ 5BHP SURVEY 1R-14 t¡sl-¡,kj\ LDL 3F-01 I'6S-Ð.d.,t) PRODUCTION PROFILE 1D-103 f:)cr; 'mio MEM P5P INJECTION PROFILE 35-17 A;}Q~ iYffl 23351 5CMT 35-06 ßkl~ -fri T, 23353 SCMT . ~ SIGNE~'\ ~Á/"\.. ~,-5.~_0~~~~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 06/24/03 ;Z63~DOð Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD _/ --' R.:,·. f,::_,~,~.~=~._·,·,-.-.· b i \ I' ¡:: D'" !), ;; ":' -~ L,.. H Vb:" ./ JU¡',j 27 2003 ÞJarilia ~~;H ¡~. f;B3 (!I~Jn[~ (::Vrf!fS1~[~ )}')cnÖftr0Ð ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission ~ 7)/) TO: Randy Ruedrich Vi:» DATE: June 27,2003 Commissioner ¡ -"J '~, Î (¡qtr?SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder \ "f:l Conoco Phillips P.I. Supervisor 3S Pad KRU -?,,, cleF d-,ÞJ FROM: Chuck Scheve Petroleum Inspector NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 3S-06A Type Inj. S T.V.D. 5596 Tubing 2050 2050 2050 2050 Interval I P.T.D. 203-088 Type test P T est psi 1399 Casing 800 2000 1975 1975 P/F f Notes: Well 3S-17A Type Inj. S T.V.D. 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. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. 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 38 Pad in the Kuparuk River Field and witnessed the initial MIT on wells 38-06 and 38- 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.'s 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 03~O'ßê) 9- Annular Disposal during the second quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21,3S-08,3S-23 2003 2003 lC-22 21553 100 0 21653 0 27044 48697 March May 1C-190, 1C-174, 1C-178, 1C-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 } 2003 2003 " CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23,3S-17, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen 1 A 2002 lC-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 1C-184, 1C-170, 1C-172 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24, 3S-03, 3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annulifor which Disposal Authorization Expired during the second quarter 2003: ) Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-S0 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-38 ID-ll 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1 D-1 03 lC-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-1 04 Schlumberger NO. 2879 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Well Log Description Field: Date BL Color 05/07/03 1 OS/25/03 1 OS/24/03 1 05/10/03 1 05/14/03 1 05/09/03 1 05/08/03 1 05/19/03 1 04/04/03 1 05/07/03 1 OS/23/03 1 Job # 3S-17A 19Q~-(,)3'-: SBHP SURVEY 3S-06 .~Ct~ -CCS -:¡- PERF RECORD W/SBHP & JEWELRY LOG 3S-08B '4Q9-nLI3 PROD PROFILE WITEMP SURVEY 3S-23 ~Q, 'oLJ.Þ)' PRODUCTION PROFILE 1 H-17 I q f)... I ?:rJ PRODUCTION PROFILE 2U-08 \~S-(..::? \ SBHP SURVEY 1R-14 J'iS(-I.J?' LDL 3F-01 1<;S5-Ð.;!)'~ PRODUCTION PROFILE 1D-103 ~C7;J 'm(O MEM PSP INJECTION PROFILE 3S-17 AAO:1 f'/¡X) 23351 SCMT 3S-06 ¡)lCG-rñ T, 23353 SCMT SIGNE~.\ '-~ A'-~'_"-0t.. ~~J'V'. DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 06/24/03 'LD~~D86 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD -~ - ~~~~ E: C~ E 1 \l 1':: 11 \ ;- .;-- -/ .'" !}~~!J}([~~ -.-~;-j ~::: ~._......;> ~ - --L;~ n~!~}~;r\ ) ') Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJ'Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 May 29,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-17 and 3S-17 A (APD# 203-015 and 203-080) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3S-17 and 3S-17 A. 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 RECEIVED JUN 1 3 2003 Alaska Oil & Gas Cons. Commission Anchorage ORtG:NA:.. ) 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: ConocoPhillips Alaska, Inc. 3. Address: WINJ 0 WDSPL 0 Plugged 0 Abandoned U 20AAC 25.105 No. of Completions _ P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2533' FNL, 1130' FEL, Sec. 18, T12N, R8E, UM At Top Productive Horizon: Total Depth: 951' FNL, 1482' FEL, Sec. 13, T12N, R7E, UM 1077' FNL, 1666' FEL, Sec. 13, T12N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476130 y- TPI: x- 470978 y- Total Depth: x- 470793 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res/Dens-Neutron, CBL 22. CASING SIZE WT. PER FT. 62.5# 40# 26# GRADE B L-80 L-80 30"x16" 9.625" 7" 5993883 5995483 5995356 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"): 8643' - 8666' MD 5876' - 5891' TVD 6 spf r'-;':-(J'I::'D;'r::r~'c~;ïÌj ~ t, _ ,Vi. t.\._ I .:.M~ ~ i !.1A 111 ~ f -';·?·Qßj j _._~.~~~-I ~,.." _' .. ,. "'''''·~'~W·'''·'LI.,.,t.;'''\'''''"''''''''~ 26. Date First Production May 20, 2003 Date of Test Hours Tested N/A Flow Tubing Casing Pressure press. 27. psi 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". RBDMS BFL, úl-' Form 10-407 Revised 2/2003 24-Hour Rate -> NONE JUN 1 -ó 2@03 Suspended 0 WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., "í At> or Aband.: Ma~, 2003 6. Date Spudded: April 29, 2003 7. Date TD Reached: May 1 , 2003 8. KB Elevation (ft): 56' AMSL 9. Plug Back Depth (MD + TVD): 8783' MD I 5970' TVD 10. Total Depth (MD + TVD): 8949' MD / 6084' TVD 11. Depth where SSSV set: Land Nipple @ 499' & 8257' 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test D 12. Permit to Drill Number: 203-080 I 13. API Number: 50-103-20448-01 14. Well Name and Number: 3S-17 A 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25544 17. Land Use Permit: ALK 2639 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1639' MD .5.J,IrA.J<d~ bl6(:/hfþ C¡Zßt:<;VO ) .-6" HOLE SIZE 42" 82 sx ArcticCrete CEMENTING RECORD AMOUNT PULLED 12.25" 465 sx AS Lite, 326 sx AS 300 sx GasBlok CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3275' Surface 8938' 8.5" 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 8344' PACKER SET (MD) 8311' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NM NM WATER-BBL GAS-MCF WATER-BBL PRODUCTION TEST Method of Operation (Flowing, gas lift. etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL CORE DATA CON"~l~ ~ j 'WA L CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) RECEIVED JUN 1 3 2003 Alaska Oil & Gas Cons. Commission Anchorage Submit in duplicate 28. ') ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Kuparuk Base Kuparuk 8643.5' 8664' 5876' 5890' N/A RECEIVED JUN 1 3 2003 Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Lowry @ 265-6869 t,1tþt C- ,t; 12-,~-, Printed Na~ R.. Thomas Signature .{ ~\ \ ~ Title: Chone Kuparuk Drillinq Team Leader Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 OR\G\NAl Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) Page 1 of 6 ConocoPhillips Alaska Operations Summary Report 38-17 38-17 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES Start: 4/20/2003 Rig Release: 5/4/2003 Rig Number: Spud Date: 4/21/2003 End: 5/4/2003 Group: 4/20/2003 07:00 - 17:00 17:00 - 19:30 19:30 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01 :00 01:00 - 02:15 02:15 - 03:30 03:30 - 04:00 04:00 - 21 :00 4/21/2003 21 :00 - 21 :45 21 :45 - 00:00 4/22/2003 00:00 - 18:15 10.00 MOVE MOVE MOVE 2.50 MOVE RURD MOVE 1.00 MOVE RURD MOVE 1.00 DRILL PULD SURFAC 0.50 DRILL PULD SURFAC 0.50 RIGMNT OTHR SURFAC 1.50 DRILL PULD SURFAC 1.00 DRILL PULD SURFAC 1.25 DRILL PULD SURFAC 1.25 DRILL OTHR SURFAC 0.50 DRILL PULD SURFAC 17.00 DRILL DRLG SURFAC 0.75 DRILL CIRC SURFAC 2.25 DRILL DRLG 8URFAC 18.25 DRILL DRLG SURFAC 18:15 - 20:15 2.00 DRILL CIRC SURFAC 20:15 - 23:30 3.25 DRILL TRIP SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 4/23/2003 00:00 - 02:00 2.00 DRILL PULD SURFAC 02:00 - 02:30 0.50 DRILL OTHR SURFAC 02:30 - 04:00 1.50 CASE RURD SURFAC 04:00 - 04:15 0.25 CASE SFTY SURFAC 04:15 - 08:30 4.25 CASE RUNC SURFAC 08:30 - 09:00 0.50 CASE CIRC SURFAC 09:00 - 10:00 1.00 CASE RUNC SURFAC 10:00 - 10:15 0.25 CASE CIRC SURFAC 10:15 -11:00 0.75 CASE RUNC SURFAC 11 :00 - 11 :45 0.75 CASE RURD SURFAC 11 :45 - 14:30 2.75 CASE CIRC SURFAC 14:30 - 14:45 0.25 CEMENT SFTY SURFAC 14:45 - 17:30 2.75 CEMENT PUMP SURFAC 17:30 - 19:30 2.00 CEMENT PULD SURFAC Moved Rig from 3S-23 to 38-17. Accepted rig @ 1700 Hrs. 4/20103. NU riser Rigged up and cleaned up drill floor. Loaded DC's in pipe shed. Picked up and stood back same. Brought BHA subs and stabilizers to rig floor. Installed blower hose on top drive. PJSM and picked up BHA. Made up MWD and down load. Locked on 33 Deg. Changed out DM collar and upload. Orient tool. Broke circulation and tested surface lines to 3500 PSI. Made up Flex collars. Spudded well at 0400 Hrs. Drilled 12 1/4" Directional hole from 108' to 1376'. ART 3.94 Hrs. AST 7.7 Hrs. Up Wt. 80 K Down Wt. 71 K Rot. Wt. 75 K. WOB 20/25 K TD RPM 60 GPM 450 to 500. Torque on Btm. 6n K Off Btm. 3/4 K. Pumped Hi vis sweep and circulated out sand. 45' fill. Drilled 12 1/4" Directional hole from 1376' to 1566'. ART .5 Hrs. AST 1.25 Hrs. Up Wt. 83 K Down Wt. 74 K Rot. Wt. 76 K. WOB 20/28 K TD RPM 60 GPM 450 to 500. Torque on Btm. 6n K Off Btm. 3/4 K. Drilled 12 1/4" Directional hole from 1566' to 3285' (2566' TVD). ART 7.69 AST 4.68 Hrs. Up Wt. 100 K Down Wt. 79 K Rot. Wt. 90 K. Torque Off Btm. 4/5 K On Btm. 6n K. TD RPM 100 WOB 20/35 K. 450/600 GPM. Circulated back to back sweeps until hole was clean. Sweeps 25 Bbls. @ 11.8 PPG. .2 PPB Baralift. Large increase with first sweep and lesser amount with second. POOH to BHA. Stood back HWDP and Flex collars. Max overpull 35000. Laid down BHA. Finished laying down BHA and bit. Cleared drill floor. Rigged up to run casing. Pre job safety meeting. Ran 51 Jts. 9 5/8" 40# L 80 BTC casing to 1951'. Ave Makeup 8800 Ft Ibs. Losing string weight. CBU to break gels in mud. Ran 21 Jts. 95/8" 40# L 80 BTC casing to 2753'. Washed down Jt # 73 (took weight). Ran 12 Jts. 9 5/8" 40# L 80 BTC casing to 3275'. Rigged down Circulating tool and rigged up cement head. Circulated and conditioned hole for cementing. 100 SPM @ 485 PSI. Worked pipe Up WT 140 K Dn Wt 105 K. Pre job safety meeting while finishing circulating. Pumped 10 Bbls CW100, Tested lines to 3500 PSI, Pumped 20 Bbls CW100 and dropped bottom plug, pumped 50 Bbls Mudpush 10.5 PPG followed by 355 Bbls lead mixed at 10.7 PPG. cement to surface. Mixed and pumped 130 Bbls of tail 12 PPG dropped top plug and Dowell displaced with 20 Bbls wash water followed by 222 Bbls mud displaced with rig pump at 7 BPM. Plug bumped with 1000 PSI and floats held. Good returns and worked pipe throughout job 210 Bbls cement to surface. CIP 1720 Hrs. 4/23/03. FC @ 3196' FS @ 3275'. Flushed riser and flowline. Rigged down cementing and casing tools. Printed: 5/16/2003 10:49: 11 AM .) ) ConocoÞhil'lipsAlaska Operatiohs Summary Report Page 2 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-17 38-17 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 4/20/2003 Rig Release: 5/4/2003 Rig Number: Spud Date: 4/21/2003 End: 5/4/2003 Group: 4/23/2003 19:30 - 20:15 0.75 CASE NUND SURFAC Nippled down and set back riser. 20: 15 - 20:45 0.50 CASE NUND SURFAC Installed FMC Gen V Speed head. 20:45 - 22:45 2.00 CASE NUND SURFAC Nippled up BOP. 22:45 - 23:45 1.00 WELCTL BOPE SURFAC Pick up test plug and set. Fill stack with water and rig up test lines and recorder. 23:45 - 00:00 0.25 WELCTL BOPE SURFAC Test BOP top rams + choke valves 1,2, and 3 + TIW + HCR kill side. 250 and 5000 PSI. 4/24/2003 00:00 - 05:00 5.00 WELCTL BOPE SURFAC Tested Hydrill to 250/3500 psi. Tested Top Rams, IBOP, Choke and Kill valves, Lower rams, Lower IBOP, Floor Safety Valves, and Blind Rams to 250/5000 psi. Tested VBR with 7" casing. Tested Accumulator System. Jeff Jones waived witiness of test. 05:00 - 05:30 0.50 DRILL OTHR SURFAC Laid down test plug and installed wear bushing. 05:30 - 08:30 3.00 DRILL PULD SURFAC Picked up 8.5" BHA. 08:30 - 09:30 1.00 DRILL PULD SURFAC Load source in MWD and run Flex DC's. 09:30 - 13:15 3.75 DRILL TRIP SURFAC RIH picking up singles 108 Jts. DP. 13:15 - 14:45 1.50 DRILL TRIP SURFAC POOH and stood back 23 stands DP. 14:45 - 17:00 2.25 DRILL TRIP SURFAC RIH picking up singles to 3188'.6' of cement above plugs. 17:00 - 17:45 0.75 DRILL CIRC SURFAC Made up TD and filled pipe. 17:45 - 19:00 1.25 CASE OTHR SURFAC Rigged up and tested casing to 2500 PSI for 30 min. 19:00 - 20:15 1.25 DRILL OTHR SURFAC Drilled out shoe track, cleaned rat hole and drillied from 3285 to 3305'. 20: 15 - 20:30 0.25 DRILL CIRC SURFAC CBU and had PJSM. 20:30 - 20:45 0.25 DRILL CIRC SURFAC Displaced LSND mud into hole. 20:45 - 22:00 1.25 DRILL FIT SURFAC Rigged up and performed FIT to 18.3 PPG EMW. 22:00 - 00:00 2.00 DRILL DRLG INTRM1 Drillied 8.5" Directional hole from 3305' to 3461'. ART 1.75 Hrs. TD RPM 60 WOB 15 K GPM 550. Up Wt. 115 K Down Wt. 75 K Rot wt. 93 K. Torque On Btm. 7/8 K Off Btm. 6 K. 4/25/2003 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drilled and Surveyed 8.5" Directional hole from 3461' to 6095'. TD RPM 100, WOB 10/20 K, GPM 550, PP 2450 PSI. ART 14.58 Hrs. AST .77 Hrs. Up Wt. 160 K, Down Wt. 85 K, Rot Wt. 112 K. Torque Off Btm. 9/10 K, On Btm. 10 K Ft. Lbs. Ave BG Gas 120. Max Gas 1200 IU @ 5,839' (C-40). 4/26/2003 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drilled and surveyed 8.5" Directional hole from 6095' to 8565'. WOB 20/30 K, TD RPM 100, GPM 530. ART 13.06 Hrs. AST .84 Hrs. Up Wt. 200 K, Down 97 K, Rot 130 K. Torque On Btm. 14000 Off 12000 Ft. Lbs. Ave BG Gas 170 IU. 4/27/2003 00:00 - 00:30 0.50 DRILL DRLG INTRM1 IDrilled and surveyed 8.5" Directional hole from 8565' to 8610'. WOB 20/30 K, TD RPM 100, GPM 530. ART .5 Hrs. AST 0 Hrs. Up Wt. 200 K, Down 97 K, Rot 130 K. Torque On Btm. 14000 Off 12000 Ft. Lbs. Ave BG Gas 170 IU. 00:30 - 01 :45 1.25 DRILL CIRC INTRM1 Circulated sweep BU X2. 01 :45 - 07:45 6.00 DRILL WIPR INTRM1 POOH to Casing shoe for wiper trip. Tight hole backreamed from 8058' to 7600'. Pulled good after that. 07:45 - 09:45 2.00 RIGMNT RSRV INTRM1 Serviced crown and Top Drive. Slipped and cut Drilling line. 09:45 - 14:00 4.25 DRILL WIPR INTRM1 RIH to 8610' filled pipe every 10 stands. No problem. 14:00 - 15:30 1.50 DRILL CIRC INTRM1 Circulated and cleaned hole. Shakers were loaded with cuttings. Max gas 2200 IU. Monitered ECD. 15:30 - 20:00 4.50 DRILL DRLG INTRM1 Drilled and surveyed 8.5" Directional hole from 8610' to 8910'. WOB 10/30 K, TD RPM 100, GPM 500. ART 4.04 Hrs. AST 0 Hrs. Up Wt. 230 K, Down 105 K, Rot 147 K. Torque On Btm. 15000 Off 14000 Ft. Lbs. Ave BG Gas 100 IU. Rap was slowed for logging from 8792' to 8869' (60/30 FPH). 20:00 - 21 :00 1.00 DRILL CIRC INTRM1 Circulated BU. Received orders to plug back and side track. 21 :00 - 00:00 3.00 DRILL TRIP INTRM1 POOH with normal drag(10-25 K) to 5135' (had 45 K). Continued POOH Printed: 5/16/2003 10:49: 11 AM ") ') CanocoPhillips Alaska Operations Summary Report Page 3 Qf 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-17 38-17 ROT - DRILLING N 1268 @ ppco.com Nabors 7E8 Start: 4/20/2003 Rig Release: 5/4/2003 Rig Number: Spud Date: 4/21/2003 End: 5/4/2003 Group: 4/27/2003 21 :00 - 00:00 3.00 DRILL TRIP INTRM1 with normal drag to 5057'. 4/28/2003 00:00 - 02:30 2.50 DRILL TRIP INTRM1 POOH to 922'. 02:30 - 03:30 1.00 DRILL TRIP INTRM1 Layed down jars and picked up and stood back new jars. 03:30 - 04:30 1.00 DRILL OTHR INTRM1 PJSM and removed RA source. Picked up flex collar. 04:30 - 06:00 1.50 DRILL PULD INTRM1 Download MWD. 06:00 - 07:00 1.00 DRILL PULD INTRM1 Finished laying down MWD, Motor, and bit. 07:00 - 07:30 0.50 DRILL OTHR INTRM1 Cleared and cleaned off rig floor. 07:30 - 08:15 0.75 ABANDJ\ RURD ABANDN Move to rig floor and RU power tongs and elevators for 3 1/2" tubing. 08:15 - 08:30 0.25 ABANDJ\ SFTY ABANDN Held prejob safety meeting with Nabors casing and rig crew. 08:30 - 10:30 2.00 ABANDJ\ TRIP ABANDN PU 30 jts of 3 1/2" tubing for plug setting - RD power tongs - change elevators to 5". 10:30 - 13:45 3.25 ABANDJ\ TRIP ABANDN RIH with 948' tubing tail below 5" drill pipe to 8910, no problems. PUW 178K SOW 100K. 13:45 - 15:45 2.00 ABANDJ\ CIRC ABANDN Stage pumps up to 10 bpm I 1265 psi and condition mud mud for cementing - 11.3 ppg in /11.35 ppg out - max trip gas 420 units @ BU - full returns throughout. LD 1 jt and rig up cement lines. Establish rate / pressure with mud 10 bpm /1443 psi. Held PJSM while cond mud. 15:45 - 16:30 0.75 CEMENT PLUG ABANDN Line up to Dowell - pumped 5 bbls of FW and tested lines to 3000 psi. Pumped additional 5 bbls of FW ahead. Plugged back 8 1/2" open hole from 8906' with 33 bbls of 15.8 ppg G cmt - displaced with rig pumps to equalization. CIP @ 1625 hrs - ETOC @ 8561' (w/35% excess). 16:30 - 17:15 0.75 ABANDJ\ TRIP ABANDN Pulled to 8253' - circ 50 bbls of mud to clean up drill pipe - 10 bpm / 1150 psi. 17:15 - 17:45 0.50 ABANDJ\ TRIP ABANDN POH to 7093'. 17:45 - 18:30 0.75 ABANDJ\ CI RC ABANDN Establish circ- pumped 30 bbls 12.3 ppg / 300+ vis pill and displaced to eqalization - est top @ 6736'. 18:30 - 19:00 0.50 ABANDJ\ TRIP ABANDN POOH to 6777'. 19:00 - 19:45 0.75 ABANDJ\ CIRC ABANDN CBU. 19:45 - 20:15 0.50 CEMENT PLUG ABANDN Line up to Dowell - pumped 5 bbls of FW and tested lines to 3000 psi. Pumped additional 15 bbls of FW ahead. Plugged back 8 1/2" open hole from 6777' with 57 bbls of 17.1 ppg G cmt followed by 4 Bbls water- displaced with rig pumps to equalization. CIP @ 2015 hrs- ETOC @ 6200' (w/35% excess). 20: 15 - 20:45 0.50 CEMENTTRIP ABANDN POOH 7 stands to 6120'. 20:45 - 21:15 0.50 ABANDJ\ CIRC ABANDN Circulated out contaminated mud. 21:15-00:00 2.75 ABANDJ\ TRIP ABANDN POOH. 4/29/2003 00:00 - 01 :00 1.00 ABANDJ\ TRIP ABANDN Fin POOH with 5" DP to 31/2" Tbg Stinger 01 :00 - 02:00 1.00 ABANDJ\ RURD ABANDN RU Nabors 31/2" Tbg Tongs & Elevators 02:00 - 02:45 0.75 ABANDJ\ TRIP ABANDN Started POOH LD 3 1/2" Stinger, Started Pulling Wet with Thick Mud after 5 Jts 02:45 - 03:15 0.50 ABANDJ\ CIRC ABANDN Circ Out Cement Contaminated Mud from 3 1/2" Tbg 03:15 - 05:15 2.00 ABANDJ\ TRIP ABANDN Fin POOH & LD 25 Jts of 31/2" Tbg Stinger, LD a Total of 30 Jts 05:15 - 05:45 0.50 ABANDJ\ RURD ABANDN RD Nabors 31/2" Tbg Tongs & Elevators 05:45 - 06:00 0.25 ABANDJ\ PULD ABANDN Pulled Wear Bushing 06:00 - 09:00 3.00 WELCTL BOPE PROD RU & Tested BOP Rams, Choke Manifold and Valves to 250 Psi Low & 5,000 Psi High, Tested Annular to 250/3,500 Psi, Note: Chuck Scheave with AOGCC Waived Witnessing of BOP Test 09:00 - 10:15 1.25 WELCTL OTHR PROD LD 7" Test JT & Blow Down Lines, Installed Wear Bushing, Cleaned Rig Floor 10:15 - 13:15 3.00 DRILL PULD PROD PU & MU Bit #3, MM and MWD Orient & Upload MWD and Surface Test Same Printed: 5/16/2003 10:49: 11 AM ) .ConocoPhillips Alaska, Operations Summary Report Page 40f 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-17 3S-17 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 4/20/2003 Rig Release: 5/4/2003 Rig Number: Spud Date: 4/21/2003 End: 5/4/2003 Group: 4/29/2003 13:15 - 13:30 0.25 DRILL SFTY PROD Held PJSM with Sperry Sun on Loading Radioactive Sources 13:30 - 15:00 1.50 DRILL TRIP PROD Loaded Radioactive Sources and TIH with BHA #3 to 3,275', (95/8" Csg Shoe) 15:00 - 16:00 1.00 RIGMNT RSRV PROD Serviced Top Drive, Greased Blocks and Crown 16:00 - 16:30 0.50 DRILL CIRC PROD Circ Btms Up at Shoe at 500 Gpm, 1,980 Psi 16:30 - 18:00 1.50 DRILL TRIP PROD TIH and Tagged Top of Cement Plug at 6,120' with 10K Wt on Plug 18:00 - 18:30 0.50 DRILL DRLG PROD Drilled Med-Hard Cmt from 6,120' to 6,160' with 5-1 OK WOB, 500 Gpm at 2,450 Psi 18:30 - 19:30 1.00 DRILL CIRC PROD Circ Out Cmt Contaminated Mud, Circ at 500 Gpm at 2,450 Psi 19:30 - 00:00 4.50 DRILL DRLG PROD Sidetracked Well at 6,160', Drill, Slide & Survey from 6,160' to 6,564' MDI 4,530' TVD, (404') 10-20K WOB, 100 Rpm's, 520 Gpm, Off Btm Press 2,000 Psi, On Btm 2,130 Psi, Off Btm Torque 11 K Ft#'s, On Btm 11 K Ft#'s, Rot Wt 118K, Pu Wt 180K, Dn Wt 88K, Ave Bgg 35 Units, 10.6 ppg Mw with 12.0 ECD 4/30/2003 00:00 - 05:30 5.50 DRILL DRLG PROD Dril, Slide & Survey from 6,564' to 7,100' MD/4,878' TVD (536'), ART 1.33 Hrs, AST 1.98 Hrs 05:30 - 06:00 0.50 RIGMNT RGRP PROD Changed Out Swab on #1 Mud Pump 06:00 - 12:00 6.00 DRILL DRLG PROD Drill from 7,100' to 7,560' MD/5,293' TVD (460'), ART 2.81 Hrs, AST .88 Hrs, 20-25K WOB, 100 Rpm's, 178 Spm, 525 Gpm, Off Btm Press 2,400 Psi, On Btm 2,550 Psi, Off Btm Torque 12K Ft#'s, On Btm 13.5K Ft#'s, 10.6 ppg Mw with Ave 12.5 ECD, Ave BGG 50 Units 12:00 - 21 :30 9.50 DRILL DRLG PROD Drill from 7,560' to 8,610' MD/5,853' TVD (1,050') ART 5.09 Hrs, AST .33 Hrs, 20-30K WOB, 100 Rpm's, 178 Spm, 525 Gpm, Off Btm Press 2,550 Psi, On Btm 2,925 Psi, Off Btm Torque 13.5K Ft#'s, On Btm 14K Ft#'s, Raised MW from 10.6 ppg to 11.3 ppg per Wt Up Schedule, ECD's with 11.3 MW Ave 13.3, Ave BGG 80 Units, Rot Wt 135K, Up WT 215K, Dn Wt 95K, EST Tops of HRZ 8,166' MDI 5,560' TVD, K-1 Sand 8,545' MDI 5,810"TVD 21 :30 - 23:15 1.75 DRILL CIRC PROD Circ Hole for Wiper Trip, Circ Btms Up, Max Gas from K-1, 190 Units Then Dropped Out to Ave 90 Units, Pumped Weighted Sweep & Circ Out with 10-20% Increase in Cuttings, Circ Clean, Circ at 500 Gpm at 2,400 Psi, Lowered ECD from 13.2 to 12.8 23: 15 - 00:00 0.75 DRILL WIPR PROD Monitored Well-Static, Started POOH, at 8,245' Pulled 30K Thru HRZ, Backreamed Out from 8,245' to 8,160' 5/1/2003 00:00 - 03:15 3.25 DRILL WIPR PROD Fin Wiping Hole to 6,000', Backreamed Thru Morraine Sand from 8,160' to 7,509', POOH from 7,509' to 6,000' with No Problems 03:15 - 05:15 2.00 DRILL WIPR PROD RIH to Btm with No Problems 05:15 - 06:45 1.50 DRILL CIRC PROD Circ Btms Up, Max Gas 420 Units, Pumped Weighted Sweep & Circ Out with 10-20% Increase in Cuttings, Circ Hole Clean at 110 Rpm's, 500 Gpm's, 2,200 Psi, 11.3 MW In & Out ECD 12.5, BGG Ave 50 Units 06:45 - 12:00 5.25 DRILL DRLG PROD Drill from 8,610' to 8,949' MD/6,083' TVD (339') T.D., ART 3.37 Hrs, AST -0-, Control Drilled KUP ·C" Sand @ 100'/Hr For Logs, 20-25K WOB, 100 Rpm's Top of KUP ·C· at 8,640' MDI 5,873' TVD, Max Gas 600 Units, Dropped Out to Ave 50 Units, With 11.3 ppg MW at 480 Gpm, 2,450 Psi Ave 12.5 ECD and No Mud Loss, at TD Rot WT 145K, PU Wt 230K, Dn Wt 11 OK, Off Btm Torque 13.5K Ft#'s, On Btm 15K Ft#'s. 12:00 - 12:45 0.75 DRILL CIRC PROD Circ Weighted Sweep Out of Hole with 10% Increase In Cuttings, Circ at 500 Gpm, 2,400 Psi 12:45-15:00 2.25 DRILL WIPR PROD Monitored Well-Static, POOH 20 Stds to 7,509', Top of Morraine Sand, No Problems 15:00 - 16:00 1.00 DRILL WIPR PROD TIH to Btm with No Problems 16:00 - 18:00 2.00 DRILL CIRC PROD Circ Btms Up, Max Gas 200 Units from Wiper Trip, Pumped Weighted Printed: 5/16/2003 10:49: 11 AM .) ) ConocoPhillips ·Alaska Operations Summary Report Page 5 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-17 38-17 ROT - DRILLING N1268@ppco.com Nabors 7E8 Start: 4/20/2003 Rig Release: 5/4/2003 Rig Number: Spud Date: 4/21/2003 End: 5/4/2003 Group: 5/1/2003 16:00 - 18:00 2.00 DRILL CIRC PROD Sweep & Circ Out with 10-20% Increase in Cuttings, Circ at 500 Gpm, 2,200 Psi, 100 Rpms, Circ 4x Btms Up, Pumped & Spotted 40 bbl, 40 ppb LCM Across Kup Sand 18:00 - 22:00 4.00 DRILL TRIP PROD Monitored Well- Static, POOH 20 Stds to 6,943' with No Problems, Pumped Dry Job and Cont POOH, Pulled 40K Over at 5,279' (C-80 Sand) 22:00 - 00:00 2.00 DRILL TRIP PROD Backreamed Out from 5,279' to 4,964' at 500 Gpm, 1,900 Psi, 80 Rpm's with 10K Ft#'s Torque, Had to Work Thru Several Spots While Backreaming Out, 1 Spot at 5,170' Tight, Went Back Down After Reaming Each Std & Ck Ok 5/2/2003 00:00 - 01 :00 1.00 DRILL TRIP PROD Cont to Backream Out from 4,964' to 4,774', Pulled from 4,869' to 4,774' W/O Pump On & Had No Problems 01 :00 - 04:00 3.00 DRILL TRIP PROD Cont POOH to Shoe with No Problems, Monitored Well-Static, Pumped Dry Job & POOH to 190', Stood Back HWDP, SLM No Corr. 04:00 - 04:15 0.25 DRILL TRIP PROD Monitored Well-Static, LD 2 Flex Dc's 04: 15 - 04:30 0.25 DRILL SFTY PROD Held PJSM with Sperry Sun on Removing Radioactive Sources 04:30 - 07:30 3.00 DRILL TRIP PROD Removed Radioactive Sources, Downloaded MWD and LD BHA #3 07:30 - 08:00 0.50 DRILL TRIP PROD Pulled Wear Bushing & Cleaned Rig Floor 08:00 - 09:15 1.25 CASE RURD PROD RU Nabors 7" Csg Equipment and Franks Fill Up Tool 09:15 - 09:45 0.50 CASE SFTY PROD Held PJSM on Running 7" Csg 09:45 - 10:30 0.75 CASE RUNC PROD MU 7" Float Shoe, 4 Jts 7" 40# L-80 BTC-Mod Csg, Float Collar & RIH, Thread Locked Conn Below Float Collar, Attempted to Fill Pipe & Franks Tool was Plugged 10:30 - 11 :30 1.00 CASE RURD PROD RD Franks Fill Up Tool & MU Fill Up Hose and Circ Thru Shoe Trac & CkOk 11 :30 - 13:30 2.00 CASE RUNC PROD RIH with 25 Jts of 7" Csg to 1,015' 13:30 - 13:45 0.25 CASE RURD PROD Re-Installed Redressed Franks Fill Up Tool & Pumped Thru & Ck Ok 13:45 - 17:15 3.50 CASE RUNC PROD RIH to 3,248',95/8" Csg Shoe (80 Jts Total in Hole) 17:15 - 17:45 0.50 CASE CIRC PROD Staged Pumps Up to 250 Gpm, 6 Bpm at 550 Psi & Circ Btms Up, Up Wt 110K, Dn Wt 53K 17:45 - 20:45 3.00 CASE RUNC PROD RIH with 56 Jts of 7" Csg to 5,535' with No Problems', (136 Jts Total in Hole) 20:45 - 21 :15 0.50 CASE CIRC PROD Staged Pumps Up to 210 Gpm, 5 Bpm at 530 Psi & Circ Btms Up, Up Wt 140K, Dn Wt 83K 21:15 - 23:45 2.50 CASE RUNC PROD RIH with 48 Jts of 7" Csg to 7,488' with No Problems, (184 Jts Total in Hole) 23:45 - 00:00 0.25 CASE CIRC PROD Began Circ Btms Up at 7,488', Staged Pumps Up to 126 Gpm, 3 Bpm at 630 Psi, Up Wt 195K, Dn Wt 90K 5/3/2003 00:00 - 00:45 0.75 CASE CIRC PROD Circ Btms Up at 7,488', Circ at 5 Bpm at 540 Psi, 205K Up Wt, 90K Dn 00:45 - 03:00 2.25 CASE RUNC PROD Fin RIH with 7" Csg, MU Landing Jt & Landed Csg, Ran a Total of 219 Jts of 9 5/8" 7" 26# BTC-Mod Csg, 8,937. 81', Landed Fit Shoe at 8,938' with Fit Collar at 8,783' 03:00 - 04:15 1.25 CASE CIRC PROD Est Circ Thru Fill Up Tool, Increased Rate up to 6 Bpm at 1,000 Psi, Began Reciprocating Pipe after Est Circ, after 30 Min Pipe Began to Get tight and Landed Csg in Hanger, Up Wt 265K, Dn Wt 95K When Landed, Circ Btms Up, Max Gas 70 Units 04:15 - 04:45 0.50 CASE RURD PROD LD Franks Fill Up Tool & MU Cement Head & Lines 04:45 - 06:00 1.25 CASE CIRC PROD Cont to Circ Csg for Cementing, Held PJSM with Dowell, APC and Rig Crew, Batch Mixed Cement While Circ, Final Rate of 6 Bpm at 775 Psi, Circ 2.5 Btms Up with 11.3 ppg, 46 Vis and 19 YP Mud Out 06:00 - 06:45 0.75 CEMENT PUMP PROD Turned Over to Dowell, Dowell Batch mixed 40 bbls CW1 00 @ 8.3 ppg, 50 bbls MudPUSH @ 12.5 ppg, 300 sxs (62 bbls) @ 15.8 ppg Class "G" at 1.16 with Additives, Pump 10 bbls CW100, Test lines to 3,500 Printed: 5/16/2003 10:49: 11 AM ) ) ConocoPhillips Alaska Operations Summary Report Page 69f 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-17 3S-17 ROT - DRILLING N 1268@ ppco.com Nabors 7E8 Start: 4/20/2003 Rig Release: 5/4/2003 Rig Number: Spud Date: 4/21/2003 End: 5/4/2003 Group: 5/3/2003 06:00 - 06:45 0.75 CEMENT PUMP PROD psi, Pump 30 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at ave. rate of 4.8 Bpm at 650 psi, Drop #2 btm plug, Pump 62 bbls cmt at ave rate of 4.6 bpm at 425 psi, Shut down 06:45 - 08:00 1.25 CEMENT DISP PROD Flush lines to rig floor with seawater, Drop top plug, Dowell Displace cement, after 300 bbls of 8.5 ppg seawater pumped at an ave rate of 7 bpm at 1,000 psi and 23.5 bbls cmt out of shoe, lost returns, slowed rate to 4 bpm at 1,975 psi then to 3.0 bpm at 1,725 psi & bumped plug wI total of 336.5 bbls, Bumped plug wI 2,150 psi, Checked Floats & Held, Bled back 2 bbls for a total of 334.5 total bbls displaced (Calculated 336.5 bbls), CIP @ 07:45 hrs 5/3103, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. 08:00 - 08:30 0.50 CEMENT RURD PROD RD Dowell, Cmt Head & Blow Down Lines 08:30 - 09:30 1.00 CASE RURD PROD LD Landing Jt & RD Csg Elevators, Changed out elevator bails, Flushed Out Stack & Riser 09:30 - 10:30 1.00 WELCTL OTHR PROD Installed 7" Csg Pack-Off and Tested Same to 5,000 Psi for 15 Min 10:30 - 10:45 0.25 CMPL TN SFTY CMPL TN Held PJSM on RU & Running 3 1/2" Completion 10:45 - 11 :15 0.50 CMPL TN RURD CMPL TN RU Nabors 31/2" Tbg Tongs & Handling Tools 11:15 -12:00 0.75 CMPLTN PULD CMPL TN MU 3 1/2" completion equipment: WLEG wi shear out sub I pup - Camco "d" nipple wi 2.75" no go - 2 pups - xo 3.5" X 4.5" - Mill out ext- Baker SAB-3 packer - KBH-22 Tubing anchor - Baker 80-40 PBR - Locator sub - pup - 1 it 31/2",9.3#, L-80 tbg - Camco "DS" nipple wi 2.813 profile - 1 it tubing - pup - Camco MMG wI DCR shear valve - pup 12:00 - 21 :00 9.00 CMPL TN RUNT CMPL TN RIH WI Completion Assembly PU 3 1/2" 9.3# L-80 EUE-Mod Tbg ( 267 Jts total 8,343.65'). PU it #284 with 8' Pup Jt to put packer on depth. 21 :00 - 22:00 1.00 CMPL TN DEQT CMPL TN RU & Tested 7" Csg to 3,500 Psi for 30 Min, Good Test 22:00 - 23:00 1.00 CMPLTN OTHR CMPL TN Dropped 2" Packer Setting Ball, Performed LOT on 7" x 9 5/8" Ann While Ball Dropped, LOT to 15.6 ppg EMW with 570 psi 23:00 - 00:00 1.00 CMPL TN RUNT CMPL TN Set Baker Packer Per Setting Procedure with No Problems, Set 31/2" x 7" Pkr at 8,311', PBR at 8,296' with WLEG at 8,343' 5/4/2003 00:00 - 01 :00 1.00 CMPL TN RUNT CMPL TN LD Jt # 268 with 8' Pup, MU Tbg Hanger on Landing Jt and Landed 3 1/2" Completion String & RILDS 01 :00 - 02:30 1.50 CMPL TN DEQT CMPL TN RU & Tested 31/2" Tbg to 3,500 Psi for 15 Min, Bled Press to 1,500 Psi and Press Tested 31/2" x 7" Ann to 3,500 Psi for 15 Min, Good Tests, Bled Off Press, Press Up on Ann and Sheared DCR Valve at 3,400 Psi, LD Landing Jt, Sim Op's Cleaning Pits 02:30 - 04:45 2.25 WELCTL NUND CMPL TN Installed TWC Valve and ND BOP's 04:45 - 06:30 1.75 CMPL TN NUND CMPL TN NU Gen V 5K# Tree & Adadpter Spool, RU & Tested Void and Tree to 5,000 Psi and Ck Ok. Pulled TWC 06:30 - 07:30 1.00 CMPL TN RURD CMPL TN RU to Freeze Protect Tbg and Ann, RU to LD Excess DP from Derrick 07:30 - 12:00 4.50 CMPL TN RURD CMPL TN LD 46 Stds (138 Jts) of Excess 5" DP from Derrick SIM OP'S: Freeze Protected 3 1/2" Tbg and Ann with 130 bbls of Diesel 12:00 - 14:00 2.00 CMPL TN RURD CMPL TN Blow Down Inj. Line Used to Freeze Protect Well & RD, MU Lubricator & Set BPV, Fin Cleaning Seawater from Mud Pits and Cleaned Cellar RELEASED RIG at 14:00 Hrs 5/4/03 to Move Rig to 3S-06 Printed: 5/16/2003 10:49: 11 AM Date 05/06/03 05/07/03 ) ) 3S-17A Event History Comment DRIFT TBG WI 2.70" CENT, TAGGED FILL @ 8752' RKB, DRIFT WI 23' X 2.60" HCDG TO 8752' RKB, FOUND GLM POCKET OPEN ( WITH OUT 1.5" DCR) SET 1.5" DV @ 8212' RKB, PRESSURE TESTED IA & TBG GOOD [GLV] LOG CBL USING SLIM CEMENT MAPPING TOOL. TAG TD AT 8752' & LOG PASS AT 1800 FPH FROM TD TO 8275' WITH 1000 PSI WHP. PASS SHOWED FAIR TO GOOD CEMENT BOND FOR APPROX 60' ABOVE ZONE OF INTEREST. BOTTOM HOLE PREssrrEMP: 3078 PSI & 158.6 DEGF. DECISION TO PERFORATE. PERF 8643' - 8666' USING 2.5" HSD GUNS LOADED WITH 2506 POWERJET HMX CHARGES, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. Page 1 of 1 5/16/2003 ) ) ~Oj'~L)rO 12-May-03 AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-17 A Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: 6,121.33 I MD Window / Kickoff Survey: 6,160.00' MD (if applicable) Projected Survey: 8,949.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED MAY 13 2003 AJa8i<a Q¡'¡ & Gas Cons. Cornmission Anchorage Sperry-Sun Drilling Services DEF\N\T'VE Western North Slope ConocoPhillips Kuparuk 3S Pad 3S-17A ~ Job No. AKZZ0002401952. Surveyed: 1 May, 2003 Survey Report 9 May, 2003 Your Ref: API 501032044801 Surface Coordinates: 5993883.06 N, 476130.01 E (70023' 39.9035" N, 150011'39.1685" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '-' Surface Coordinates relative to Project H Reference: 993883.06 N, 23869.99 W (Grid) Kelly Bushing: 56.46ft above Mean Sea Level Elevation relative to Project V Reference: 56.46ft Elevation relative to Project V Reference: 56.46ft !5pE5!!r".......Y-sUF1 DRIL.L.ING SeRVIc:es A Halliburton Company Survey Ref: 5vy2035 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-17A Your Ref: API 501032044801 Job No. AKZZ0002401952, Surveyed: 1 May, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inc1. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6121.33 54.790 301.040 4205.87 4262.33 2082.72 N 3413.42 W 5995976.67 N 472723.26 E QESJNFfWE _ 6160.00 54.740 300.910 4228.18 4284.64 " 2098.97 N 3440.50 W 5995993.01 N 472696.23 E 6219.08 53.770 296.330 4262.70 4319.16 2121.94 N 3482.57 W 5996016.11 N 472654.24 E 6313.20 52.990 291.730 4318.87 4375.33 2152.70 N 3551.52 W 5996047.09 N 472585.38 E 4.009 -808.19 6407.50 51.930 288.570 4376.33 4432.79 2178.47 N 3621.70 W 5996073.08 N 472515.29 E 2.885 -808.40 6499.86 51.440 283.590 4433.62 4490.08 2198.54 N 3691.29 W 5996093.38 N 472445.76 E 4.263 -803.46 .~ 6594.21 50.970 278.750 4492.75 4549.21 2212.79 N 3763.39 W 5996107.85 N 472373.70 E 4.029 -792.19 6688.16 49.390 274.010 4552.93 4609.39 2220.84 N 3835.06 W 5996116.13 N 472302.06 E 4.223 -775.24 6782.36 48.950 266.980 4614.57 4671.03 2221.47 N 3906.25 W 5996116.99 N 472230.87 E 5.665 -751.48 6878.31 49.130 261.720 4677.49 4733.95 2214.33 N 3978.31 W 5996110.08 N 472158.79 E 4.143 -720.13 6972.37 49.740 256.550 4738.68 4795.14 2200.86 N 4048.44 W 5996096.83 N 472088.62 E 4.225 -683.48 7067.94 49.070 251.890 4800.89 4857.35 2181.15N 4118.24 W 5996077.35 N 472018.76 E 3.768 -641.09 7161.85 50.350 247.980 4861.63 4918.09 2156.56 N 4185.49 W 5996052.97 N 471951.43 E 3.456 -594.98 7257.26 50.650 246.410 4922.32 4978.78 2128.02 N 4253.35 W 5996024.65 N 471883.48 E 1.308 -544.96 7351.75 51.300 242.940 4981.83 5038.29 2096.62 N 4319.68 W 5995993.4 7 N 471817.05 E 2.934 -492.76 7446.57 51.530 241.590 5040.97 5097.43 2062.13 N 4385.28 W 5995959.18 N 471751.34 E 1.139 -437.91 7537.79 50.830 241.480 5098.15 5154.61 2028.26 N 4447.76 W 5995925.51 N 471688.75 E 0.773 -384.71 7633.77 51.220 239.380 5158.52 5214.98 1991.43 N 4512,65 W 5995888.89 N 471623.74 E 1.749 -327.92 7725.65 50.740 239.350 5216.37 5272.83 1955.06 N 4574.07 W 5995852.71 N 471562.21 E 0.523 -272.73 7820.65 50.460 238.990 5276.67 5333.13 1917.44 N 4637.11 W 5995815.29 N 471499.05 E 0.415 -215.82 7914.86 49.700 239.460 5337.13 5393.59 1880.47 N 4699.18 W 5995778.52 N 471436.86 E 0.893 -159.85 8007.87 48.750 239.190 5397.87 5454.33 1844.53 N 4759.76 W 5995742.78 N 471376.16 E 1.045 -105.36 8102.29 47.550 238.820 5460.86 5517.32 1808.32 N 4820.05 W 5995706.76 N 471315.76 E 1.304 -50.71 8194.32 49.170 236.980 5522.01 5578.4 7 1771.76 N 4878.30 W 5995670.39 N 471257.39 E 2.309 3.56 ..~ 8287.19 49.010 236.500 5582.83 5639.29 1733.27 N 4936.99 W 5995632.09 N 471198.58 E 0.427 59.81 8381.61 48.480 236.160 5645.09 5701.55 1693.92 N 4996.06 W 5995592.92 N 471139.38 E 0.623 116.99 8475.33 48.440 235.810 5707.24 5763.70 1654.68 N 5054.21 W 5995553.87 N 471081.11 E 0.283 173.75 8566.60 48.000 235.450 5768.05 5824.51 1616.25 N 5110.39 W 5995515.62 N 471024.81 E 0.565 229.07 8658.94 47.770 235.890 5829.98 5886.44 1577.62 N 5166.95 W 5995477.18 N 470968.12 E 0.432 284.72 8752.99 47.460 234.830 5893.38 5949.84 1538.14 N 5224.11 W 5995437.87 N 470910.84 E 0.895 341.37 8850.56 46.910 235.050 5959.69 6016.15 1497.03 N 5282.69 W 5995396.95 N 470852.12 E 0.587 400.04 8881.31 46.800 235.380 5980.72 6037.18 1484.23 N 5301.12 W 5995384.21 N 470833.66 E 0.861 418.37 8949.00 46.800 235.380 6027.06 6083.52 1456.19 N 5341.73 W 5995356.30 N 470792.96 E 0.000 458.60 Projected Survey 9 May, 2003 - 13:45 Page 2 of 3 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-17A Your Ref: API 501032044801 Job No. AKZZ0002401952, Surveyed: 1 May, 2003 ConocoPhiJ/ips Western North Slope All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.46' MSL. Northings and Eastings are relative to 2533' FNL, 1130' 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 2533' FNL, 1130' FEL and calculated along an Azimuth of 200.000° (True). Magnetic Declination at Surface is 25.121 0(19-Apr-03) ',-- Based upon Minimum Curvature type calculations, at a Measured Depth of 8949.00ft., The Bottom Hole Displacement is 5536.65ft., in the Direction of 285.249° (True). .-../ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6121.33 6160.00 8949.00 4262.33 4284.64 6083.52 2082.72 N 2098.97 N 1456.19 N 3413.42 W 3440.50 W 5341.73 W Tie On Point Window Point Projected Survey Survey tool program for 3S-17A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) -' 0.00 267.00 0.00 266.88 267.00 8949.00 266.88 Tolerable Gyro (3S-17 Gyro) 6083.52 AK-6 BP _IFR-AK (3S-17) 9 May, 2003 - 13:45 Page 3 of 3 DrilfQuest 3.03.02.005 ) ') 12-May-03 AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-17A MWD Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: 6,121.33' MD Window I Kickoff Survey: 6,160.00' MD (if applicable) Projected Survey: 8,949.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RE·Cr:~\!~;(l ~,.. ~~ U V ~~,.p. :J Attachment( s) M AY 1 3 r; iì r' '; I . L 'y'¡¡ .... A:\ Q G"'" "..,-~ I"-,-."..""""",,,,-,:~¡ Aia~1!î "",i, 1,:\ ' ...t~." LA1f ¡t::' ',,,~...i; :.,. :...;:,"...,!.. p;;~~~ef!!·ij~·;· ~D8-oro (;) ~ (J' t'~ ~~ (1)~ Sperry-Sun Drilling Services ,-~-. Western North Slope ConocoPhillips Kuparuk 3S Pad 3S-17A MWD Job No. AKMW0002401952, Surveyed: 1 May, 2003 Survey Report 9 May, 2003 /- Your Ref: API 501032044801 Surface Coordinates: 5993883.06 N, 476130.01 E (700 23' 39.9035" N, 1500 11' 39.1685" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993883.06 N, 23869.99 W (Grid) Kelly Bushing: 56.46ft above Mean Sea Level Elevation relative to Project V Reference: 56.46ft Elevation relative to Project V Reference: 56.46ft spe....,......y-sul'l CRILLING seRVIc:es A Halliburton Company Survey Ref: svy2036 DrmQuest 3.03.02.005 Page 2 of 3 9 May, 2003 - 13:45 ~--------- ---- --- ------.---- Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-17A MWD Your Ref: API 501032044801 Job No. AKMW0002401952, Surveyed: 1 May, 2003 ConocoPhiJlips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6121.33 54.790 303.210 4205.99 4262.45 2107.86 N 3398.17 W 5996001.76 N 472738.59 E -818.50 Tie On Point 6160.00 54.740 302.670 4228.30 4284.76 2125.03 N 3424.68 W 5996019.02 N 472712.14 E 1.148 -825.57 Window Point 6219.08 53.770 296.920 4262.84 4319.30 2148.86 N 3466.25 W 5996042.97 N 472670.64 E 8.067 -833.74 6313.20 52.990 292.530 4319.00 4375.46 2180.45 N 3534.83 W 5996074.79 N 472602.16 E 3.834 -839.97 .~ 6407.50 51.930 289.930 4376.46 4432.92 2207.53 N 3604.51 W 5996102.09 N 472532.56 E 2.458 -841.59 6499.86 51.440 285.210 4433.74 4490.20 2229.41 N 3673.56 W 5996124.19 N 472463.58 E 4.044 -838.53 6594.21 50.970 279.220 4492.89 4549.35 2244.97 N 3745.37 W 5996139.98 N 472391.83 E 4.972 -828.59 6688.16 49.390 275.140 4553.06 4609.52 2254.01 N 3816.93 W 5996149.25 N 472320.29 E 3.735 -812.61 6782.36 48.950 267.410 4614.71 4671.17 2255.61 N 3888.09 W 5996151.07 N 472249.14 E 6.225 -789.78 6878.31 49.130 262.640 4677.63 4734.09 2249.33 N 3960.24 W 5996145.02 N 472176.98 E 3.758 -759.20 6972.37 49.740 256.980 4738.82 4795.28 2236.68 N 4030.51 W 5996132.60 N 472106.66 E 4.616 -723.28 7067.94 49.070 252.390 4801.03 4857.49 2217.54 N 4100.47 W 5996113.68 N 472036.64 E 3.713 -681.36 7161.85 50.350 247.690 4861.78 4918.24 2193.07 N 4167.75 W 5996089.43 N 471969.28 E 4.053 -635.36 7257.26 50.650 245.950 4922.47 4978.93 2164.09 N 4235.42 W 5996060.66 N 471901.52 E 1.442 -584.98 7351.75 51.300 241.390 4981.98 5038.44 2131.54N 4301.18 W 5996028.32 N 471835.66 E 3.811 -531.90 7446.57 51.530 238.800 5041.12 5097.58 2094.59 N 4365.42 W 5995991.57 N 471771.30 E 2.149 -475.21 7537.79 50.830 239.850 5098.31 5154.77 2058.33 N 4426.54 W 5995955.51 N 471710.06 E 1.180 -420.23 7633.77 51.220 237.380 5158.68 5215.14 2019.47N 4490.23 W 5995916.86 N 471646.25 E 2.041 -361.93 7725.65 50.740 238.880 5216.53 5272.99 1981.78 N 4550.85 W 5995879.36 N 471585.51 E 1.372 -305.78 7820.65 50.460 239.490 5276.83 5333.29 1944.17 N 4613.89 W 5995841.95 N 471522.35 E 0.577 -248.88 7914.86 49.700 239.250 5337.29 5393.75 1907.36 N 4676.06 W 5995805.34 N 471460.06 E 0.830 -193.02 /-- 8007.87 48.750 237.850 5398.03 5454.49 1870.62 N 4736.15 W 5995768.79 N 471399.86 E 1.530 -137.95 8102.29 47.550 239.250 5461.03 5517.49 1833.92 N 4796.14 W 5995732.28 N 471339.75 E 1.684 -82.94 8194.32 49.170 237.210 5522.18 5578.64 1797.70 N 4854.60 W 5995696.25 N 471281 .17 E 2.417 -28.91 8287.19 49.010 237.580 5583.00 5639.46 1759.88 N 4913.72 W 5995658.62 N 471221.93 E 0.347 26.85 8381.61 48.480 237.140 5645.26 5701.72 1721.59 N 4973.50 W 5995620.53 N 471162.03 E 0.662 83.27 8475.33 48.440 237.030 5707.41 5763.87 1683.47 N 5032.39 W 5995582.60 N 471103.03 E 0.098 139.23 8566.60 48.000 235.340 5768.22 5824.68 1645.60 N 5088.93 W 5995544.90 N 471046.36 E 1 .462 194.16 8658.94 47.770 235.450 5830.15 5886.61 1606.70 N 5145.31 W 5995506.18 N 470989.86 E 0.264 249.99 8752.99 47.460 233.770 5893.55 5950.01 1566.48 N 5201.94 W 5995466.14 N 470933.10 E 1.360 307.16 8850.56 46.910 234.880 5959.86 6016.32 1524.73 N 5260.08 W 5995424.58 N 470874.83 E 1.007 366.27 8881.31 46.800 235.250 5980.89 6037.35 1511.89 N 5278.4 7 W 5995411.79 N 470856.39 E 0.948 384.64 8949.00 46.800 235.250 6027.23 6083.69 1483.76 N 5319.01 W 5995383.80 N 470815.76 E 0.000 424.93 Projected Survey Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-17A MWD Your Ref: AP/501032044B01 Job No. AKMW0002401952, Surveyed: 1 May, 2003 ConocoPhi/lips Western North Slope All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.46" MSL. Northings and Eastings are relative to 2533' FNL, 1130' 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 2533' FNL, 1130' FEL and calculated along an Azimuth of 200.000° (True). ~--. Magnetic Declination at Surface is 25.121 O( 19-Apr -03) Based upon Minimum Curvature type calculations, at a Measured Depth of 8949.00ft" The Bottom Hole Displacement is 5522.09ft., in the Direction of 285.587° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6121.33 6160.00 8949.00 4262.45 4284.76 6083.69 2107.86 N 2125.03 N 1483.76 N 3398.17 W 3424.68 W 5319.01 W Tie On Point Window Point Projected Survey Survey tool program for 3S-17A MWD /-...... From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 267.00 0.00 266.88 267.00 8949.00 266.88 Tolerable Gyro (3S-17 Gyro) 6083.69 MWD Magnetic (3S-17 MWD) -------...---~.- ----- - -~----- 9 May, 2003 - 13:45 Page 3 of3 Dri/fQllest .1.03.02.005 ) ) .~ ~Q3 -æ[) "qq\ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tl1 Avenue, Suite 100 Anchorage, Alaska May 15, 2003 RE:MWD Formation Evaluation Logs 3S-17A, AK-MW-2401952 1 LDWG formatted Disc with verification listing. llPI#: 50-103-20448-01 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 Arctic Blvd. Anchorage, Alaska 99518 Date: Signe~j\.~·R ~"-(~V'- F..,;r-<q,F.'""'"C~E"VE-""'D: .. f=# f"~"" tl ~~~~ e JUN 0 2 2003 Aiaska Ü;; & GEt~ Cene. Comm!55ioo /~lchort!ge ~~~~~ ') ~p~' ConocoPhillipš ) Post Office Box 1 00360 Anchorage, Alaska 99510-0360 Scott Lowry Phone (907) 265-6869 Fax: (907) 265-1535 Email: scott.l.lowry@conocophillips.com May 19, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well 3S-17 A Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that 3S-17 A be pennitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on 3S-17A approximately June 20,2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Dri11ing Report during Celllent job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Production Casing Description 7. Production Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. Details on all wells within ~ Illile of 3S-17 A at the surface casing shoe (N/ A) If you have any questions or require further information, please contact Scott Lowry at 265-6869, or Randy Thomas at 265-6830. Sincerely, _'") _»-?Pt., / Scott Lowry Drilling Engineer cc: 3S-17A Well File Randy Thomas Sharon Allsup-Drake RECEIVED MAY 2 7 Z003 ATO-1576 ATO-1530 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL 0) ') NOTE TO FILE 35-17 A...203-080...303-155 Request for Annular Disposal Approval Summary ConocoPhillips (ConPPCo) has requested approval for annular disposal on the subject well. This is the 5th well on Drill Site 3S that ConPPCo has sought approval for annular disposal. They have submitted the required information. This document analyzes the information and recommends approving their request. Offset Well Information NA-No offset wells were identified within % mile of the surface casing shoe of 3S-17 A. Well 35-17 A Information The surface casing was set when the original wellbore was drilled in late April 2003. In the case of 3S-17, it is noted that over 210 bbls of cement were circulated. Based on spreadsheet calculations, gauge plus 500/0 XS cement was left in the well. It is indicated that the surface casing is adequately cemented. The casing was successfully pressure tested prior to drillout. When tested, the formation did not leak off at about 18.3 ppg EMW. During the 10-minute observation period, the pressure dropped about 380 psi. The well was drilled into the Kuparuk reservoir and the well was plugged back before the 7" casing string was set and cemented. On the injectivity test, the pressure builds steadily to about 540 psi when it sharply breaks and a stabilized injection pressure was developed at about 580 psi. After pumping was stopped, a 100 psi drop was recorded after 1 minute with a stabilized pressure of about 400 psi being reached by the end of 5 minutes and holding for the remainder of the observation period. The pressure plots for 3S-17 are similar to those presented for the other wells. Geologicallnformation This well lies within the Palm development area, which is located within the western margin of the Kuparuk River Unit as defined by the Eighth Expansion of the Unit Area approved by the Division of Oil and Gas on September 26, 2002. The Palm development area is also situated within the boundary of the Kuparuk River Unit aquifer exemption issued by the EPA. I n well 3S-17, the base of the permafrost lies near 1,550' TVD, and the West Sak Sands lie between approximately 2,000' and 2,450' TVD. The 9-5/8 inch casing shoe is set in the Colville Shale at 3,275 MD, about 100' TVD below the base of the West Sak Sands. In the nearby Palm #1 exploratory well (renamed 3S-26), the Colville Shale is several thousand feet thick, and is composed of very soft to moderately firm claystone, mudstone and siltstone, with minor sand and rare conglomerate. In the Geologic Considerations section of Note to File for well 3S-07, Bob Crandall notes that this disposal interval has low mechanical strength, and that the sands are minor, low permeability, low in volume, and frequently hydrocarbon-bearing. He also notes that the Colville Shale has a long track record of successfully receiving annular disposal in the Alpine, Meltwater, Tarn and Kuparuk River Unit areas. M:\tommaunder\Well Information\By Subject\Annular Disposal\030527 _203-043--KRU_3S-17A_AD.doc ) ) Recommendation Based on the presented information, we recommend that ConocoPhillips' request for annular disposal in 3S-17A (203-080) be approved. ~"W(~ Tom Maunder, PE ( Sr. Petroleum Engineer ~ Steve Davies Petroleum Geologist M:\tommaunder\Well Information\By Subject\Annular Disposal\030527 _203-043--KRU_3S-17A_AD.doc ") ) Its/),! JltJ-s -V3ð STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory Stratigraphic _ Service _XX 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2533'FNL, 1130'FEL, Sec. 18, T12N, R8E,UM At top of productive interval 974' FNL, 1510' FEL, Sec. 13, T12N, R7E, UM At effective depth (asp's: 476130, 5993883) (as proposed) At total depth 1131' FNL, 1693' FEL, Sec. 13, T12N, R7E, UM 12. Present well condition summary Total depth: measured true vertical (as proposed) Effective depth: 8949 6084 8752 5949 feet Plugs (measured) feet feet Junk (measured) feet Cemented 82 sx Arctic Crete 465 sx AS IllLite, 326 sx AS 300 sx GasBlok measured true vertical Casing Conductor Surface Production Size 301X16" 9.625" Length 108' 3247' 8910' 7" Perforation depth: measured 8643' - 8666' MD true vertical 5876' - 5891' TVD Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 8344' Packers & SSSV (type & measured depth) Baker SAB-3 pkr @ 8311', No SSSV 13. Attachments Description summary of proposal _XX 14. Estimated date for commencing operation June 20, 2003 16. If proposal was verbally approved Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 28' / 56' AMSL 7. Unit or Property name Other _XX Annular Disposal Kuparuk River Unit 8. Well number 3S-17 A 9. Permit number I approval number 203-080 / 10. API number 50-103-20448-01 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool Measured Depth 108' 3275' 8938' True vertical Depth 108' 2560' 6076' RECEIVED MAY 2 7 Z003 Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program 15. Status of well classification as: Oil Name of approver Date approved Service _XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 0..~ \ ~ ~ Title: Kuparuk Drilling Team Leader R. Th:mas - - ---1 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- ~0 t-<-eßL .:-~ Approved by order of the Commission nr:- ~,\U.!.~~ ~ô1r~g 1'·/:· - ~HH) " Form 10-403 Rev 06/15/88 · OR\G\NAL BOP sketch Gas Suspended _ Questions? Call Scott Lowry 265-6869 S-lf4(O ~ Date Prepared by Sharon Allsup-Drake I Approval no. gC·-=). 'CS5 ~~~\-c\. (J..""\J\(j.~Ths~Q'.:A. \ Commissioner Date t!J 1;/ (J 3 SUBMIT IN TRIPLICATE ) ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. 3 S-1 7 A b. The depth to the base of freshwater aquifers and No aquifers / Base Permafrost = +/- 1546' TVD permafrost, if present. RKB c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. From the 9 5/8" shoe to the cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non-hydrocarbon bearing sands. See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. e. Identify the types and maximum volume of Types of waste can be drilling mud, drilling waste to be disposed of and the estimated density cuttings, cement-contaminated drilling mud, of the waste slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated differential pressure at the outer casing shoe during annular disposal casing shoe during disposal operations is 1939 psi. operation and calculations showing how this See attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT/FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. See attached casing summary sheet and calculation page. 1. Any additional data required by the Commission NA to confirm containment of drilling wastes. ) ') 38-17 A Pressure Calculations for Annular Disposal DET AILS: (¡) !..... "0 Q,) ro "0 Q,) ro .l:: Q,) .l:: ëi5 '(j) 0. 0. 0 0 I.!) M I.!) Q) ..- M c: + ..- "(j) + ro ~ ~ ü '(j) '(j) £e 0. 0. I.!) ..- ..- I ..- ..- L 0 0 ~ IJ) IJ) ro ro C9 (9 ....... ......... ....... .... ........ Q) Toe c :ö :;j I- ~ ch 0> c:: ëñ co Ü ¡::... - .. L ~ <=9-5/8" 40 lb/ft, L-80 BTC casing @ 3275 ft MD (2560 ft TVD) Pburst = 5750 psi, @ 850/0: Pburst85% = 4888 psi Estimated Top of Cement @ 7593 ft MD (5189 ft TVD) (7" csg x 8-1/2" Open hole annulus) <=3-1/2" 9.3 Ib/ft L-80 tubing to 8344 ft MD I packer at 8311' MD <=7" 26 lb/ft, L-80, BTC casing @ 8938 ft MD (6075 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 4598 psi ASSUMPTIONS: · Maximum injection pressure, PApplied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft · Injection gas pressure is 0.11 psi/ft + 1350 psi header pressure CALCULA TIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied - PFonnation Pmax = 12.0 (0.052) (2560)+ 1500 - 0.4525 (2560) Pmax = 1939 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFonnation 4888 = MWmax (0.052) (2560) + 1500 - 0.4525 (2560) MWmax = 34.1 ppg Maximum Fluid Density to Collapse 7" Casing: P collapsc85% = PHydrostatic + P Applied - P GasGradicnt - PHcader 4598 = MWmax (0.052) (5189) + 1500 - (0.11) (5189) - 1350 MWmax = 18.6 ppg ) ) I·.· çonocoPhiUips. Alask,a,.lnc. KRU 3S-17A TUBING (25-8344, 00:3.500, 10:2.992) ~OOUCTION (26-8938, 00:7.000, Wt:26.00) NIP (8257-8258, 00:4.520) SEAL (8295-8296, 00:5.875) ANCHOR (8310-8311, 00:3.500) NIP (8336-8337, 00:4.520) WLEG (8343-8344, 00:4.530) Peri (8~8666) [] [) 3S-17A API: 501032044801 SSSVType: NIPPLE Well Type: SVC Orig Completion: LastW/O: An~le @¿ TS: de~ ~ Angle @ TO: deg @ Annular Fluid: Rev Reason: NEW WELL, GLV design, Tag fill, PERF Last Update: 5/1212003 Ref Lo~ Date: TO: 8938 ftKB Max Hole An~le: 0 de~ @¿ Reference Log: 24.7' RKB Last Tag: 8752 Last Ta~ Date: 5/612003 Casing String - ALL STRINGS Description Size PRODUCTION 7.000 SURFACE 9.625 CONDUCTOR 16.000 Tubing String - TUBING Size I Top 3.500 25 Perforations Summary Interval TVD 8643 - 8666 8643 - 8666 Top Bottom TVD Wt Grade Th rea d 26 8938 8938 26.00 L-80 BTCM 29 3275 3275 40.00 L-80 BTC 29 108 108 62.50 H-40 WELDED TVD Wt Grade Thread 8344 9.30 L-80 EUE8RD Status Ft SPF Date Type Comment 23 6 5/7/2003 IPERF 2.5" HSD 2506 PJ, 60 deg phase, random orient Bottom 8344 Zone Gas Lift Mandrels/Valves St MD TVD Man Man Mfr Type 1 8212 8212 CAMCO MMG Other (:>Iugs, equip., etc.', - JEWELRY Depth TVD Type 25 25 HANGER 499 499 NIP 8257 8257 NIP 8295 8295 SEAL 8310 8310 ANCHOR 8311 8311 PACKER 8336 8336 NIP 8343 8343 WLEG General Notes Date Note 5/3/2003 TREE: FMC I WKM I GEN 5 / 5M TREE CAP CONNECTION: TO 5.75" ACME with 3.5" EUE 8RD THREAD V Mfr V Type V 00 Latch Port TRO Date Run 5/6/2003 Vlv Cmnt RK 0.000 o DMY 1.5 10 3.500 2.875 2.812 2.970 3.250 3.250 2.750 2.982 Description FMC 3.5 GEN 5 TBG HANGER CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE BAKER LOCATOR SUB/SEAL ASSEMBLY W/80-40 PBR KBH-22 ANCHORAGE TUBING SEAL NiPPLE BAKER SAB-3 PACKER WIMILLOUT EXTENSION 10 3.71" CAMCO '0' NIPPLE WINO GO PROFILE BAKER PUMP OUT SUB ) ), _PHILLIPS Alaska, Inc. .. .. A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 9 5/8" Surface CasinQ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 85 Nabors 7ES RT to Lnd Ring UO groove center(Load shoulder= 29.4: FMC Gen V Hanger (Pup = 3.07') (00 of hngr 15.25") 83 Jts 9-5/81140# L-80 BTC Csg Weatherford Model 402 Float Collar (00 10.64", 10 8.865") 2 Jts 9-5/81140# L-80 BTC Csg Weatherford Model 303 Float Shoe (00 10.64", 108.865") Jts 1 to 2 9-5/811 Shoe @ 3,2751 MD 25601 TVD 12-1/411 T.D. @ 3,2851 MD 25661 TVD RUN TOTAL 14 BOWSPRING CENTRALlZERS- 2 on jt.#1 (51 above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 51 below Float Collar) 1 per jt on Jt #3 - #13 (Total of 14 centralizers & 2 Stops) Total of 85 Jts. On tally & inside shed Total of 85 Jts. To be run in hole Total of 104 Jts. On location Use II Run-N-Sealll pipe dope MU torque 8,800 ft/Ib Remarks: Up Wt - 140k On Wt -105k Block Wt - 30k Drifted all casing to 8.67911 Well: 3S-17 Date: 4/23/2003 LENGTH 29.45 3.07 3163.26 1.48 76.08 1.68 DEPTH TOPS 29.45 32.52 3195.78 3197.26 3273.34 3275.02 Supervisor: David Burley / Larry Hill ConocoPhillips A~ska Casing Report Page 1. of 2 Report #: Start: Spud Date: 4/21/2003 Report Date: 4/23/2003 End: 5/4/2003 Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING 1 4/20/2003 General Information String Type: Surface Casing Hole TVD: 2,566.0 (tt) Ground Level: 27.70 (tt) Circ Hours: 2.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: 12.250 (in) (tt) (tt) 29.45 (tt) -....~ Drill Floor 29.56 (tt) (tt) (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 3,285.0 (tt) 111,350 (Ibs) 55.63 (0) 3.00 (days) Casing Flange I Wellhead Model: Gen 5 Packoff Model: Top Hub/Flange: (in) / (psi) BTM Hub/Flange: (in) / (psi) Manufacturer: FMC Hanger Model: Actual TMD Set: 3,275.02 (tt) Item RKB 7 ES Casing Hanger Casing Float Collar Casing Float Shoe Bowspring Centralizer Bowspring Centralizer Bowspring Centralizer Stop Collars Integral Casing Detail . Size Weight Grade Dritt Threads JTS Length Top MU Torq. THD Manufacturer Model Cond. Max 00 MinlD Comp. Name (in.) (I bitt) (in) (ft) (ft) (tt-Ibf) (in) (in) 29.45 9.625 BTC 1 3.07 29.45 15.250 Casing Hanger 9.625 40.00 L-80 8.679 BTC 83 3,163.26 32.52 8.835 9 5/8" 40# L-80 9.625 40.00 L 80 BTC 1 1.48 3.195.78 Float Collar 9.625 40.00 L-80 8.679 BTC 2 76.08 3,197.26 8.835 9 5/8" 40# L-80 ~/ 9.625 40.00 BTC 1 1.68 3,273.34 Float Shoe 3,275.02 Non-Integral Casing Accessories Accessory Manufacturer How Fixed Spacing (tt) Number Interval Top (ft) Bottom (tt) WEATHERFORD WEATHERFORD WEATHERFORD WEATHERFORD 1 1 12 2 Clamped Clamped OverCollar Bolted Printed: 5/19/2003 10:42:54 AM ConocóPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING Report #: Start: 1 4/20/2003 Spud Date: 4/21/2003 Report Date: 4/23/2003 End: 5/4/2003 Remarks Average MU torque first 10 joints = 8800 ft-Ibs Thread locked shoe track [3 jts] Used Jet Lube Run -N- Seal pipe dope Drifted all casing to 8.679" ..~ Operational Detail: RU 95/8" slips, elevator,tiII up tool, long bails and Nabors tongs. Held safety and opts meeting with crew. Mu 9 5/8" shoe track and circ to check floats, all joints 40#, L-80 BTC casing. RIH to 3275', (85) jts total - (washed through @ 1990'). MU landing joint and land casing in wellhead. FC @ 3196' I FS @ 3275' PUW 140K SOW 105K Block Wt 30K. ~ Printed: 5/19/2003 10:42:54 AM ) ') Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Cmtd. Csg: Report #: Start: 1 4/20/2003 Cementer: Kevin Anderson Pipe Movement: Reciprocating Spud Date: 4/21/2003 Report Date: 4/23/2003 End: 5/4/2003 Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Rot Time Start: : Rec Time Start: 11 :45 Time End: : Time End: 16:50 RPM: Init Torque: (ft-Ibf) SPM: 100 Stroke Length: 12.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 140,000 (Ibs) Drag Down: 105,000 (Ibs) Type: Cement Casing Volume Excess %: 350.00 Meas. From: 210 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 295 (gpm) Mud Circ Press: 485 (psi) Start Mix Cmt: 14:56 Start Slurry Displ: 15:25 Start Displ: 16:44 End Pumping: 17:20 End Pump Date: 4/23/2003 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 7.00 (bbl/min) Y 483 (psi) 1,000 (psi) 5 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 210.00 (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Type: Spud Mud Density: 9.4 (ppg) Visc: 90 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PVIYP: 32 (cp)/26 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 8 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 222.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: 30.0 (bbl) Class: Yield: (ft3/sk) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 5/19/2003 10:42:33 AM ) ConocoPhillips Alaska Cementing Report Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Report #: Start: 1 4/20/2003 Stage No: 1 Slurry No: 2 of 4 ') Page 2 of 3 Spud Date: 4/21/2003 Report Date: 4/23/2003 End: 5/4/2003 Description: MUDPUSH XL Class: To: 3,275.00 (ft) Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Description: ARCTIC SET Class: G To: 1,739.00 (ft) Cmt Vol: 355.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Slurry Vol:465 (sk) Water Vol: 221.0 (bbl) Other Vol: () Purpose: PRIMARY Mix Water: 19.38 (gal) Foam Job: Y Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: D79 S001 D46 D65 D124 D53 D44 .. . ..... .. .......",... .. ...... .. ....... ...... ". . . ......... ........... .. . .... ... ... . . , . .. . ... . ..... ,", . ,"... .......... .. .................... .., . . ... ...... ........ ..... . .".... . ... .... .... . "' ...." ". .....:... ........: ...... ..... ... ......... .. ....". ...... .... ..... '". .......... ................ ..... . .. ..... .... .' . .... ... .. ... . .." ........ .... .......... "'" ....... ....... ... .... .. ............ ....... ...... ........ . ..... ....... ~tétge Nô:1§ILJtry~0:3C?f ~. ..!\~~i~ïves ···TYpe Concenti-åtion .. . Units· · 1.50 %BWOW 1.50 %BWOW 0.60 %BWOW 0.50 %BWOW 43.1 C %BWOW 30.0C %BWOW %BWOW Temp (OF) (OF) Pressure (psi) (psi) Stage No: 1· SlurryNo:40f4 GPS GPS GPS GPS GPS GPS Slurry Data Fluid Type: TAIL Description: ARCTIC SET Class: G Slurry Interval: 1,739.00 (ft}ro: 3,275.00 (ft) Cmt Vol: 130.0 (bbl) Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Source: Slurry Vol:326 (sk) Water Vol: 64.0 (bbl) Other Vol: () Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: TAIL Mix Water: 8.27 (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 5/19/2003 10:42:33 AM ') ) Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING Report #: Start: 1 4/20/2003 Spud Date: 4/21/2003 Report Date: 4/23/2003 End: 5/4/2003 D46 D65 D79 0.10 %BWOC 0.65 %BWOC 0.3C %BWOC GPS GPS GPS Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 18.30 (ppge) Tool: N Open Hole: 20 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N ····.L.··Q9!Sur"eye"ålûåt.lo. n.·.·.··.· ... .......... ... ..... ..... . ..... ....... ............ .............. ... .. ..... .. ........ .. .... . ". .' . . .. .......... .. ........ ..., . ..........................." .. ................ ..... ".. ... . . . . . . . ........ ". .." ..........". ..... ....... ..... ...... "." .... . ... '.' . ..... . ...... . .", . .. . . . . ,. . ... ... . '" . ... . · ·lnt~:rpl'etätlôri$uml11~ry: ...... . CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: Surface TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: ..·FJel'r1~~I<$ ..... Pumped 10 Bbls CW100, Tested lines to 3500 PSI, Pumped 20 Bbls CW1 00 and dropped bottom plug, pumped 50 Bbls Mudpush 10.5 PPG followed by 355 Bbls lead mixed at 10.7 PPG. cement to surface. Mixed and pumped 130 Bbls of tail 12 PPG dropped top plug and Dowell displaced with 20 Bbls wash water followed by 222 Bbls mud displaced with rig pump at 7 BPM. Plug bumped with 1000 PSI and floats held. Good returns and worked pipe throughout job 210 Bbls cement to surface. CIP 1720 Hrs. 4/23/03. Printed: 5/19/2003 10:42:33 AM NUMBER I EVENT CODE 124 HRS PROG I DFS ODR 2,566.0 3.00 I FIELD NAME I OCS NO. I DAILY TANG Kuparuk River 9,147.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD Pick up BHA. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Finish BOP, PU BHA & DP, Casing test, LOT, Drill. 4/23/2003 367,435 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE CLAYSTONE 10028702 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 4/22/2003 3,200.18 52.260 297.770 9.625 (in) @ 3,275.0 (ft) 7.000 (in) @ 9,147.0 (ft) ~~Nsïtv(PPQ)1 9.40 H~~II It:fpl .. .lrø4D:qp.r!\tp~ILYCP~T¡ 0 lçuM¢o~tl 0 'f~r·PVIYE»GEL$"VLI~JJip·fÇ(T;$()L ."·'()ILl\VA:r:,.%$éln~E:rrl)~~lplIII .... LPi/NIf·.:>9L.·' ··;:Cil<H2S . . .t..IME .,. ~$'." 90 32/26 418 8.01 2/ I 121.2 9.01 I ) 3S-17 SUPERVISOR I RIG NAME & NO. Dave Burley/Larry Hill N1268@ppco.co Nabors 7ES CURRENT STATUS ..···Ø~A~~~I.. .. ..1. . ..1.'..·· ,BHA Vir;BELQWJARS ) NO. 4 I CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 717,614 AUTH. LAST BOP PRES TEST . . :,~HAt""ÓL~,~Q~[)~,.lqNS' ....; ';' . '. STaINGW,.~ON· .. '..", STRIN~WT; Flør< '.,.... T()~qlJt:l.lJ~ITS.' .,". ft-Ibf ·1· ..I:IIT~Q;.. ., 1 ··;;:':BHÀLENGTH'. ... 904.95 CONNSIZECPNN'tvÞÊ :' ITEM DE$CRIPl1()N: .. ..... ..... ···NOJrS '., 1 1 1 1 1 Bit Mud Motor Float Sub Stabilizer Flex Collar - Non Mag MWD HCIM MWD DM MWD TM UBHO Stabilizer Crossover Flex Collar - Non Mag Drill Pipe - Heavy Wgt Hyd Jars Drill Pipe - Heavy Wgt 1 1 1 1 3 9 1 14 ,·····I,;i:NGTH'··'·'·· . 1.00 29.22 2.00 6.05 11.95 6.51 9.20 9.97 3.00 5.81 2.77 93.09 271.89 30.58 421.91 12.250 8.000 8.000 8.200 7.800 8.000 8.000 8.000 8.130 8.050 7.750 6.750 5.000 6.250 5.000 4.000 5.250 2.750 2.875 2.875 1.920 1.920 2.813 2.875 2.875 2.750 2.813 3.000 2.250 3.000 BITS SERIAL NO; JETSORTFA 5019302 15/15/15/10/1 BIT I RUN 1/ GPM 600 BIT OPERATIONS PRESS P BIT HRS WOB 25 I 40 RPM 85 I 100 24Hr DIST 1,719.0 .. DEPTH IN DA TEIN I-Ó-D-L~B~G-O-R · 109.0 4/20/20032-2-WT-A-E-1-EC-TD 24Hr ROP 141.27 CUM HRS CUM DEPTH CUM ROP 25.61 4,895.0 191.14 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 02:00 2.00 DRILL P PULD SURFAC Finished laying down BHA and bit. 02:00 02:30 0.50 DRILL P OTHR SURFAC Cleared drill floor. 02:30 04:00 1.50 CASE P RURD SURFAC Rigged up to run casing. 04:00 04:15 0.25 CASE P SFTY SURFAC Pre job safety meeting. 04:15 08:30 4.25 CASE P RUNC SURFAC Ran 51 Jts. 95/8" 40# L 80 BTC casing to 1951'. Ave Makeup 8800 Ft Ibs. Losing string weight. 08:30 09:00 0.50 CASE P CIRC SURFAC CBU to break gels in mud. 09:00 10:00 1.00 CASE P RUNC SURFAC Ran 21 Jts. 95/8" 40# L 80 BTC casing to 2753'. 10:00 10:15 0.25 CASE P CIRC SURFAC Washed down Jt # 73 ( took weight). Printed: 5/19/2003 10:45:08 AM ) ) FaqM ... TO 10: 15 11 :00 11 :00 11 :45 11 :45 14:30 · '. fiØURS 0.75 0.75 2.75 ""CODE CASE P CASE P CASE P 14:30 14:45 14:45 17:30 0.25 2.75 CEMENT P CEMENT P 17:30 19:30 2.00 CEMENT P 19:30 20:15 0.75 CASE P 20:15 20:45 0.50 CASE P 20:45 22:45 2.00 CASE P 22:45 23:45 1.00 WELCTL P 23:45 00:00 0.25 WELCTL P . .... .... ,·:······"Ô~¡ERATIØNS~µM~\f't¥..·..·i...····.·..·....1:...··..·...··.¡,:i'·!>·¡.··...¡, ft·Rql.rât.~;$.u~Pti~SE,., ....,.. ..... ........ . DESCRiPTION: . RUNC SURFAC Ran 12 Jts. 95/8" 40# L 80 BTC casing to 3275'. RURD SURFAC Rigged down Circulating tool and rigged up cement head. CIRC SURFAC Circulated and conditioned hole for cementing. 100 SPM @ 485 PSI. Worked pipe Up WT 140 K Dn Wt 105 K. SFTY SURFAC Pre job safety meeting while finishing circulating. PUMP SURFAC Pumped 10 Bbls CW100, Tested lines to 3500 PSI, Pumped 20 Bbls CW100 and dropped bottom plug, pumped 50 Bbls Mudpush 10.5 PPG followed by 355 Bbls lead mixed at 10.7 PPG. cement to surface. Mixed and pumped 130 Bbls of tail 12 PPG dropped top plug and Dowell displaced with 20 Bbls wash water followed by 222 Bbls mud displaced with rig pump at 7 BPM. Plug bumped with 1000 PSI and floats held. Good returns and worked pipe throughout job 210 Bbls cement to surface. CI P 1720 Hrs. 4/23/03. FC @ 3196' FS @ 3275'. SURFAC Flushed riser and flowline. Rigged down cementing and casing tools. SURFAC Nippled down and set back riser. SURFAC Installed FMC Gen V Speed head. SURFAC Nippled up BOP. SURFAC Pick up test plug and set. Fill stack with water and rig up test lines and recorder. BOPE SURFAC Test BOP top rams + choke valves 1,2, and 3 + TIW + HCR kill side. 250 and 5000 PSI. PULD NUND NUND NUND BOPE 24 HR SUMMARY: Ran and cemented 85 Jts. 9 5/8" casing, Rigged down Cement and casing tools. Nippled down riser, Nippled up FMC speed head and BOP. Started BOP test. Baroid PERSONNEl-DATA ··.··.NO~. HOÜRS' ··C:ÓMPANY 28 Halliburton / Sperry-Sun 2 Epoch 5 APC 2 2 . . MA1;ERIALS ICONSUMPTION ON HAND ITEM 13,410 Water, Potable 17,453 Fuel 656 446 RESERVOIR NAME 3s-16 COMMENTS 3S-17 RESERVOIR AND INTERVAL . DATA ZONE TOP BASE 1081 2.5 650 Printed: 5/19/2003 10:45:08 AM Well Name: 3S-17 I Rig: Drilling Supervisor: Dave Burley/Larry Hill Type of Test: I OpenholeTest LOT/FIT Hole Size: i 8-1/2" ... RKB-CHF: 26.9 Ft CasinQ Size and Description: CasinQ Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: BlockslTop Drive Weight: Estimates for Test: PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Nabors 7 ES I Date: 4/24/2003 Pump used: I #1 Mud Pump .1 Pumping down I annulus and DP. I Hole Depth 3,305 Ft-MD 2,572 Ft-TVD ...\ Casing Shoe Depth 3,275 Ft-MD 2,560 Ft-TVD : 9-5/8" 40#/Ft L-80 BTC Pressure InteQritvTest Mud Weight: 8;7.þpg Mud 10 min Gel: 7:ÜLb/100 Ft2 Rotating Weight: 93,000 Lbs BlockslTop Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1238 psi 9.1 ppg 12.0 Lb/100 Ft2 2,555 psi 88,000 Lbs 26,000 Lbs 2.2 bbls 1.1 bbls ...1 ...1 EMW = Leak-off Pressure + Mud Weight = 1275 0.052 x TVD 0.052 x 2560 + 8.7 EMW at 3275 Ft-MD (2560 Ft- TVD) = 18.3 ppg PIT 15 Second Shut-in Pressure, psi 1220 3000· - Lost 20 psi during test, held .:: 99.2% of test pressure. ~-.---- .,.......,...... 2500 -~- LU 0:: ::::> U) U) LU 0:: C- o 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Barrels ~CASING TEST __LEAK-OFF TEST Comments: Changed well over to 8.7 ppg LSND mud prior to FIT. I Volume Input Volume/Stroke Pump Rate: í Strokes .. 0.0700 Bbls/Strk ¡ .. 8.0 Strk/min ... Casing Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Strks psi Min psi Strks psi Min psi 0 0 0 2555 0 0 0 1270 2 123 1 2555 2 270 0.25 1220 4 270 2 2555- 4 370 0.5 1190 6 432 3 2545 6 470 1 1130. 8 615 4 2545 8 600 1.5 1110 "-' 10 729 5 2545 10 690 2 1090 12 840 6 2545 12 790 2.5 1050 14 953 7 2545 14 880 3 1030 16 1070 8 2545 16 975 3.5 1010 18 1204 9 2545 18 1075 4 1000 20 1325 10 2545 20 1170 4.5 1000 22 1463 15 2535 22 1275 5 995 24 1611 20 2535 5.5 990 26 1754 25 2535 6 980 28 1907 30 2535 6.5 960 30 2057 7 940 32 2219 7.5 910 34 2375 8 910 36 2555 8.5 905 9 900 9.5 890 10 890 --- ... Volume Volume Pumped Bled Back 2.5 tsbls _l::5blS Vo ume Bled Back I::5bls ') ) Casing Detail 7" Intermediate Cas in a ConocoPhillips Alaska Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 1111 X 711 Hanger (711 PU P 1 .23') Jts 5 to 219 215 Jts 711 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 402 Float Collar Jts 1 to 4 4 Jts 711 26# L -80 BTCM Csg 711 Weatherford Sure-Seal Model 303 Float Shoe 7" Shoe @ 89381 MD 60751 TVD TD of 8-1/211 hole @ 89491 MD 60831 TVD Total Centralizers 1- 7" Bow cent.! stop rings 31-5' above FS jt # 1 & 3'-5' below FC on jt #4 Bowspring centralizer over collar on joints #1, #2 , #3 and #5 thru #3 7" x 8-3/8" Centering guide on every jt. From #141 thru #145 (Total of 5) 7" x 8-3/8" Centering guide on every 3rd Jt. # 208, 211,214,217 (Total of 4) Totals: 31 Bowspring, 9 centering guides, 2 Stop collars Total of 235 jts.on location (Including extra shoe) Total of 219 jts. Ran in hole Total out: 15 jts. Inside shed ( 1 spare FS jnt outside) Remarks: Use IIRun-N-Sealll pipe dope Drifted to 6.15111 MU Torque 8,000 ft/lb Up Wt = 265K On Wt = 95K Block Wt= 30K Well: 3S-17A Date: 05/03/03 LENGTH 26.90 2.37 8753.74 1.30 152.05 1.45 DEPTH TOPS 26.90 29.27 8783.01 8784.31 8936.36 8937.81 Supervisor: David Burley/Peter Wilson Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING String Type: Production Casing Hole TVD: 6,083.0 (ft) Ground Level: 27.70 (ft) Circ Hours: 2.50 (hr) Manufacturer: Hanger Model: FMC A-75 Fluted Actual TMD Set: 8,937.81 (ft) Item Size Weight Grade (in.) (I bItt) Casing Hanger Casing Float Collar Casing Float Shoe Bowspring Centralizer Centering Guides Centering Guides 7.000 7.000 7.000 7.000 7.000 26.00 L-80 26.00 L-80 26.00 L-80 26.00 L-80 26.00 L-80 ConocoPhillips Alaska Casing Report Report #: Start: 2 4/20/2003 Page 1 of 2 Spud Date: 4/21/2003 Report Date: 5/3/2003 End: 5/4/2003 Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 8,949.0 (ft) (Ibs) 55.63 (0) 13.00 (days) .~ Accessory General Information Permanent Datum: Drill Floor Hole Size: 8.500 (in) KB-Datum: 29.56 (ft) Water TMD: (ft) CF Elevation: (ft) Liner Overlap: (ft) Mud Lost: (bbl) KB to Cutoff: 26.90 (ft) Casing Flange I Wellhead Model: Gen V Packoff Model: A-75 Integral Casing Detail Drift Threads JTS Length Top MU Torq. THO Manufacturer Model (in) (ft) (ft) (ft -I bf) 6.151 BTC-MOD 2.37 26.90 N FMC 6.151 BTC-MOD 215 8,753.74 29.27 N 6.150 BTC-MOD 1.30 8,783.01 Y Weatherford 402 6.151 BTC-MOD 4 152.05 8,784.31 y 6.151 BTC-MOD 1.45 8,936.36 Y Weatherford 303 8,937.81 Non-Integral Casing Accessories Manufacturer Number Spacing (ft) Top (ft) 7,759.0 3,069.0 151.0 WEATHERFORD WEATHERFORD WEATHERFORD 31 5 4 Top Hub/Flange: 11.000 (in) / 5,000 (psi) BTM Hub/Flange:11.000 (in) I 5,000 (psi) Condo Max 00 MinlO Comp. Name (in) (in) \JEW 7.000 6.276 Casing Hanger \JEW 7.000 6.276 7" 26# L-80 Cas \JEW 7.000 6.276 Float Collar \JEW 7.000 6.276 7" 26# L-80 Cas \JEW 7.000 6.276 Float Shoe c-' Interval How Fixed Remarks Bottom (ft) 8,930.0 OverCollar 3,235.0 Floating 519.0 Floating MU Float Shoe, 4 Jts 7" 26# L-80 BTC-Mod Csg, Float Shoe, Thread Locked Conn Below FC, Check Shoe Trac & Ck Ok, RIH with 7" Csg, Stopped & Circ Btms Up at 3,248',5,535' and 7,488', RIH with a Total of 219 Jts, 8,937.81' Including fit Equip, Made Up Hanger & Landed Csg with Fit Shoe at 8,938' and Fit Collar at 8,783' Printed: 5/19/2003 10:42:44 AM ConocoPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: 38-17 Common Well Name: 38-17 Event Name: ROT - DRILLING Report #: Start: 2 4/20/2003 Spud Date: 4/21/2003 Report Date: 5/3/2003 End: 5/4/2003 Remarks Est Circ Thru Fill Up Tool, Increased Rate up to 6 Bpm at 1,000 Psi, Began Reciprocating Pipe after Est Circ, after 30 Min Pipe Began to Get tight and Landed Csg in Hanger, Up Wt 265K, On Wt 95K When Landed, Circ Btms Up, Max Gas 70 Units -' LD Franks Fill Up Tool & MU Cement Head Cont to Circ Csg for Cementing, Held PJSM with Dowell, APC and Rig Crew, Batch Mixed Cement While Circ, Final Rate of 6 Bpm at 775 Psi, Circ 2.5 Btms Up with 11.3 ppg, 46 Vis and 19 YP Mud Out ---'" Printed: 5/19/2003 10:42:44 AM ) ) Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING Hole Size: 8.500 (in) TMD Set: 8,938 (ft) Date Set: 5/3/2003 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: 3 4/20/2003 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Spud Date: 4/21/2003 Report Date: 5/3/2003 End: 5/4/2003 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Cementer: Kevin Anderson Rot Time Start: : Rec Time Start:03:00 :.: :.:": ...:.....::" ::". ":""". ":, ... . ...... .... .............. .... . ....... ." ...... . . . . . .......... . . ............... ... ........ ...... ...... ......... .. .. .' . "." ...' .. .. . ....... ..,................. ........... ............. ...... .. .····..·.i~ip~iMþvèro~~~····i·..· , Time End: : Time End: 03:30 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 265 (Ibs) Max Torque: (ft-Ibf) Drag Down: 95 (Ibs) Type: Cement Casing Volume Excess %: 75.00 Meas. From: 0 Time Circ Prior To Cementing: 2.50 Mud Circ Rate: 252 (gpm) Mud Circ Press: 730 (psi) Start Mix Cmt: 05:20 Start Slurry Displ: 06:30 Start Displ: 06:50 End Pumping: 07:45 End Pump Date: 5/3/2003 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 11.3 (ppg) Visc: 46 (s/qt) Bottom Hole Circulating Temperature:115 (OF) Displacement Fluid Type:Seawater Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.50 (bbl/min) 7.00 (bbl/min) Y 1 ,730 (psi) 2,156 (psi) 3 (min) Y Returns: 97 Total Mud Lost: Cmt Vol to Surf: 35.00 (bbl) (bbl) . ." .,,' . .... '. .. . .._. .. .. . . . .. . ... ....... . . ..... MU(tData Ann Flow After: N Mixing Method: Batch Density Meas By: press scal PVIYP: 14 (cp)/19 (lb/100ft2) Gels 10 sec: 6 (lb/100ft2) Gels 10 min: 10 (lb/100ft2) Bottom Hole Static Temperature: 149 (OF) Density: 8.6 (ppg) Volume: 335.00 (bbl) Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 4,937.00 (ftJT"o: 6,117.00 (ft) Cmt Vol: (bbl) Water Source: Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.40 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 5/19/2003 10:40:58 AM ') ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Legal Well Name: 38-17 Common Well Name: 38-17 Event Name: ROT - DRILLING Report #: Start: 3 4/20/2003 8pud Date: 4/21/2003 Report Date: 5/3/2003 End: 5/4/2003 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 6,117.00 (ft}To: 7,593.00 (ft) Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Description: GasBlock Slurry Interval: 7,593.00 (ft)To: 8,938.00 (ft) Cmt Vol: 62.0 (bbl) Water Source: Lake Slurry Vol:300 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 36.9 (bbl) Other Vol: () Purpose: PRIMARY Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: 3.38 Free Water: (%) Fluid Loss: 14.0 (cc) Fluid Loss Pressure: 115 (OF) Temperature: 115 (OF) Temperature: (OF) Temperature: 115 (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Type Concentration . ... ........... ..... ...... ... .. ... .... .. .". ....... .... .... ...... "... . . '". '. ..... . ..... ." ... .... .,..... . . ... .. . . . . . ". '. ........ . . : '. . . '. . .. .. ...... ·..~t~g~N():1$I~rryfi():3()f ~HActditiye!;. Units B155 065 047 0600 0.03 %BWOC 0.30 %BWOC 0.20G P S 2.00 G P S Printed: 5/19/2003 10:40:58 AM '.) ) ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 3S-17 Common Well Name: 3S-17 Event Name: ROT - DRILLING Report #: Start: 3 4/20/2003 Spud Date: 4/21/2003 Report Date: 5/3/2003 End: 5/4/2003 Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N ... . ...... .... .... .. "." "." .. ".' '. .. ......' ..... ..... .......... ...... ..... .... .......... . ."' .: ......... ... '.".. . . . ....... . .................... . ".. ........ ........ ... . . .... ... ...... . .. ... ..... .... ..... ....... ...." '. ." "' ........ . ...... .'.." .".. . .. ".' . ........ ......"". . . .. ... ...... ....... . .... ........ ........ . .... ... . . .. ....... .. ... "' . ... .. '.' : ':}.r¡·. ...·!~~$1$9r,,~Y~,,~'I.I~ti#~: ..,.. .... . CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Turned Over to Dowell, Dowell Batch mixed 40 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 12.5 ppg, 300 sxs (62 bbls) @ 15.8 ppg Class "G" at 1.16 with Additives, Pump 1 0 bbls CW1 00, Test lines to 3,500 psi, Pump 30 bbls CW1 00, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at ave. rate of 4.8 Bpm at 650 psi, Drop #2 btm plug, Pump 62 bbls cmt at ave rate of 4.6 bpm at 425 psi, Shut down Flush lines to rig floor with seawater, Drop top plug, Dowell Displace cement, after 300 bbls of 8.5 ppg seawater pumped at an ave rate of 7 bpm at 1,000 psi and 23.5 bbls cmt out of shoe, lost returns, slowed rate to 4 bpm at 1,975 psi then to 3.0 bpm at 1,725 psi & bumped plug wI total of 336.5 bbls, Bumped plug wI 2,150 psi, Checked Floats & Held, Bled back 2 bbls for a total of 334.5 total bbls displaced (Calculated 336.5 bbls), CIP @ 07:45 hrs 5/3/03, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. Printed: 5/19/2003 10:40:58 AM ) ) Page 1 of 2 ConocoPhillips Alaska Daily Drilling Report WELL NAME 3S-17 JOBNUMBER EVEONTDCRoDE 24HRSPROG TMD TVD DFS 8,949.0 6,083.0 13.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Dave Burley/Peter Wilso N1268@ppco.co Nabors 7ES Kuparuk River 9,147.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD NUTree 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Test Tree, Freeze Protect well, LD DP, RD & Move to 3S-06 4/28/2003 500,355 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 18.24 10028702 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 5/1/2003 8,949.00 46.800 235.380 7.000 (in) @ 8,938.0 (ft) (in) @ (ft) 4/29/2003 Q~~$lrY(pþg) 8.50,!:PP .... ... IECDI IMUD DATAl DAILY COST I 0 .. JC~~Å9~t:l.... 0 ....~,,/ ¡pviYP ;GEL$WLlftJ11p·Fcrr.~ØL. "'()'I+IW,~T:' :. ,%!)~!1~~T¡ .. ,.... .,. fl1lp.M>,'·" ;·FfflMf,,,·;>:cr'· '; '... :çé!> . ,,·J::t2$ ... i~IMI;: .: E~¡ 28 I / / / / / I I REPT NO. I DATE 14 5/3/2003 ¡CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 2,348,843 AUTH. FROMTC) 00:00 00:45 00:45 03:00 HoURsi 0.75 2.25 <¢OOIS " CASE P CASE P .....;' ... ;;()P~~Ä1;ïO~~SUM~ARY ..: TROUBLE: : sUB:' ,. : PHASE · CIRC PROD RUNC PROD 06:45 08:00 1.25 CEMENT P DISP Circ Btms Up at 7,488', Circ at 5 Bpm at 540 Psi, 205K Up Wt, 90K On Fin RIH with 7" Csg, MU Landing Jt & Landed Csg, Ran a Total of 219 Jts of 9 5/8" 7" 26# BTC-Mod Csg, 8,937. 81', Landed Fit Shoe at 8,938' with Fit Collar at 8,783' PROD Est Circ Thru Fill Up Tool, Increased Rate up to 6 Bpm at 1,000 Psi, Began Reciprocating Pipe after Est Circ, after 30 Min Pipe Began to Get tight and Landed Csg in Hanger, Up Wt 265K, On Wt 95K When Landed, Circ Btms Up, Max Gas 70 Units PROD LD Franks Fill Up Tool & MU Cement Head & Lines PROD Cont to Circ Csg for Cementing, Held PJSM with Dowell, APC and Rig Crew, Batch Mixed Cement While Circ, Final Rate of 6 Bpm at 775 Psi, Circ 2.5 Btms Up with 11.3 ppg, 46 Vis and 19 YP Mud Out PROD Turned Over to Dowell, Dowell Batch mixed 40 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 12.5 ppg, 300 sxs (62 bbls) @ 15.8 ppg Class "G" at 1.16 with Additives, Pump 10 bbls CW100, Test lines to 3,500 psi, Pump 30 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at ave. rate of 4.8 Bpm at 650 psi, Drop #2 btm plug, Pump 62 bbls cmt at ave rate of 4.6 bpm at 425 psi, Shut down PROD Flush lines to rig floor with seawater, Drop top plug, Dowell Displace cement, after 300 bbls of 8.5 ppg seawater pumped at an ave rate of 7 bpm at 1,000 psi and 23.5 bbls cmt out of shoe, lost returns, slowed rate to 4 bpm at 1,975 psi then to 3.0 bpm at 1,725 psi & bumped plug wI total of 336.5 bbls, Bumped plug wI 2,150 psi, Checked Floats & Held, Bled back 2 bbls for a total of 334.5 total bbls displaced (Calculated 336.5 bbls), CIP @ 07:45 hrs 5/3/03, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. PROD RD Dowell, Cmt Head & Blow Down Lines PROD LD Landing Jt & RD Csg Elevators, Changed out elevator bails, Flushed Out Stack & Riser PROD Installed 7" Csg Pack-Off and Tested Same to 5,000 Psi for 15 Min CMPL TN Held PJSM on RU & Running 3 1/2" Completion CMPL TN RU Nabors 3 1/2" Tbg Tongs & Handling Tools CMPL TN MU 3 1/2" completion equipment: WLEG wi shear out sub I pup - Camco "d" nipple wi 2.75" no go - 2 pups - xo 3.5" x 4.5" - Mill out ext - Baker SAB-3 packer - KBH-22 Tubing anchor - Baker 80-40 PBR - Locator sub - pup - 1 jt 3 03:00 04: 15 1.25 CASE P CIRC 04:15 04:45 0.50 CASE P RURD 04:45 06:00 1.25 CASE P CIRC 06:00 06:45 0.75 CEMENT P PUMP 08:00 08:30 0.50 CEMENT P RURD 08:30 09:30 1.00 CASE P RURD 09:30 10:30 1.00 WELCTL P OTHR 10:30 10:45 0.25 CMPL TN P SFTY 10:45 11 :15 0.50 CMPL TN P RURD 11 :15 12:00 0.75 CMPL TN P PULD Printed: 5/19/2003 10:44:36 AM ) ) .·HOORS 11:15 12:00 0.75 ., "., ,·':··.·.··.··.··.';,'.,'···'..Ø~~FïÄ'T'IQNSSl.JMMARy·· ..>,?.........,....;'.:!:'.'..... ....>..,',.. . .. ·CODE··, TAOOBLf$> St,JI:1 :PHAse>:' .. >OESCFtII?'I10N ' CMPL TN P PULD CMPL TN 1/2",9.3#, L-80 tbg - Cameo "DS" nipple wI 2.813 profile - 1 jt tubing - pup- Cameo MMG wI DCR shear valve - pup - CMPL TN RIH WI Completion Assembly PU 3 1/2" 9.3# L-80 EUE-Mod Tbg ( 267 Jts total 8,343.65'). PU jt #284 with 8' Pup Jt to put packer on depth. CMPL TN RU & Tested 7" Csg to 3,500 Psi for 30 Min, Good Test CMPL TN Dropped 2" Packer Setting Ball, Performed LOT on 7" x 9 5/8" Ann While Ball Dropped, LOT to 15.6 ppg EMW with 570 psi CMPL TN Set Baker Packer Per Setting Procedure with No Problems, Set 31/2" x 7" Pkr at 8,311', PBR at 8,296' with WLEG at 8,343' 12:00 21:00 9.00 CMPL TN P RUNT 21:00 22:00 1.00 CMPL TN P DEQT 22:00 23:00 1.00 CMPL TN P OTHR 23:00 00:00 1.00 CMPL TN P RUNT 24 HR SUMMARY: Fin Running 7" Csg to 8,938', Circ & Cond Mud, Cemented Csg, RU & Ran 31/2" Completion, Tested 7" Csg to 3,500 Psi, Set Pkr at 8,311' with WLEG at 8,343' .COMPANY· . Nabors Phillips DUS Baroid PEFlS()~N,~IJ·[)~,.~···.' ..... Ii pt,J R$ . ... .COMI?ANY 29 Halliburton I Sperry-Sun 2 APC 5 Baker 2 FMC Ht>VRS.. 5 2 1 1 ITEM····· Fuel Rig Water, Drilling ···UNITS ., gals bbls ': ..MATERIAL~J:CONSOMPT,~ON·· . '.··USAGE . ON HAND...··' . ITEM > 899 12,898 Fuel Camp 857 217 Water, Potable ^,Ã' . UNITS. ,',. gals gals ON HAND ' 1,650 10,620 4,680 'RESERvoiR NAMe 3s-16 . RESERVOIFlAND INtEFlVAL [)ATA ZONET()P> BASE. 1649 2.5 700 psi 3S-17 Printed: 5/19/2003 10:44:36 AM PRESSURE INTEGRITY TEST PHilLIPS Alaska, Inc. Nabors 7es Date: 5/4/2003 pump used: I Other- See Comments [ ... ...1 Pumping down I annulus. ¡ ... I Hole Depth 7,725 Ft-MD 5,273 Ft-TVD ...1 Well Name: 3S-17 I Rig: Drilling Supervisor: Burley I Wilson Type of Test: I Annulus Leak Off Test for Disposal Adequacy Hole Size: ,8-1/2" · Casing Shoe Depth RKB-CHF: 26.9 Ft 3,275 Ft-MD 2,560 Ft-TVD Casina Size and Description: 9-5/8" 40#/Ft L-80 BTC Chanaes for Annular AdeQuacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Pressure IntegritvTest Mud Weight: 11.3· ppg Inner casing OD: 7.0 In. Desired PIT EMW: Estimates for Test: 15.8 ppg 599 psi 0.4 bbls ·L EMW = Leak-off Pressure + Mud Weight = 570 + 11 3 0.052 x TVD 0.052 x 2560 . EMW at 3275 Ft-MD (2560 Ft-TVD) = 15.6 PIT 15 Second Shut-in Pressure, psi 520 1000 -~- UJ c::: => U) U) UJ c::: a.. 8 0 5 10 15 20 2S 30 Shut-In time, Minutes o PIT Point 3 4 Barrels ~CASING TEST -+-LEAK-OFF TEST Comments: Initial shoe test = 18.3 ppg I::MW Used Injection pump for test. I Volume, Input Volume/Stroke Pump Rate: I Strokes 1..- 0.0187 Bbls/Strk I ..- 19.0 Strk/min ... I I Casing Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Strks psi Min psi Strks psi Min psi 0 0 0 550 20 60 0.25 520 40 130 0.5 500 60 210 1 480 80 300 1.5 460 C'--_. 100 380 2 440 120 470 2.5 425 140 540 3 420 160 570 3.5 420 180 580 4 410 200 580 4.5 410 220 570 5 410 240 570 5.5 400 260 580 6 400 280 580 6.5 400 300 580 7 400 320 590 7.5 400 340 580 8 400 360 580 8.5 400 9 400 9.5 400 10 400 '-' ¡. Volume Bled Back _l:Sbls Volume Bled Back _I::sbls 3~·1? -1320 -1238 -1031 -n~ --1;19 -413 --206 -0 -206 -413 -6J9 -H2~ -1O.~1 -1238 -1320 3:!~.I.n "\(,<)_\~:,.H!t. WEli. DlT>JL' :"crUUfor E..Hl:-.,.. A'<ìI-COlllSIO)O; SETfJ:'GS COMPA..!."'.;:YDETAll...S \VElLPA1H DETA1LS L.......:¡pud.! Phillips ÞJaska Ir~. ~.ir:u..ring Knpo.-roc 35-17 "- 501 0321}44~Wl Interp¡lation ),{ethod: ),10 futervaJ: 1.000 Depth R:lllge From: 327H)(0 To: 3280.000 Maximum Range: 10000.000 Reference: Definitive Pam .7(.U0.úl 70·H·:'~).QO}.X 1~0Î 1'39.l6SVo' S'f.~ N7E-S 3$-17: 56A60ft 114 NlilëRadius......o! 3S-17A.u9·518".Csg<Pt (@3275i'MDI2560'..·TVl)) Pgf.,nl Wëllru1.h: TIt. ;)i!. \ID: 3S-17 612133Ù ûJ..;:¡,¡l~tiiH); Me.lb-........,j; Miri..!:liu..m. Om7!1rri'. En~:r S'V'SI.':'.I!l: ISCWSA ·5{--lJ1 ~etl"~::-=:i: Trr.' C)1in&r 'XC\1th ErrN S!:i1f;;.;:.e: ElljptiC-21 -+ C~nh WZTiÎ!!gMe.l~..j: Rcle.s.B~ëd Oricin Origin +:s:l-s +EI-'1.~ Ref.D~~ ~":~i\D VSectiOD Anglo DZO From Colour o 200 300 400 600 gOO WOO 1500 :WOO 3000 270 90 180 b2(j Travelling Cylinder Azimuth (TFOt-AZr) [deg] vs Centre to Centre Separation [ft] ToMD 200 300 400 600 800 1000 1500 2000 3000 4000 ~c -,I -- ,~/ I.lro-r' r.~. Lr\~ ll1 [JJ~.. ,..,~......:.1 'l \ 'IF U! ¡ ) m<L fE (cL 'F IJ0 / LID, ~~ J\\A\ I / / J ) FRANK H. MURKOW5KI, GOVERNOR AItASKA OILAlWD GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 333 w. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field 3S-17 A ConocoPhillips Alaska, Inc. Permit No: 203-080 Surface Location: 2533' FNL, 1130' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 1131' FNL, 1693' FEL, Sec. 13, T 12N, R 7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you trom obtaining additional permits or approvals required by law trom 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, æ~L; /~l-v¿~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thiq day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encJ. Department of Environmental Conservation w/o encJ. Exploration, Production and Refineries Section ) ~. 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 April 28, 2003 Alaska Oil and Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Sidetrack well, 3S-17 A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby files this Application for Permit to Drill sidetrack well 3S-17 A. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, ~\~ Randy Thomas GKA Drilling Team Leader RECEIVED APR 2 9 2003 A'aska Oi\ & Gas Cons. Commission Anchorage OR\G\NAL 1a. Type of Work: Drill 0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ~b~ PERMIT TO DRILL 20 AAC 25.005 Redrill U 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surlace:2533'FNL, 1130'FEL,Sec. 18,T12N,R8E,UM Top of Productive Horizon: 974' FNL, 1510' FEL, Sec. 13, T12N, R7E, UM Total Depth: 1131' FNL, 1693' FEL, Sec. 13, T12N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surlace:x- 476130 16. Deviated wells: Kickoff depth: 6500 18. Casing Program Size Hole Casing 8.5" 7" 19 Total Depth MD (ft): 8910' Casing Structural Conductor Surlace Intermediate Production Liner Perforation Depth MD (ft): y- 5993883 Zone- ft. Maximum Hole Angle: 53.6° Weight Specifications Grade Coupling Length 26# L-80 BTC-M 9060' PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) 5978' 8906' - 8561',6777'- 6200' Size Length 80' 3247' ExploratoryU Development Oil U Multiple Zone D Service 0 Development Gas D Single Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 3S-17A 6. Proposed Depth: 12. Field/Pool(s): MD: 9088' TVD: 6079' Kuparuk River Field 7. Property Designation: ALK 25544 8. Land Use Permit: Kuparuk River Pool 13. Approximate Spud Date: 4/29/2003 ADL 2639 9. Acres in Property: 2560 14. Distance to Nearest Property: 974' at target 15. Distance to Nearest 10. KB Elevation 4 Well within Pool: none, (Height above GL): RKB 28' / 56' AMSL 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3187 psig Setting Depth I Max. Surlace Pressure: 2537 psig Quantity of Cement c. f. or sacks (including stage data) Top Bottom MD TVD MD TVD 28' 28' 9088' 6079' 290 sx Class G (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 5975'-5744',4650'- 4308' Cement Volume MD TVD 16" 82 sx ArcticCrete 465 sx AS Lite, 326 sx AS 108' 2560' 9.625" None 20. Attachments: Filing Fee 0 Property Plat D BOP Sketch 0 Diverter Sketch D Drilling Program0 Seabed Report D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature R. Thomas 108' 3275' Perforation Depth TVD (ft): None Time v. Depth Plot D Drilling Fluid Program 0 Date: Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 Contact Scott Lowry @ 265-6869 Title Kuparuk Drilling Team Leader Phone Date '-t /2 c'7/0 '5 PreDared bv SharQn Al/sUD-Drake \~\~ ::::~ D~ 03 _ 0 g 0 AP~:U~: ~ _ -< 0 ~:O;~i:i:n Use :::;, Vh 9 Þ ~ ~~:~:;;e~:~:men's Conditions of approval: Samples required DYes J2SI No Mud log Z.~d ~"'" S \,N'E 0 Hydrogen sulfide measures D Yes ~ No Directional survey required ~g No l\RR 2 ~ 2003 \J\\\i CQ.""'~f'...\\.\)~'\'\l \~, .' . G Con~Comr""~s'on BY ORDER OF A\aska 0\\ & as . ~ ' .' /~ COMMISSIONER THE COMMISSION Date: Anchorage"\ a? P __ O ,J f G ' ,~r ,,1 , ,1/ ~i ~ :f ,; ,I ".S Other: ~Sb(J ~~' I. ~ '\ ~ \ ~ '-J \1"-. ~a"V> \-~ \.. Approved by: \~~~ 'tv-e,lv';Á- Form 10-401 Revised 3/2003 · Submit in duplicate ) . I' ,cation for Permit to Drill, Well 3S-17 A l Revision No.O Saved: 28-Apr-03 Permit It - Kuparuk Well 35-17 A Application for Permit to Drill Document Moxir'r'1iZE We-II VçIlUE¡ Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................2 2. Location Summary....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................ 2 Requirements of 20 AAC 25.050(b) .................................................................................................... 2 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) ............................................................................... ................. 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ...............................................................................................3 5. Procedure for Conducting Formation Integrity Tests .............................................3 Requirements of 20 AAC 25.005 (c)(5) ...............................................................................................3 6. Casing and Cementi ng Program .......... ............ ......... ..... ......... .......... .... .......... ...........4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................ 4 7. Diverter System Information ..... .......... ...... ...... ..... ............ ..... ..... ...... ........ ............. .....4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................ 4 8. Dri II i ng Flu id Prog ram................................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................ 4 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (c)(9) ............................................................................................... 5 10. Seism ic Analys is.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ............................................................................................. 5 11. Seabed Condition Analysis...... ....... ..... ...................... ........... ........... ........ .......... ........5 Requirements of 20 AAC 25.005 (c)(11) .............................................................................................5 12. Evidence of Bon ding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) .............................................................................................5 13. Proposed Dri lling progra m ............. ............................ ................ ................................ 5 C 1 ' ." I ~, ~ 11 ¡ l¡ ¡ j ~¡ i1_ 3S-17A PERMIT IT.DOC Page 1 of 6 Printed: 28-Apr-03 ) t'~cation for Permit to Drill, Well 3S-17A ) Revision No.O Saved: 28-Apr-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. Attach ments.................................................................................................................. 6 Attachment 1 Directional Plan............................................................................................................ 6 Attachment 2 Drilling Hazards...... . . . .,. ... ...... .. . . .. .. . ..... . ... . . . ... ... ... . . . .,. . . . .. . . . . ... . . . . . . ., . ..... . . . . . . .. . .6 Attachment 3 Well Schematic......... ...... .. . . . . ...... .. . .... .. ... .... . . ... ... . .. .. . ... . . . ... ... . .... . ... ..... . .. .. . . .. ..6 1. Well Name Requirements of 20 AA C 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly 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-17A. 2. Location Summary Requirements of 20 AAC 25. 005(c) (2) An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the property's owners and showing (A}the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, 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) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,993,883 12533' FNL, 1130' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,130 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,995,460 974' FNL, 1510' FEL, Sec 13, T12N, R7E, UM Eastings: 470,950 Measured Depth RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8788' 5901' 5845' Location at Total Depth 11131' FNL, 1693' FEL, NGS Coordinates Northings: 5,995,304 Eastings: 470,766 Sec 13, T12N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth 55: 9088' 6079' 6023' and (D) 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 (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wel/bores wIthin 200 feet of any portion of the proposed we/f,' Please see Attachment 1: Directional Plan ØI '1 !,/~ J ~ .,~,f' L II ~ i I \:J i i ~: i'L 3S-17A PERMIT IT. DOC Page 2 of 6 Printed: 28-Apr-03 ) f '\lcation for Permit to Drill, Well 3S-17A ) Revision No.O Saved: 28-Apr-03 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells/ to the extent that those names are known or discoverable in public records/ and show that each named operator has been furnished a copy of the application by certified mail,' 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 Permit to Drill must be accompanied by each of the following items/ except for an item already on file with the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 AAC 25.03~ or 20 MC 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 Dnll must be accompanied by each of the following items/ except for an item already on file with the commission and identified in the application: (4) information on drilling hazards/ including (A) the maximum downhole pressure that may be encounterec£ criteria used to determine it and maximum potential surface pressure based on a methane gradient/ A pressure build-up test performed on Palm 1A (3S-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-17A sidetrack is predicted at 3200 psi at 5901' tvd, 0.54 psi/ft or lOA ppg EMW. The maximum potential surface pressure (MPSP) while drilling 3S-17A sidetrack is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5901' tvd: MPSP =(5901 ft)*(0.54 - 0.11 psi/ft) = 2537 psi (B) data on potential gas zones/ The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata/ lost circulation 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 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: (5) a description of the procedure for conducting formation integrity tests/ as required under 20 MC 25. 030(f}/ A procedure is on file with the commission for performing LOT's. For 3S-17 A, the 9 5/8" surface casing shoe has been tested to 18.3 ppg EMW on 4/24/03. C ,~:r.,P~ " , l~' i i ~: , 't3II 3S-17A PERMIT IT. DOC Page 3 of 6 Printed: 28-Apr-03 ) I' "~cation for Permit to Drill, We1l3S-17A } Revision No.O Saved: 28-Apr-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 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed.: Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Ibltt) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 3247' 28'/28' 3275'/2560' Cemented to surface as per APD 203-015 7 8-1/2 26 L-80 BTC-Mod 9060' 28'/28' 9088'/6079' 290 sx 15.8 ppg 'G' w/ add. Planned TOC= 7738' 3-1/2 9.3 L-80 EUE 8rd 8410' 28' / 28' 8438'/5693' SAB- 3 packer set at Mod 8438' 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 3 112" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file wIth the commission and identified in the application: (l) a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2).: Please reference diverter schematic on file for Nabors 7ES. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling flU/ä program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033.: Drilling will be done using mud systems having the following properties: 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 11.3 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 0-1 5 1 5-19 JO.· ~..~~.,~ ,¡¡. L 1_ ,,,' t '! r~ . ~i I .. : ¡ .. Ii j ~i ~ ,~ 'J l"'~ ... 3S-17A PERMIT IT. DOC Page 4 of 6 Printed: 28-Apr-03 ') t "{cation for Permit to Drill, Well 3S-17A ,1 Revision No.O Saved: 28-Apr-03 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a 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: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); NI A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and Identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a 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: (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 the following Items, except for an item already 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 6500' 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 wi SAB-3 permanent packer and PBR. Set packer 100' above top planned perforation, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 1/2" 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. OR' if'\~~, .' \,r~, L C!r ~.~ ~J 1 ~ . ,~ :,( ,." ~ ¡ j \~! f-'! 3S-17A PERMIT IT. DOC Page 5 of 6 Printed: 28-Apr-03 ) P~'\cation for Permit to Drill, Well 3S-17A " Revision No.O Saved: 28-Apr-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/ except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation 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-17A for annular pumping of fluids occurring as a result of future drilling operations on 3S pad. 15. Attach ments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. J R '~I ~ ", '1 , , if ' 'I' . I ;.~ . . ~ \;vJ ~ ~·,;t".'1 .~ 3S-17A PERMIT IT.DOC Page 6 of 6 Printed: 28-Apr-03 >L ConocoPhillips Ala Western Nor· Kuparu 3· Sperry-Sun Drilling Services ...~ In ska -Pad) .- a :J:) ~-'-"'~'Ji'S Proposal Report !::~ c) )~~~~ ~.--- 28 October, 2003 Your Ref: Revised Fallback Target... tied into surveys Surface Coordinates: 5993883.01 N, 476130.06 E (70023' 39.903011 N, 150011' 39.167011 W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ·-..........7 Kelly Bushing: 55.80ft above Mean Sea Level spE!l'r'Y-EiUI! DRILLING SERVICES A Halliburton Company Proposal Ref: pro2023 C :!::- ""'""" ~~- -j ::::J (f) ~ Co u) .- LO II ~.~ CO ~ fS .c ã. <1> o (ij <..> 5500- :e <1> > ð ß 1\ 6000- J:: U C ~ ¡¡; ~ C/J 4500 - 5000 - C~Ph· _11*' Canaco I IPS ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) 3S-17A (wp04) Scale: 1 inch = 50011 -1500 I o -1000 I -500 I '!I>"""t. ""' <þoo to ~ Begin .'i:?,r:j{;}-r::J'<':. ;-,-Q ¡. re· .([1f,lo'fiOO. ff '< fÇ ,0; I -1500 o I 1000 Scale: 1 inch = 50011 DrillQuesl 3.03.02.002 500 I I 500 (j) 0> c :E t o Z -5500 I 2250 - - 2250 (j) 0) c :.ë: t 0 Z - 1750 0 0 l{) -~ 1\ .c u c ¡¡; - 1250 TI (j) I -3500 ScaJe: 1inch = 500ft -5000 I Eastings -4500 I -4000 I -3500 I 3S·17F (Revised) 5900.80 nV,1560.4./ N. 5185.07 W \ I \ \ 1750 - 1250 - I -5500 5993883.01 N, 476130.06 E 38.97 N, 325.07 W 70° 23' 39.9030" N, 150° 11' 39.1670" W 2533' FNL & 1130' FEL, SEC. 18- T12N - R8E 55.80ft above Mean Sea Level True North Feet (US) TARGET: 8787,6ít MD, 5900.8ft TVD (974' FNL & 1510' FEL, Sec 13- T12N·R7E) Total Depth: 9087.60ft MD, 6079.01 It TVD (1131' FNL & 1693' FEL, SEC. 13- T12N-R7E) I -5000 I -4500 I -4000 I Dir @ 5.000/100ft : 6500'jft MD, 4483.31 ft TVD \.~~ i >I'D 1"""""' I . ~v ,- ~ End Dir, Start Sail @ 53.55°: 7615.41ft MD, 5204.47ft TVD . . _ ~~'Q"1<j>0,,", l_ _ u"~' I &.7 '>-1 (~Q oßf", _~__ _____ _ _ '9- ~~-l;''- r - - -- 3S-17F (Revised) ,,0-" 5900.80 T't'V, 1560.-14 N. 5185.117 W -- _: -r"s:--: :- '~~-- - ,-.--- - ., " {~~ TO:::~:~~. ~~~::'~~~~:;::~T~~~v~ (1131' FNL & 1693' FEL, SEC. 13-T12N-R7E) I I -1000 -500 1000 I - 4500 J~f "* Reference is True North Well: Current Well Properties 3S·17 - 5000 Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation : North Reference: Units: -5500 spe"-'Y-SUI1 DRII-LING SERViceS A Halliburton Company -6000 ~' Ian ConocoPhillips Alaska, Inc. 3S-17A (wp04) .~ MD Inc Azim. SSTVD TVD N/S E/W Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) a 6500.00 53.47 300.69 4427.51 4483.31 2240.23· N 3677.50 W 5996134.97N 472459;73 E 0.00 -847.35 ST off of Cmt Plug.@ .5°/100' in 8-1/2" Hole 7534.92 52.07 234.23 5100.00 5155.80 2211.92 N 4417.21 W 5996109.02 N 471719.94 E 5.00 -567.75 Top Moraine ::r:j 7615.41 53.56 229.54 5148.67 5204.4 7 2172.34 N 4467.62 W 5996069.61 N 471669.40 E 5.00 -513.32 End Dir; Start Sail ~_r ~, 7860.06 53.56 229.54 5294.00 5349.80 2044.63 N 4617.36 W 5995942.38 N 471519.26 E 0.00 -342.10 Base Moraine f.~ .~~) 8156.33 53.56 229.54 5470.00 5525.80 1889.97 N 4798.70 W 5995788.30 N 471337.43 E 0.00 -134.74 Top HRZ 8442.51 53.56 229.54 5640.00 5695.80 1740.59 N 4973.85 W 5995639.47 N 471161.79 E 0.00 65.54 Base HRZ 8627.68 53.56 229.54 5750.00 5805.80 1643.92 N 5087.19 W 5995543.17 N 471048.15 E 0.00 195.14 K-1 -~ 8745.52 53.56 229.54 5820.00 5875.80 1582.41 N 5159.31 W 5995481.89 N 470975.83 E 0.00 277.61 Kuparuk ~-""",,",-----.:¡:~ 8779.18 53.56 229.54 5840.00 5895.80 1564.84 N 5179.92 W 5995464.38 N 470955.17 E 0.00 301.17 Base Kuparuk :! 8787.60 53.56 229.54 5845.00 5900.80 1560.44 N 5185.07 W 5995460.00 N 470950.00 E 0.00 307.06 TARGET 9087.60 53.56 229.54 6023.21 6079.01 1403.84 N 5368.69 W 5995303.98 N 470765.88 E 0.00 517.02 Total Depth -- Western North Slope Measured Depth (ft) Incl. Azim. 6500.00 53.467 300.686 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 ~a :1t:J 7500.00 7534.92 7600.00 7615.41 ..:i""-,;,,~._ ~ <~- -) 7700.00 __"J 7800.00 7860.06 7900.0Q,;·· 8000.00"',:" 8100.00' ->-- 8156.335 ' 8200.00" 8300.00 8400.00 8442.51 8500.00 8600.00 8627.68 8700.00 8745.52 51.658 50.157 48.994 48.194 47.778 47.757 48.130 48.889 50.014 51 .480 52.067 53.256 53.556 53.556 53.556 53.5~6,c 53.5~6c ·'·þ~.556~. ~~.q56,:- 53.556 53.556 53.556 53.556 53.556 53.556 53.556 53.556 53.556 53.556 28 October, 2003 - 16:31 294.813 288.666 282.277 275.695 268.987 262.232 255.515 248.915 242.502 236.327 234.234 230.424 229.540 229.540 Sub-Sea Depth (ft) 4427.51 4488.33 4551 .43 4616.31 4682.49 4749.46 4816.72 4883.75 4950.04 5015.08 Vertical Depth (ft) 4483.31 4544.13 4607.23 4672.11 4738.29 4805.26 4872.52 4939.55 5005.84 5070.88 ~~:;~~~~0-~ Sperry-Sun Drilling Services Proposal Report for 35-17 Plan - 35-17 A (wp04) Your Ref: Revised Fallback Target... tied into surveys Revised: 28 April, 2003 Local Coordinates Northings Eastings (ft) (ft) 2240.23 N 2277.21 N 2305.98 N 2326.30 N 2338.03 N 5078.39 5134;19' '<_"":~~_? ' N 5100.00 <:5155.ª0::2211.92 N ~~¡~~~~~ ~J'h~!~¡i~ ~~~~:;~ ~ ,.~ - .~ '.. '--.. .-~' ;.-.:- :-.:,:. ....----,.--.' . -. -' _.--- ,$i 98~~2--i2JtWf5254. 72 229;5;40'" 5258.32 ;~~9.~~Q ,/. 5294.00 ~EJ.q4(); 5317.73 229.54Q:' 5377.13 "229.546'·' 5436.54 '229.540 229.540 229.540 229.540 229.540 229.540 229.540 229.540 229.540 229.540 5470.00 5495.94 5555.34 5614.75 5640.00 5674.15 5733.56 5750.00 5792.96 5820.00 ,. 5314.12 5349.80 5373.53 5432.93 5492.34 5525.80 5551.74 5611.14 5670.55 5695.80 5729.95 5789.36 5805.80 5848.76 5875.80 2128.18 N 2075.98 N 2044.63 N 2023.78 N 1971.58 N 1919.38 N 1889.97 N 1867.18 N 1814.98N 1762.77 N 1740.58 N 1710.57 N 1658.37 N 1643.92 N 1606.17N 1582.41 N 3677 .50 W 4394.66 W 4417.21 W 4458.14 W 4467.62 W 4519.39 W 4580.60 W 4617.36 W 4641.80 W 4703.01 W 4764.22 W 4798.69 W 4825.42 W 4886.63 W 4947.83 W 4973.85 W 5009.04 W 5070.25 W 5087.19 W 5131.45 W 5159.31 W Page2of5 --,d.@~:""J- ConocoPhillips , . ., Global Coordinates Northings Easti (ft) 'ô~g{' . Vertical ,- Rate: Section Comment ~I1Oôft) 5996134.97 N 996236.97 N 5996231.55 N 5996217.46 N 5996194.80 N 5996163.76 N 5996124.57 N 5996109.02 N 5996077.53 N 5996069.61 N 5996025.61 N 5995973.61 N 5995942.37 N 5995921.60 N 5995869.60 N 5995817.59 N 5995788.30 N 5995765.59 N 5995713.58 N 5995661.57 N 5995639.47 N 5995609.57 N 5995557.56 N 5995543.17 N 5995505.56 N 5995481.89 N 472096.41 E 472022.65 E 471949.83 E 471878.51 E 471809.24 E 471742.53 E 471719.94 E 471678.90 E 471669.40 E 471617.49 E 471556.11 E 471519.26 E 471494.74 E 471433.37 E 471372.00 E 471337.42 E 471310.62 E 471249.25 E 471187.88 E 471161.79 E 471126.51 E 471065.14 E 471048.15 E 471003.76 E 470975.83 E 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 -847.35 Begin Dir @ 5.000/100ft : 6500.00ft MD, 4483.31ft TVD -858.09 -860.49 -854.52 -840.23 --" -817.73 -787.19 -748.84 -702.97 -649.94 -590.14 -567.75 Top Moraine -524.03 -513.32 End Dir, Start Sail @ 53.55°: 7615.41 MD, 5204.47ft TVD -454.11 -384.13 -342.10 -314.14 -244.15 -174.17 Base Moraine -134.74 -1 04.18 -34.19 35.79 65.54 -' Top H RZ Base H RZ 1 05.78 175.77 195.14 K-1 245.75 277.61 Kuparuk DrillQuest 3.03.02.002 ~... ;__._--J "~:TJ ;'.-' ;·...-'---L.·--'>%oI 1'],::,- ~.~~.~ r- Sperry-Sun Drilling Services Proposal Report for 35-17 Plan - 35-17 A (wp04) Your Ref: Revised Fal/back Target '" tied into surveys Revised: 28 April, 2003 Western North Slope Measured Sub-Sea Vertical local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings East' (ft) (ft) (ft) (ft) (ft) (ft) 8779.18 53.556 229.540 5840.00 5895.80 1564.84 N 5179.92 W 8787.60 53.556 229.540 5845.00 5900.80 1560.44 N 5185.07 W 8800.00 53.556 229.540 5852.37 5908.17 470942.39 E 8900.00 53.556 229.540 5911.77 5967.57 470881.02 E 9000.00 53.556 229.540 5971.17 6026.97 470819.65 E 9087.60 53.556 229.540 6023.21 6079.01 5995303.98 N 470765.88 E All data is in Feet (US Survey) unless otherwise stª~~g",_ "ordinates are relative to True North. Vertical depths are relative to RKB = 55.8' MSL.~:Nortñí-,ª9 . ,"C astings are relative to 2533' FNL, 1130' FEL. Global Northings and Eastings are relativE:!.tci-NJ\P?7 ATg~ka S âte Planes, Zone 4. --~~c-7'- -. The Dogleg Severity is in D61jreaspei1 00leet (USŠ(jr~;ev) Vertical Section is from 25:13 FNL. 11 JO' FEL .õ1n(1 C31(IJI;¡It:'ij along an Azimuth of 200.000° (True). Based upün MinimumCÛ;,/::¡tiJie t~~:~alculations, at a Measured Depth of 9087.60ft., The 3ùn,)m Hole D:~,13cem¿.nt IS 554~.19ft., in the Direction of 284.654° (True). The Along HOleOfspfä:ÒemêN is 6349.18ft, the Planned Tortuosity is 1.843°/1 OOft and the Directional Difficulty Index is 5.7. 28 October, 2003 - 16:31 Page30fS ConocoPhillips Comment 301.17 Base Kuparuk 307.06 TARGET: 8787.6ft MD, 5900.8ft TVD (974' FNL & 1510' FEL, Sec 13-T12N· R7E) Target - 3S-17F (Revised), 150.00-·~ Radius., Current Target 0.000 315.74 0.000 385.73 0.000 455.71 0.000 517.02 Total Depth: 9087.60ft MD, 6079.01ft TVD (1131' FNL & 1693' FEL, SEC. 1 T12N-R7E) 7" Casing ,--,,' Dril/Quest 3.03.02.002 a =t:ß -.. ç-. ~- .-. r;.·~ Western North Slope Comments Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for 35-17 Plan - 35-17 A (wp04) Your Ref: Revised Fallback Target... tied into surveys Revised: 28 April, 2003 ConocoPhillips Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6500.00 7615.41 8787.60 9087.60 4483.31 5204.47 5900.80 6079.01 Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dirn. ---'" 5100.00 5294.00 5470.00 5640.00 5750.00: 5820.00' 5840.00 0.000 359,817' 0.000 359;817 0.000/ 3!?~.817 . 0.000 3~9.817 0.000 359:817 0.000 ,.359.817 0.000 359.817 28 October, 2003 - 16:31 2240.23 N 2172.34 N 1560.44 N 1403.84 N P r .9{~ Measured . Ve(_ D~&)th,'r''fl~;g) ;- .--:" .;.;-:~~:: .. _,7~,4.92"> - .,:786'0. 06 ,}8156.33 , 8442.51 8627.68 8745.52 8779.18 "- 3677.50 W 4467.62 W 5185.07 W 5368.69 W , 483.31ft TVD . t MO, 5204.47ft TVD VD (974' FNL & 1510' FEL, See 13-T12N-R7E) 79.01ft TVD (1131' FNL & 1693' FEL, SEC. 13-T12N-R7E) - .--.---"- etration ea Depth (ft) Poi n t Northings (ft) Eastings (ft) Formation Name 5155.80 5100.00 2211.92 N 4417.21 W Top Moraine 5349.80 5294.00 2044.63 N 4617.36 W Base Moraine 5525.80 5470.00 1889.97 N 4798.69 W Top HRZ 5695.80 5640.00 1740.58 N 4973.85 W Base H RZ 5805.80 5750.00 1643.92 N 5087.19 W K-1 5875.80 5820.00 1582.41 N 5159.31 W Kuparuk 5895.80 5840.00 1564.84 N 5179.92 W Base Kuparuk ---- Page 4 0'5 DrillQuest 3.03.02.002 a ~~-- -<'_;,<;,1- ,-_J J ,-~-~ 1 Western North Slope Casing details Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Run-TD> <Run-TD> Tarøets associated with this well"ath Target Name 3S-17F (Revised) ') 28 October, 2003 - 16:31 Sperry-Sun Drilling Services Proposal Report for 35-17 Plan - 35-17 A (wp04) Your Ref: Revised Fal/back Target... tied into surveys Revised: 28 April, 2003 Casing Detail 7" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 5900.80 5845.00 Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Target Radius: 150.00ft PageS of 5 Target Shape 1560.44 N 5185.07 W 5995460.00 N 470950.00 E 700 23' 55.2335" N 1500 14' 11.0726" W Circle ConocoPhillips ~ Target Type Current Target ..............J DrillQuest 3.03.02.002 ) SPERRY_SUN HES Anticollision Report ') c~nipany:' Field: :R,eferenceShe: R.èference Well: I ' ,R~fer~nce Wellpath:,' Phillips Alaska Inc. KuparukRiver Unit Kupa.ruk3S Pad Plan: 3$717 Plan:3S-17A Date: 10/28/2003 TÌln~:17:02:46 .Page: 1 Co-ordìnate(NE) Reference: ' VeJ,"tical(TVD) Refere,nce: Well: Plan :3S-17, Trué North RKB = 55.8' MSL 55.8 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 6500.00 to 9087.78 ft Maximum Radius: 1106.61 ft Reference: Error Model: Scan Method: Error Surface: 'Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/28/2003 Validated: No Planned From To Survey ft ft 87.00 6500.00 6500.00 9087.78 Version: 2 Toolcode Tool Name 3S-17 (Rig Surveys) (3) Planned: 3S-17A (wp04) V8 MWD MWD MWD - Standard MWD - Standard Casing Points MP , 'ft 9094.22 TVD ft' 0.00 , Diameter ,In ' 7.000 8.500 7" Summary <+~~--~.~~.~~~7-~--~.-.()ftset WeUpath -~-~:~~~~~..~---7.'~--'"' ,I I 'Site ' Well 'W~U¡>ath", I Offsèt' '; Ctr.€tr " No~Go, " Allowable . MD,. Œst~nceArea ' Deviatioð, ,'ft' '. ft, ft 'ft Kuparu k 3S Pad Kuparu k 3S Pad Plan: 3S-13 Plan: 3S-17 3S-13 (BHL 19) V1 Plan 3S-17 (Rig) V3 6500.00 6500.00 0.00 1.02 Out of range -0.65 FAIL: No Errors n f~: L ¡r.~., Î : , , i WElLPATHDErAILS CO~A"ï' DErAILS P~~~Inc. KupMUk ANTI-COLLISION SETTINGS 25.00 9087.78 Plan: 3S-17F(wp04) WELL DETAILS EastÍn 476130.01 Slot :>fA Longttud 150'11'39.1631'.' Latitud 70'23·39.903S Sonhing 5993833.06 ,F/·W ·325 +SI 39.01 S:i!.IT'I:" ToMD 6500 6550 6600 6700 6800 6900 7000 7100 7300 7500 7700 7900 8100 8300 8500 8700 89rr 91 ~~' .....-31",/ Colour 90 55. 80ft ~~'D 0.00 From o 6500 6550 6600 6700 6800 6900 7000 7100 7300 7500 7700 7900 8100 8300 8500 8700 8900 3S-17 (Rig) 6500.00 N7ES RKB = 55.S· W;L Origin ü-rhrn +N-S +F/:-W 0.00 0.00 (Rig) Plan:3S-l7 (3S-17 Parent Wellpath: T~. on MD: Rli!: Rei. Datuùi: V.Section Angk 292. o 22 Caku!aiion Memod: Mi:ûm.m1 Curyaturë &Tor System: ISCWSA Sc@Method: Tra'i C)"tinde.r N-:>rÙl fIror Surfa«.: EJ!ipti<aJ + Casi1g W2JDing ~od: Rub; Based. 270- --22. -20.0 -10.0 -10.0 -20.0 -22.1 -15.0 -0 -5.0 -15.0 -5.0 Interval: To: Reference: ToMD 6500 6550 6600 6700 6800 6900 7000 7100 7300 7500 7700 7900 8100 8300 8500 8700 8900 9100 Interpolation Method:MD Depth Range From: 6500.00 Maximum Range: 1106.61 Colour 90 From o 6500 6550 6600 6700 6800 6900 7000 7100 7300 7500 7700 7900 8100 8300 ~O ~OO ___ 8700 ~ ~ 8900 ~ '\ \\ ('~ \ \\ \ \ (' Tool MWD SURVEY PROGRAM SutVeylPlan Planned: 3S-l7F (wp04) V8 o 420 400 Depth To 9087.78 P\ 71;:/ . Depth Fm 6500.00 270 -420 -400 -300 -100 -100 -300 -' A,,,,,",200 -200 t:-:) rO r l8CP' 3S-17A (wp04) Approved Plan --- Target 3S (l7LRev VSec ·U52.63 4957.72 5389.73 5500.24 ITace 0.00 -112.95 0.00 0.00 DLeg 0.00 5.00 0.00 0.00 40û 1 Ro'"UO SECfIO~ DEI' AILS +:\1-$ +FJ- W -3677.-18 -4467.-13 -5185.53 -5369.23 2240.11 2172.-12 1560.55 1404.02 TVD 4483.31 5204.16 5900.80 6079.00 AD 300.69 229.57 229.57 229.57 e 53.-17 53.56 53.56 53.56 ~ 6500.00 7615.02 8787.78 9087.78 See -400 -420 Centre Separation [lOft/in] Centre to VS [deg] Azimuth (TFO+AZI) Travelling Cylinder Centre to Centre Separation [200ft/in] [deg] vs Travelling Cylinder Azimuth (TFO+AZI ) 3S-17A 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 Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Low Moderate Moderate 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-17A Drilling Hazards Summary. doc prepared by Scott Lowry 4/28/03 n \~ê4 Page 1 of 1 KRU - 35-17 A I. .lector Proposed Completion Schematic Single Completion 16"x30" insulated conductor @ +1- 108' MD :i'Æ I I I I I I I I I I I ~ I I I I I I Surface csg. I 9-5/8"40# L-80 ~ BTC (3275' MD / 2560' TVD) C Sand Perfs (to be done after rig moves off) Production csg. 7" 26# L -80 BTCM (+1- 9088' MD) I ~ I I ~ I ~ ~ U ,~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ z i ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i~J ~ ~ ..- ~ ~ ~ ~ ~ ~ ~ ~ = ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 t- J~:: -.. i ._y~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ þ~~~~ ~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ) . ·~Ph········ _1··1- COnocO! .. ·i¡il:IPS i ~ ~ ~ ~ I L..... 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" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +1- 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" Camco IDS' nipple wI 2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2"'SAB-3' Permanent Packer set +1- 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" Camco 'D' nipple wI 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide w/ shear out sub. Tubing tail 320' above top planned perforation. TD @ 9,088' MD 16,079' TVD Scott L Lowry 04/28/03 '0' I, .:r 1(0 r~~~!~;:~~A:-~'~-~-~"'~~~~--'__~ ANCHORAGE AK 99501 DAn;; +,-¡2..h2Ø~62"'ß11 I PAY TO THE 9f/TTEof' ALAsfJC/ !~C ....... ... 1$/00 C>Q ; O~DEROF 'Ok~ ckct.l>,~-tø ··UULLAM"lðe-= ~ t · I~~ .:~~~;2~::::~~:,,~:æ;~~~~~Ê~j ,'?"""'J~"""'r'f",,,,,,...J·'"'{l"fl'1mn:~-..__.r~""~~~_'I""J~~~-'l--"~~~~,~,,,,=~~~~'§=;~_ --=- ~_=~ ~ ~~~,,~;;o~~~~ =-l~~~'"»-~~_ ~ =_~ - RECEIVED APR 2 9 2003 Alaska Oil & Gas Cons. Commission Anchorage ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME ~ ~- \'\ ~ PTD# ðC)~ -G<é;O '\ K\CèC\-~~ ~\. \ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 Ojody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY~c:.ø/'JøÞ'f$WELL NAME&a 3s-/7A PROGRAM: Exp _ Dev _ Redrll_ Re-Enter _ Serv X Wellbore seg_ FIELD & POOL t..¡1ð/oC/ INITCLASS /-e....._n:>,j /~-'1 GEOLAREA ¥76 UNIT# ///~o ON/OFFSHORE CI7'\..J ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . '0, N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ~.íJ > _ / _ .) 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N a.c- ~ð2 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #.2...1!L Y N (Service Well Only) 14. All wells w/in X mile area of review identified.. . . . . .. <Y)N /Và~ c- ENGINEERING G) N ~~ Iv ~ >"- ,,"«> '""- " \.," "-, ~"" ,~~ ~ \- · ~.,,~ \.-.- ~"o¡...~ ~'-,... <",( \c>"'~ "". Y N 3~~-\~==\ ::> Y N .-¥--W- ~ þ.. " ~ N ",,"-....?' ""' ~ \0 _ '-\. X'\t,. ",,-w ~-.Ñ \\-j ~ ~ ""b,~"<I...,\:Q! ~S...-..~,. \'\'Cc, 'MOo"'~\\'( ~. \-'" "" S<JC'<)~, --y<ED "'I "\. rQf)-N~ ~""'I..~~\\s~\\"'V".. C-\~\\v, )fer: Y N Y N APPR DATE ~11-;!} APPR DATE (Service Well Only) GEOLOGY APPR DATE #é d7Á? (Exploratory Only) Rev: 07/12/02 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . 18. CMT vol adequate to tie-in long stri'ng to surf csg. . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to ? S"ðc) psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. 33. 34. 35. 36. Permit can be issued wlo hydrogen sulfide measures. . . . . Data presented on potential overpressure zones. . . . . . . . Seismic analysis of shallow gas zones. . . . . . . . . . . . . Seabed condition survey (if off-shore). . . . . .. ...... Contact namelphone for weekly progress reports. ...... { ¡;U I .¡:;¡, ( GEOLOGY: RPcL PETROLEUM ENGINEERING: TEM U 1rv'\ RESERVOIR ENGINEERING JDH UIC ENGINEER JBR COMMISSIONER: Commentsllnstructions: ~ ð-~ ý;./ DTS \ /<,P~ SFD_ WGA G:\geology\perm its\checklist.doc MJW ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the tlistory file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) 803 -OBO " \ qq \ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 14 16:09:28 2003 Reel Header Service name..... . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/05/14 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. . . . . . . . . . . . . . . . ; . . . .03/05/14 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-17A 501032044801 Conoco Phillips Alaska, Inc. Sperry-Sun Drilling Services 14-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002401952 E. QUAM D. BURLEY MWD RUN 3 MW0002401952 E. QUAM D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2533 1130 56.46 27.70 ~,:~ [:.: (: F ~ '\ l~= r) ~ ~L:,= ~ &=.U Ii!- =- JU!\\ Or) 1",(', ("-'J' r'4 '- LUV l;1aSttÐ ()~j ¡~ G:£~ß C(:r~s~ ~\}tnrn~~5tOn ~~\:J~\~ lJlm~horê'ì.ae .... ) ') # 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 3275.0 # 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 EFFECTED BY SIDETRACKING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT 6160'MD / 4285'TVD IN THE 3S-17 WELLBORE. 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-17A WITH API#: 50-103-20448-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8949'MD / 6084'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: 10.3 - 11.3 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/14 Maximum Physical Record. .65535 F i I e 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 RPX RPS RPM RPD FET NCNT ROP PEF FCNT GR RHOB DRHO NPHI $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3254.5 3279.5 3279.5 3285.0 STOP DEPTH 8908.5 8908.5 8908.5 8908.5 8908.5 8861.0 8949.0 8873.0 8861.0 8916.5 8873.0 8873.0 8861.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD BIT RUN NO MERGE TOP 2 3250.0 MERGE BASE 6160.0 ) ) MWD $ 3 6160.5 8949.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-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 3250 8949 6099.5 11399 3250 8949 ROP MWD FT/H 1.03 307.82 177.575 11399 3250 8949 GR MWD API 42.25 425.54 121.283 11325 3254.5 8916.5 RPX MWD OHMM 0.27 60.94 4.02931 11318 3250 8908.5 RPS MWD OHMM 0.12 2000 4.48608 11318 3250 8908.5 RPM MWD OHMM 0.09 2000 6.92435 11318 3250 8908.5 RPD MWD OHMM 0.1 2000 12.122 11318 3250 8908.5 FET MWD HOUR 0.1592 91.4959 0.833431 11318 3250 8908.5 NPHI MWD PU-S 12.49 45.72 31.8681 11153 3285 8861 FCNT MWD CNTS 566.9 2578.5 990.083 11223 3250 8861 NCNT MWD CNTS 114641 197030 137450 11223 3250 8861 RHOB MWD G/CM 1.982 3.253 2.32917 11188 3279.5 8873 DRHO MWD G/CM -0.101 0.448 0.0595477 11188 3279.5 8873 PEF MWD BARN 1.36 12.52 3.04489 11247 3250 8873 First Reading For Entire File......... .3250 Last Reading For Entire File.......... .8949 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/14 Maximum Physical Record. .65535 File 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...... .03/05/14 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 RPD FET PEF NCNT FCNT RPM RPS RPX ROP GR DRHO RHOB NPHI $ 2 header data for each bit run in separate files. 2 .5000 # LOG HEADER DATA START DEPTH 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3250.0 3254.5 3279.5 3279.5 3285.0 STOP DEPTH 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 6160.0 ') 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 TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record 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 ) 28-APR-03 Insite 66.37 Memory 6160.0 3285.0 6160.0 47.5 55.0 TOOL NUMBER 155790 136749 151842 181190 8.500 3275.0 LSND 11.30 55.0 9.2 750 2.0 2.100 1.310 2.200 3.700 76.0 125.6 76.0 76.0 ') Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 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 3250 6160 4705 5821 3250 6160 ROP MWD020 FT/H 2.99 307.82 184.75 5821 3250 6160 GR MWD020 API 42.25 172.41 115.61 5812 3254.5 6160 RPX MWD020 OHMM 0.27 17.51 4.04525 5821 3250 6160 RPS MWD020 OHMM 0.12 2000 4.85411 5821 3250 6160 RPM MWD020 OHMM 0.09 2000 9.56663 5821 3250 6160 RPD MWD020 OHMM 0.1 2000 19.3094 5821 3250 6160 FET MWD020 HOUR 0.1592 52.3096 1.05772 5821 3250 6160 NPHI MWD020 PU-S 12.49 45.72 33.7984 5751 3285 6160 FCNT MWD020 CNTS 566.9 2578.5 874.914 5821 3250 6160 NCNT MWD020 CNTS 114641 192774 130800 5821 3250 6160 RHOB MWD020 G/CM 1.982 2.763 2.23962 5762 3279.5 6160 DRHO MWD020 G/CM -0.065 0.448 0.0688962 5762 3279.5 6160 PEF MWD020 BARN 1.65 12.52 3.01431 5821 3250 6160 First Reading For Entire File......... .3250 Last Reading For Entire File.......... .6160 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/14 'ì " 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...... .03/05/14 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 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 6160.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD STOP DEPTH 8908.5 8873.0 8949.0 8916.5 8908.5 8908.5 8908.5 8861.0 8861.0 8861.0 8873.0 8873.0 8908.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 STABILIZED LITHO DEN 01-MAY-03 Insite 66.37 Memory 8949.0 6160.0 8949.0 46.8 53.8 TOOL NUMBER 155790 136749 59952 ') CTN $ COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 105918 8.500 3275.0 Water 11.30 44.0 9.4 600 3.6 Based 1.900 1.200 1.700 2.400 77.0 125.6 77.0 77.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-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 6160.5 8949 7554.75 5578 6160.5 8949 ROP MWD030 FT/H 1.03 290.06 170.087 5578 6160.5 8949 GR MWD030 API 54.21 425.54 127.263 5513 6160.5 8916.5 RPX MWD030 OHMM 1.07 60.94 4.01243 5497 6160.5 8908.5 RPS MWD030 OHMM 1.11 69.36 4.09636 5497 6160.5 8908.5 RPM MWD030 OHMM 1.13 62.97 4.12634 5497 6160.5 8908.5 RPD MWD030 OHMM 1.19 99.95 4.51101 5497 6160.5 8908.5 FET MWD030 HOUR 0.1681 91.4959 0.595926 5497 6160.5 8908.5 NPHI MWD030 PU-S 14.74 43.93 29.8132 5402 6160.5 8861 FCNT MWD030 CNTS 766.2 2376 1114.18 5402 6160.5 8861 NCNT MWD030 CNTS 126642 197030 144616 5402 6160.5 8861 RHOB MWD030 G/CM 2.227 3.253 2.42427 5426 6160.5 8873 DRHO MWD030 G/CM -0.101 0.348 0.0496203 5426 6160.5 8873 PEF MWD030 BARN 1.36 10.46 3.0777 5426 6160.5 8873 First Reading For Entire File......... .6160.5 Last Reading For Entire File.......... .8949 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/14 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services ') ) Reel Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/05/14 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