Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
202-232
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-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 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 2601' 7" L-80 6159' 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 8113' SIZE DEPTH SET (MD) 62.5# 40# 108' Surface Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 143 bbls 15.8 ppg Class G Cement 5704-5854' 68 bbls 15.8 ppg cement (perf wash) Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 2123-5879' 40.3-2075' Plugged and Abandoned Perforations: 7802-7812' MD and 5853-5863' TVD (Cemented) 7812-7842' MD and 5863-5893' TVD (Cemented) Gas-Oil Ratio:Choke Size: 132 bbl 15.8 ppg Cement from Casing to OA Per 20 AAC 25.283 (i)(2) attach electronic information 7720' MD/ 5774' TVD PACKER SET (MD/TVD) 42" 12-1/4" 81 sx ArcticCrete Surface 570 sx AS Lite, 300 sx LiteCrete Surface 3368'Surface Surface 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 5998103 SETTING DEPTH TVD 5998155 TOP HOLE SIZE AMOUNT PULLED 478301 478332 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 1670' MD/ 1539' TVD N/A 2501' FNL, 993' FEL, Sec. 18, T12N, R8E, UM 1746' FSL, 1060' FWL, Sec. 8, T12N, R8E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476266 5993915 1694' FSL, 1044' FWL, Sec. 8, T12N, R8E, UM Surface/ Surface 8130' MD/ 6176' TVD ADL038106, ADL0380107 ALK4624, ALK4623 50-103-20440-00-00 KRU 3S-10 December 18, 2002 January 5, 2003 9. Ref Elevations: KB: 56.3 ft Kuparuk River Field/ Kuparuk River Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/24/2023 202-232/ 323-191 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/ GasBlok8-1/2" 7753'3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Surface By James Brooks at 10:29 am, Nov 14, 2023 Abandoned 10/24/2023 JSB RBDMS JSB 112723 G DSR-1/26/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1670' 1539' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email: jill.simek@conocophillips.com Contact Phone:(907) 263-4131 Staff Well Integrity Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Formation Name at TD: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Plugged and Abandoned Authorized Name and INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Plugged and Abandoned Authorized Title: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2023.11.09 14:24:38 -09'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC) 7,718.0 3S-10 3/18/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&A'd 7' below OG,Final site clearance waived by Adam Earl AOGCC 3S-10 10/24/2023 mouser Notes: General & Safety Annotation End Date Last Mod By NOTE: Hydrowell cement plug in 7" from 5204'=5880' RKB milled out to 6.25" ID 7/22/23 7/22/2023 rmoore22 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 40.3 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 40.3 3,368.3 2,600.8 40.00 L-80 BTC PRODUCTION 7 6.28 40.3 8,113.0 6,158.9 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 7,681.9 Set Depth … 7,752.9 Set Depth … 5,805.2 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,688.0 5,741.5 11.81 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT 2' ABOVE FULLY LANDED) Baker Seal Assy 3.000 7,690.3 5,743.8 11.78 PBR 5.870 BAKER 80-40 PBR Baker 80-40 2.970 7,703.9 5,757.2 11.62 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE Baker KBH-22 3.000 7,704.9 5,758.1 11.60 PACKER 5.956 BAKER SAB-3 PACKER Baker SAB-3 3.250 7,709.8 5,762.9 11.55 EXTENSION 4.500 80-40 MILL OUT EXTENSION Baker Mill Out Extensio n 3.730 7,728.9 5,781.7 11.42 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO Camco DS 2.750 7,736.0 5,788.6 11.40 WLEG 4.550 WIRELINE ENTRY GUIDE w/ SHEAR OUT SUB, 5" OD Baker PUMP OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 40.3 40.3 0.12 MARKER PLATE 30" marker plate-1/4" thick 30" Marker plate , 1/4" thick 10/24/2023 0.000 5,879.2 4,180.5 46.49 CIBP 5.61" CIBP MID-ELEMENT AT 5880', OAL 1.6' LEGACY HPBP 000- 5610- 002 5/5/2023 0.000 7,681.0 5,734.7 11.89 CUT WELLTEC MECHANCIAL TUBING CUT, TATTLE-TAIL INDICATED 3.61" BLADE TRAVEL, CUT WAS CALIPERED PER RWO ENGINEER REQUEST 3/19/2023 2.992 7,742.0 5,794.5 11.38 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 8/1/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 2,070.0 2,075.0 1,798.4 1,801.5 10/4/2023 4.0 APERF 5FT, 1.56", 4 SPF, 0 DEG PHASE, CASING PUNCH 5,704.0 5,729.0 4,064.8 4,080.7 6/19/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,730.5 5,770.5 4,081.7 4,107.5 6/19/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,772.0 5,792.0 4,108.5 4,121.7 5/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,792.0 5,812.0 4,121.7 4,134.9 6/18/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,814.0 5,834.0 4,136.3 4,149.7 5/26/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 5,834.0 5,854.0 4,149.7 4,163.2 5/26/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 7,802.0 7,812.0 5,853.3 5,863.1 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ 7,812.0 7,842.0 5,863.1 5,892.6 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,718.0 7,753.0 5,770.9 5,805.3 Cement Plug Pumped 18.5 bbls of 15.8 ppg class G cement. 17 bbls on bottom and 1.5 bbls on top. 8/1/2022 7,752.9 7,942.0 5,805.2 5,990.8 Cement Plug Pumped 18.5 bbls of 15.8 ppg class G cement. 17 bbls on bottom and 1.5 bbls on top. 8/1/2022 5,704.0 5,854.0 4,064.8 4,163.2 Plug – Perf- Wash-Cement Pumped 68 bbls 15.8ppg cement through Hydrawell tool 6/28/2023 2,123.0 5,879.2 1,831.9 4,180.5 Cement Plug LAYED IN 143 BBLS, 15.8 PPG, CLASS G 9/10/2023 40.3 2,075.0 40.3 1,801.5 Cement Plug CIRC'D IN 132 BBL 15.8 PPG CEMENT FROM CASING TO OA 10/7/2023 3S-10, 11/7/2023 6:07:16 PM Vertical schematic (actual) PRODUCTION; 40.3-8,113.0 IPERF; 7,812.0-7,842.0 IPERF; 7,802.0-7,812.0 Cement Plug; 7,752.9 ftKB CEMENT RETAINER; 7,742.0 Cement Plug; 7,718.0 ftKB PACKER; 7,704.9 CUT; 7,681.0 CIBP; 5,879.2 APERF; 5,834.0-5,854.0 APERF; 5,814.0-5,834.0 APERF; 5,792.0-5,812.0 APERF; 5,772.0-5,792.0 Plug – Perf-Wash-Cement; 5,704.0 ftKB APERF; 5,730.5-5,770.5 APERF; 5,704.0-5,729.0 SURFACE; 40.3-3,368.3 Cement Plug; 2,123.0 ftKB APERF; 2,070.0-2,075.0 CONDUCTOR; 40.3-108.0 MARKER PLATE; 40.3 Cement Plug; 40.3 ftKB KUP PROD KB-Grd (ft) 33.30 RR Date 1/9/2003 Other Elev… 3S-10 ... TD Act Btm (ftKB) 8,130.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044000 Wellbore Status PROD Max Angle & MD Incl (°) 53.84 MD (ftKB) 2,926.87 WELLNAME WELLBORE3S-10 Annotation Last WO: End DateH2S (ppm) 108 Date 6/6/2014 Comment SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-10 Plug and Abandonment November 6, 2023 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-10, commencing operations on April 23, 2023 and completing the Plug and Abandonment on October 24, 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 5,879ft KB, the production casing was perforated from 5,704ft to 5,854ft 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 2,123ft SLM inside the production casing. The production casing was perforated at 2,070-2,075ft and cement pumped to surface in the 7” production casing and 7” x 9-5/8” annulus. The well was then excavated below original ground level and the tree and wellhead removed. After state inspection, the well was capped with a marker plate, and the excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report Summary is attached. DTTMSTART JOBTYP SUMMARYOPS 4/22/2023 CHANGE WELL TYPE SLB ELINE MOVE EQUIPMENT FROM PRUDHOE BAY TO 3S PAD, SPOT EQUIPMENT, RIG UP FOR IBC-CBL LOG 4/23/2023 CHANGE WELL TYPE SLB COMPLE RU, DRIFT 7" CASING TO TUBING STUB @ 7676.5' PDC, PU IBC-CBL, LOSE COMMS IN LOGGER, TROUBLE-SHOOT, DECSION MADE TO BRING OUT NEW WAFE TO LOGGER & INSTALL, COMMS BACK BY MIDNIGHT. 4/24/2023 CHANGE WELL TYPE SLB ELINE LOG IBC-CBL FROM 7655' TO 5500' PDC. JOB IS READY FOR ELINE PERFORATING. 5/5/2023 CHANGE WELL TYPE SET 7" LEGACY CAST IRON BRIDGE PLUG MID-ELEMENT AT 5880'. AFTER PLUG SET, PRESSURE UP CASING TO 1500 PSI AND HOLD FOR 15 MIN (PASS), BLEED WELL BACK TO 0 PSI. JOB COMPLETE, READY FOR CASING PERFORATIONS 5/7/2023 CHANGE WELL TYPE MIRU ELINE, PT PCE, RIH WITH PEK-BB/CAL-B/WPSA/HSD GUN. PERFORATE INTERVAL 5792' - 5772' OFFSET 7.3' CCL STOP DEPTH 5764.7. GOOD INDICATION. POOH AND UNSTAB PCE. MIRU LRS FOR MIT. OPERATIONS CONTINUED INTO NEXT DAY. 5/8/2023 CHANGE WELL TYPE OPERATIONS CONTINUED FROM PREVIOUS DAY. PERFORM PASSING MIT W/ LRS TO 780 PSI. CONFIR W/ CONOCO REP, DECISION MADE TO RIG DOWN. JOB COMPLETE 5/25/2023 CHANGE WELL TYPE MOVE EQUIPMENT FROM 3S-26 TO 3S-10, SPOT EQUIPMENT AND PREPARE FOR PERFORATION RUN 5/26/2023 CHANGE WELL TYPE PERFORATE INTERVAL 5834' - 5854' WITH 4.72" HSD POWERFLOW GUN SET 7" BAKER RBP MID-ELEMENT AT 5813' WITH MEMORY GAUGES HUNG BELOW JOB COMPLETE, READY FOR LRS TO PERFORM FORMATION PRESSURE TEST 5/27/2023 CHANGE WELL TYPE PERFORM PRESSURE TEST ON FORMATION PUMPED 1.5 BBLS DSL DOWN TBG TO REACH TEST PSI OF 753 TESTED FOR 30 MIN., 09:15 AM START TIME PRE T/I/0=0/0/0 START T/I/O=753/740/0 15 MIN T/I/O=705/697/0 30 MIN T/I/O=683/675/0 BLED 0.8 BBLS BACK TO REACH STARTING PSI PUMPED 0.9 BBLS DSL DOWN TBG TO REACH TEST PSI OF 766 TESTED FOR 60 MIN starting time 10:00am PRE T/I/O=0/0/0 START T/I/O=766/756/0 15 MIN T/I/O=726/717/0 30 MIN T/I/O=711/703/0 45 MIN T/I/O=702/695/0 60 MINT/I/O=696/689/0 BLED 0.4 BBLS BACK TO REACH STARTING PSI 5/27/2023 CHANGE WELL TYPE PULLED BAKER 7" RBP W/ DUAL PRESSURE GAUGES HUNG BELOW @ 5813' RKB (MAX = 1804 PSI). JOB COMPLETE 6/18/2023 CHANGE WELL TYPE RIG UP ELINE TO PERFORATE W/ 4.72" POWERFLOW HSD. RUN 1: PERFORATED INTERVAL = 5814' - 5834', CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5806.7' RUN 2: PERFORATED INTERVAL = 5792' - 5812', CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5784.7' ***JOB IN PROGRESS*** 3S-10 Plug and Abandon Summary of Operations 6/19/2023 CHANGE WELL TYPE *** JOB CONTINUED FROM 6/18/23 *** GUN 3: PERFORATED INTERVAL = 5750.5' - 5770.5', CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5743.2' GUN 4: PERFORATED INTERVAL = 5730.5' - 5750.5', CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5723.2' GUN 5: PERFORATED INTERVAL = 5709' - 5729', CCL TO TOP SHOT = 7.3', CCL STOP DEPTH = 5701.7' GUN 6: PERFORATED INTERVAL = 5704' - 5709', CCL TO TOP SHOT = 12.1', CCL STOP DEPTH = 5691.9' DRIFTED WITH JUNK BASKET AND 5.9" GAUGE RING. TAGGED FILL AT 5861'. JOB COMPLETE 6/26/2023 CHANGE WELL TYPE CONDUCT BOP TEST. RIG UP 5.94" BEAR CLAW MILL BIT TO DRIFT TO CIBP. SAT DOWN AT 2221' CTMD. COME ONLINE WITH PUMP. UNABLE TO BREAK THROUGH OBSTRUCTION. POOH TO CHANGEOUT BHA.RIH W / MOTOR AND 6" MILL AT 2300' DIDN'T ANYTHING TAGGED AT 5830' CLEAN OUT TO CIBP 6/28/2023 CHANGE WELL TYPE CLEANED OUT TO 5857' CTMD. MADE UP HYDRAWELL TOOL. COMPLETED WASH PASSES ACROSS PERFS. PUMP 5/8" BALL DOWNHOLE. NO INDICATION OF TOOL SHIFT. POOH. RBIH PUMPED 68 BBLS OF 15.8 PPG CEMENT. PUMPED CIRC BALL PRESSURED UP TO 5500 PSI LOOKED LIKE IT SHEARED AND THEN UNABLE TO PUMP. POOH. RBIH TO CLEAN OUT CEMENT. RBIH TO FREEZE PROTECT WELL 119 BBLS OF DIESEL. RDMO. 7/3/2023 CHANGE WELL TYPE PRE STATE-WITNESSED TAG TOC @ 5186' SLM (EST TOC @ 5554'), CEMENT IN BAILER. PERFORM PASSING MIT TO 1500 PSI ON PRODUCTION CASING. JOB IN PROGRESS. 7/8/2023 CHANGE WELL TYPE TAG TOC @ 5180' SLM, CEMENT IN BAILER, STATE WITNESS CANCELED JOB IN PROGRESS 7/9/2023 CHANGE WELL TYPE PERFORM STATE WITNESS (ADAM EARL) TAG TOC @ 5197' SLM. STATE WITNESS MITT TO 1500 PSI (PASSED) READY FOR COIL. 7/20/2023 CHANGE WELL TYPE PERFORM WEEKLY BOP TEST. DRY TAG CEMENT AT 5204' CTMD. MILL HARD CEMENT FROM 5545' CTMD TO CIBP AT 5848' CTMD / 5880' RKB WITH 5.94" BEAR CLAW MILL. COMPLETED PASSES WITH 6.25" UNDERREAMER TO SAME. POOH. FREEZE PROTECT WELL. READY FOR ELINE CBL. 8/29/2023 CHANGE WELL TYPE MOBILIZED EQUIPMENT FROM, SPOT EQUIPMENT, PREPARE PCE, PREPARE FOR JUNK BASKET RUN. JOB IN PROGRESS 8/30/2023 CHANGE WELL TYPE PERFORMED JUNK BASKET (5.91") RUN, TAGGED FILL AT 5817' LOGGED USIT(IBC)-CBL FROM 5817' TO 4800' 5DEG 6", 5DEG 3", 5DEG 1.5" AND 5DEG 0.6" RESOLUTIONS PER PROCEDURE. JOB IN PROGRESS. 8/31/2023 CHANGE WELL TYPE LOGGED USIT(IBC)-CBL FROM 5817' TO 4800' AT 5DEG 6", 5DEG 3", 5DEG 1.5" AND 5DEG 0.6" RESOLUTIONS, RIG DOWN. JOB IS COMPLETE. 9/10/2023 CHANGE WELL TYPE STBY FOR WELL SUPPORT TO MOVE RIG UP. WEEKLY BOP TEST COMPLETE, LOWER EQ TEST PORT PLUGGED, WAIT ON BOP'S FROM DEADHORSE, SWAP BOP'S, FUNCTION TEST, SHELL TEST ON TREE.LAID IN 143 BBLS OF CEMENT 3 BBLS SHORT LEAVING CEMENT TOP AT APPROXIMATELY 2083' FREEZE PROTECT FROM 2000' W / 97 BBLS OF DIESEL JET BOP'S RDMO 9/15/2023 CHANGE WELL TYPE TAGGED CEMENT @ 2112' SLM, OBTAINED PASSING MIT ON 7" PRODUCTION CASING TO 1500 PSI. JOB COMPLETE, WELL READY FOR E-LINE. 10/3/2023 CHANGE WELL TYPE STATE WITNESS TAG TOC @ 2123' SLM. MITT PASSED AT 1500 PSI. READY FOR E-LINE. 10/4/2023 CHANGE WELL TYPE PERFORATED 7'' PRODUCTION CASING FROM 2070' - 2075' TO ESTABLISH CIRCULATION TO OA. SHOT 5FT, 1.56'' TUBING PUNCH (4 SPF, 0 Deg Phase, TWENTY 0.23" HOLES). CCL TO TOP SHOT = 7.5', CCL STOP DEPTH = 2062.5'. LRS PUMPED DOWN 7" CASING TO VERIFY INJECTION, TAKING RETURNS UP OA (20 BBL DIESEL PUMPED @ 2 BPM @ 1350 PSI), U- TUBED 7"x9-5/8" FOR FP. CORRELATED TO STATE WITNESSED TAG OF TOC FROM 10/3/23. JOB IS READY TO PUMP CEMENT 10/7/2023 CHANGE WELL TYPE PUMPED 5 BBL WATER INJECTION TEST, PRESSURE TESTED TO 3500 PSI, GOOD TEST, MIXED 40 BBL SURFACTANT PILL, PUMPED WORKING UP TO 4BPM MAX, MATCHING RETURNS, SHUT DOWN, BATCHED 15.8 CEMENT, GOOD SCALE, STARTED PUMPING WORKING UP TO 3BPM, STARTED TO SEE CEMENT RETURNS @ 132 BBL, PUMPED 5BBL ADDITIONAL, GOOD CEMENT TO SURFACE, SHUT DOWN, CLOSED INNER CASING VALVE, CLOSED OA VALVE. 10/10/2023 CHANGE WELL TYPE (P & A) DDT T X IA (PASSED), DDT OA (PASSED), TXIA TOC = 69", OA TOC @ SF. 10/16/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- REMOVED IA VALVES AND DOUBLE SWAB VALVES, REPLACED WITH BLINDS AFTER ALLOWING TO BREATHE TO ATMOSPHERE FOR 5 HOURS. 10/17/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- CUT AND REMOVED WELL HEAD 72" BELOW TUNDRA REFERERNCE MARK ON INNER CASING HANGER FLANGE.. WELL STUB ~36" BELOW ORIGINAL TUNDRA. REMOVED STEEL CELLAR, SET 8' x16 SHORE CAN. *** NEXT STEP - VIBRATE SHORE CAN TO DEPTH.**** 10/18/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- NES VIBRATED SHORE CAN INTO POSITION AND BEGAN EXCAVATING WITHIN SHORE CAN. ACHIEVED 9' OF TARGET DEPTH 12'. ***NEXT STEP CONTINUE TO EXCAVATE TO TARGET DEPTH AND PREP WELL STUB FOR REMOVAL.*** 10/19/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- CUT AND REMOVED ADDITIONAL 55" OF WELL STUB. TOC = 7' 7" BELOW OG ***NEXT STEP-PREP 3S-10 WELL STUB FOR MARKER PLATE**** 10/21/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- AOGCC INSPECTOR WITNESSED MARKER PLATE INFORMATION AND WELD. MARKER PLATE GREATER THAN 7' BELOW ORIGINAL TUNDRA. PREPARED SHORE CAN FOR INSPECTION BY MISTRAS. ***NEXT STEP- CAN INSPECTION, BACKFILL , CAN EXTRACTION, FINAL SITE CLEARANCE..*** 10/22/2023 CHANGE WELL TYPE (P&A) IN PROGRESS- MISTRAS INSPECTED SHORE CAN PRIOR TO EXTRACTION.BACKFILLED SHORE CAN AND REMOVED. ***NEXT STEP REQUEST FINAL SITE CLEARANCE FROM AOGCC.*** 10/24/2023 CHANGE WELL TYPE P&A COMPLETE. FINAL SITE CLEARANCE WAIVED PER EMAIL CRITERIA FROM INSPECTOR ADAM EARL. From:Davies, Stephen F (OGC) To:Brooks, James S (OGC) Subject:RE: issue with KRU 407 Date:Tuesday, December 19, 2023 9:44:45 AM Attachments:image001.png Certainly. I re-calculated the coordinates for 3S-10 in RBDMS and they now are only different by about one foot. Cheers From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Tuesday, December 19, 2023 9:34 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: issue with KRU 407 Can you check coordinates for 3S-10 ? thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, December 19, 2023 9:31 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: issue with KRU 407 Hi James, This is what I have recorded in my work journal: Cheers and Be Well, Steve From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Tuesday, December 19, 2023 9:24 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: issue with KRU 407 My apologies, I did not document this very well. Was this for KRU 3S-10 (ptd 202-232) or 3S-26 (201-040) ? thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, December 11, 2023 2:09 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: issue with KRU 407 Hi James, I checked all of the coordinates in RBDMS against the original Completion Report in the Well History file and they all looked fine. I re-entered the coordinate values into RBDMS again, pressed the “Calc Surface Spot” button, and they recalculated to values that are very close the Operator’s reported State Plane Coordinates. I don’t know what happened, but re-entering the values and recalculating the coordinates in RBDMS did the trick. Thanks, Steve From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Monday, December 11, 2023 12:06 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: issue with KRU 407 Here you go thanx -$0(6%522.6 5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21 '(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17 E-$0(6%522.6#$/$6.$*29 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact James Brooks at 907-793-1241 or james.brooks@alaska.gov. 2023-1021_Surface_Abandon_KRU_3S-10_am Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/21/2023 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandonment Petroleum Inspector Kuparuk River Unit (KRU) 3S-10 ConocoPhillips Alaska Inc. (CPAI) PTD 2022320; Sundry 323-191 10/21/2023: I traveled to location and met with Roger Mouser of CPAI to witness the surface abandonment of the well. The well had been cut off 7 feet below original ground level. All annuli had cured cement to surface. I used a shovel to verify cement integrity. Marker plate was of proper thickness and didn’t extend beyond outermost string. I requested the field name KRU be welded next to the well name. I found no issues with this inspection other than the field name and informed Roger he could weld the marker plate on and back fill the hole. Attachments: Photos 2023-1021_Surface_Abandon_KRU_3S-10_am Page 2 of 4 Surface Abandonment – KRU 3S-10 (PTD 2022320) Photos by AOGCC Inspector A. McLeod 10/21/2023 2023-1021_Surface_Abandon_KRU_3S-10_am Page 3 of 4 2023-1021_Surface_Abandon_KRU_3S-10_am Page 4 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:8130 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@ 3368 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8113 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 7753 Feet Tbg Cut@ 7681 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Casing Stub Bridge plug 5880 ft 2123 ft 7.9 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1700 1615 1575 IA 1700 1615 1575 OA 30 30 30 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): Good cement sample returned in bailer after tag. October 3, 2023 Kam StJohn Well Bore Plug & Abandonment KRU 3S-10 ConocoPhillips Alaska Inc PTD 2022320; Sundry 323-191 none Test Data: P Casing Removal: rev. 3-24-2022 2023-1003_Plug_Verification_KRU_3S-10_ksj 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:8130 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@ 3368 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 8113 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 7753 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 5884 ft 5197 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1710 1650 1620 IA OA 40 40 40 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to KRU 3S-10 to witness a wireline tag and pressure test for P&A. The wireline tag was first with the tool string consisting of weight bar, spangs, and a 2-inch sample bailer. Hanging weight was 200lbs. Top of cement was tagged @ 5,197 feet MD. The sample bailer brought back a decent mix of good cement and interface. Test went as per chart above. July 9, 2023 Adam Earl Well Bore Plug & Abandonment KRU 3S-10 ConocoPhillips Alaska Inc PTD 2022320; Sundry 323-191 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-0709_Plug_Verification_KRU_3S-10_ae SFD 3/31/2023GCW 04/12/23JLC 4/12/2023 04/12/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.12 16:53:17 -08'00' RBDMS JSB 041423 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 2601' 7" L-80 6159' 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 17 bbl 15.8 ppg Class G cement below retainer, 1.5 bbls 15.8 ppg Class G cement on top of retainer ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/ GasBlok8-1/2" 7753'3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/12/2022 202-232/ 322-150 50-103-20440-00-00 KRU 3S-10 ALK4624, ALK 4623 12/28/2022 8130' MD/ 6176' TVD 7722' MD/ 5775' TVD P.O. Box 100360, Anchorage, AK 99510-0360 476266 5993915 CASING WT. PER FT.GRADE 1/5/2003 CEMENTING RECORD 5998103 1670' MD SETTING DEPTH TVD 5998155 TOP HOLE SIZE AMOUNT PULLED 478301 478332 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. N/A 2501' FNL, 993' FEL, Sec. 18, T12N, R8E, UM 1694' FSL, 1044' FWL, Sec. 8, T12N, R8E, UM 1746' FSL, 1060' FWL, Sec. 8, T12N, R8E, UM 9. Ref Elevations: KB: 56.3 ft or BOTTOM DEPTH SET (MD) 7720' MD/ 5774' TVD PACKER SET (MD/TVD) 42" 12-1/4" 81 sx ArcticCrete 29'570 sx AS Lite, 300 sx LiteCrete 30' 3368'29' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Kuparuk River Field/ Kuparuk River Oil Pool ADL0380106, ADL0380107 Flow Tubing SUSPENDED Perforation: 7802-7812' MD and 5853-5863' TVD (Cemented) 7812-7842' MD and 5863-5893' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 26# 26' 62.5# 40# 180' Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: 7722-7842' MD Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 26' 8113' SIZE 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 8/12/2022 JSB RBDMS JSB 022823 xG Susp. DSR-3/3/23 202-232/ 322-150 KRU 3S-10 Kuparuk River Field/ Kuparuk River Oil Pool Suspended Development WCB 2023-08-04 Permit to Drill Number / Sundry: 8/12/2022 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1670' 1670' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations Contact Name: Jill Simek Contact Email: jill.simek@conocophillips.com Contact Phone:(907) 263-4131 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 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 TPI (Top of Producing Interval). Formation Name at TD:N/A - Suspended 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. INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title:Staff Well Integrity Engineer Signed for Jill Simek Digitally signed by Allen EscheteDN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.com Reason: I have reviewed this document Location:Date: 2023.02.20 15:22:01-09'00'Foxit PDF Editor Version: 12.0.1 Allen Eschete Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag TOC 3S-10 8/12/2022 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic 9.0 11/1/2009 lmosbor General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / GEN 5 / 5M TREE CONNECTION: TOP 5.75"" ACME W/3.5"" EUE 8RD THREAD 1/8/2003 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 29.2 3,368.3 2,600.8 40.00 L-80 BTC PRODUCTION 7 6.28 26.4 8,113.0 6,158.9 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.2 Set Depth … 7,752.9 Set Depth … 5,805.2 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD 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) 24.2 24.2 0.07 HANGER 8.100 FMC GEN 5 TUBING HANGER FMC Gen IV 2.992 498.1 497.3 5.59 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO Camco DS 2.875 3,388.5 2,613.4 51.63 GAS LIFT 5.390 Camco KBUG-M 2.920 5,259.8 3,788.6 52.03 GAS LIFT 5.390 Camco KBUG-M 2.920 6,439.7 4,600.0 35.11 GAS LIFT 5.390 Camco KBUG-M 2.920 7,116.8 5,199.0 21.15 GAS LIFT 5.390 Camco KBUG-M 2.920 7,605.5 5,661.0 13.21 GAS LIFT 5.968 Camco MMG 2.920 7,656.6 5,710.8 12.18 SLEEVE 4.520 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE Baker CMU 2.812 7,704.0 5,757.2 11.61 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT 2' ABOVE FULLY LANDED) Baker Seal Assy 3.000 7,706.3 5,759.5 11.59 PBR 5.870 BAKER 80-40 PBR Baker 80-40 2.970 7,720.0 5,772.9 11.45 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE Baker KBH-22 3.000 7,720.9 5,773.8 11.45 PACKER 5.956 BAKER SAB-3 PACKER Baker SAB-3 3.250 7,725.8 5,778.6 11.43 EXTENSION 4.500 80-40 MILL OUT EXTENSION Baker Mill Out Extensio n 3.730 7,745.0 5,797.4 11.37 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO Camco DS 2.750 7,752.0 5,804.3 11.35 WLEG 4.550 WIRELINE ENTRY GUIDE w/ SHEAR OUT SUB, 5" OD Baker PUMP OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,722.0 5,774.9 11.44 TUBING PLUG Pumped 18.4 bbls of 15.8 ppg class G cement. 17 bbls on bottom and 1.5 bbls on top. 8/12/2022 0.000 7,742.0 5,794.5 11.38 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 8/1/2022 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) 3,388.5 2,613.4 51.63 1 GAS LIFT DMY BK 1 0.0 12/12/2020 0.000 5,259.8 3,788.6 52.03 2 GAS LIFT DMY BK-5 1 0.0 1/8/2003 0.000 6,439.7 4,600.0 35.11 3 GAS LIFT DMY BK-5 1 0.0 1/8/2003 0.000 7,116.8 5,199.0 21.15 4 GAS LIFT DMY BK-5 1 0.0 1/8/2003 0.000 7,605.5 5,661.0 13.21 5 GAS LIFT DMY RK 1 1/2 0.0 12/13/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,802.0 7,812.0 5,853.3 5,863.1 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ 7,812.0 7,842.0 5,863.1 5,892.6 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ IPERF; 7,802.0-7,812.0 TUBING PLUG; 7,722.0 CEMENT RETAINER; 7,742.0 PACKER; 7,720.9 GAS LIFT; 7,605.5 GAS LIFT; 7,116.8 GAS LIFT; 6,439.7 GAS LIFT; 5,259.8 GAS LIFT; 3,388.5 SURFACE; 29.2-3,368.3 NIPPLE; 498.1 CONDUCTOR; 30.0-108.0 DTTMSTART JOBTYP SUMMARYOPS 4/29/2022 SUPPORT OTHER OPERATIONS RIGGED UP AND UPON PRESSURE TESTING PCE NOTICED LEAK. LAY DOWN EQUIPMENT TO TROUBLE SHOOT. IN PROGRESS. 7/31/2022 SUPPORT OTHER OPERATIONS MIRU RIH W / CEMENT RETAINER STARTED STACKING WT AT 4400' BLEED GAS CAP PUMP DOWN BS STILL HAVING TROUBLE POOH AT 1100' HAD A OVER PULL AND AT SURFACE RETAINER WAS GONE. P/U A NZ BHA RIH AND TAGGED @ 1075' STACKED WT -20K POOH P/U MOTOR AND MILL RIH AND START MILLING ON RETAINER AT 11075' 8/1/2022 SUPPORT OTHER OPERATIONS CONTINUE MILL @ 1204' GOT SLIPS & RUBBER & METAL CHUNKS BACK IN VENTURI ON THE THIRD RUN W / VENTURI RECOVERED LOWER HALF OF THE RETAINER RBIH W / MOTOR AND MILL TAGGED HYDRATES AT 1338' MILLED HYDRATES TO 2500' RAN IN TO 7611' POOH.& P/U RETAINER RBIH SET RETAINER @ 7742' RKB. PUMP 18.5 BBLS OF 15.8 CLASS G CEMENT THRU RETAINER. PUMP 1.5 BBLS ON TOP OF RETAINER. DROP BALL & PUMP CONTAIM PILL & CHASE OUT. F/P TBG FROM 2500' W/ DIESEL. READY FRO S/l TAG IN ~ 24 HOURS. 8/5/2022 SUPPORT OTHER OPERATIONS PERFORM PASSING MIT-T TBG TO 1500 PSI, IN PROGRESS 8/6/2022 SUPPORT OTHER OPERATIONS DRIFTED TBG W/ 2.25" CENT & SAMPLE BAILER, TAGGED TOC @ 7718' SLM, RECOVERED CEMENT SAMPLE. PERFORMED PASSING DDT-T TEST. 8/12/2022 SUPPORT OTHER OPERATIONS DRIFT TBG W 2.25" CENT @ SAMPLE BAILER, TAGED TOC @ 7722' SLM, RECOVERED CEMENT SAMPLE, LRS TO MITT & CMIT PASSED 3S-10 Suspend Summary of Operations SET RETAINER @ 7742' RKB. PUMP 18.5 @ BBLS OF 15.8 CLASS G CEMENT THRU RETAINER @ RIH AND START MILLING ON RETAINER AT 11075' PERFORM PASSING MIT-T TBG TO 1500 PSI 1.5 bbls of cement atop the retainer, inside the 3-1/2" tubing. This translates to 172' (1.5 bbls)/(.00870 bbl/ft)=172.4'), making the projected TOC 7742'-172'=7570'. But, the TOC tag was lower, at 7718. So, there is 7742'-7718'=24' of cement atop the retainer. - WCB **The below WBS does not show cement in the 7" casing. Per my request, Conoco sent an updated WBS, showing the cement in the casing. The new WBS is its own PDF, separate from this file. -WCB As per 25.112 (c)(1)(D), the retainer was set between 50' and 500' above the perforated interval, as it was set at 7742', and the uppermost perfs are at 7802'. 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 7842'-7753'=89'. Casing cap is 26.14 ft/bbl. So the casing contains (89')/(26.14 ft/bbl) =3.4 bbls cement. 18.5 bbls were pumped through the retainer, so roughly 15 bbls cement (18.5-3.4=15.1) were squeezed into the perfs. -WCB MIRU RIH W / CEMENT RETAINER STARTED STACKING WT AT 4400' BLEED GAS CAP PUMP DOWN BS STILL HAVING TROUBLE POOH AT 1100' HAD A OVER PULL AND AT SURFACE RETAINER WAS GONE. DRIFTED TBG W/ 2.25" CENT & SAMPLE BAILER, TAGGED TOC @ 7718' SLM 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8130'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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 Grade: Tubing MD (ft): 7721' MD and 5774' TVD 498' MD and 497' TVD Perforation Depth TVD (ft): Tubing Size: L-80 7753' 3/26/2023 Packer: Baker SAB-3 Packer SSSV: Camco DS Nipple w/NoGo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380106, ADL0380107 202-232 P.O. Box 100360, Anchorage, AK 99510 50-103-20440-00-00 ConocoPhillips Alaska, Inc. KRU 3S-10 Kuparuk River Field N/A Length Size TVD Burst 6176' 7722' 5775' 1440 7722' MD 108' 2601' 108' 3368' 6159'8113' 16" 9-5/8" 78' 3339' Perforation Depth MD (ft): 7802-7842' (cemented) 8087' 5853-5893'' (cemented) 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Current Pools: N/A Proposed Pools: N/A By Samantha Carlisle at 11:01 am, Feb 13, 2023 323-086 X DLB 02/15/2023 10-407 X VTL 2/15/23X DSR-2/13/23 BOP test to 2500 psig Annular preventer to 2500 psig X VTL 2/17/23GCW 02/22/23 JLC 2/22/2023 2/22/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.22 15:26:02 -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 Producer 3S-10 (PTD# 202-232). Well 3S-10 was drilled and completedas a Kuparuk Producer in January 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-10 RWO Procedure Kuparuk Producer Suspend PTD # 202-232 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-10. (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-10 RWO Procedure Kuparuk Producer Suspend PTD # 202-232 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: 3/26/2023 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 8/5/2022. (Well will be P&A’d and tubing will cut for RWO.) CMIT Passed 8/12/2022 MIT-OA Passed to 1800 psig 9/15/2019. IC POT &PPPOT PASSED 8/27/2020. TBG POT &PPPOT PASSED 8/27/2020. 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-10 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 3368 2601 9.625 8.92 40 L80 BTC BTC Production/ Intermediate 8113 6159 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 ~7690' 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 7,722.0 3S-10 8/12/2022 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag TOC 3S-10 8/12/2022 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic 9.0 11/1/2009 lmosbor 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 WELD Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.2 Set Depth (ft… 3,368.3 Set Depth … 2,600.8 Wt/Len (lb/ft) 40.00 Grade L-80 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.4 Set Depth (ft… 8,113.0 Set Depth … 6,158.9 Wt/Len (lb/ft) 26.00 Grade L-80 Top Connection BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.2 Set Depth … 5,805.2 String Ma… 3 1/2 Tubing Description TUBING Set Depth (ftKB) 7,752.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD 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) 24.2 24.2 0.07 HANGER 8.100 FMC GEN 5 TUBING HANGER FMC Gen IV 2.992 498.1 497.3 5.59 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" NO GO Camco DS 2.875 3,388.5 2,613.4 51.63 GAS LIFT 5.390 Camco KBUG-M 2.920 5,259.8 3,788.6 52.03 GAS LIFT 5.390 Camco KBUG-M 2.920 6,439.7 4,600.0 35.11 GAS LIFT 5.390 Camco KBUG-M 2.920 7,116.8 5,199.0 21.15 GAS LIFT 5.390 Camco KBUG-M 2.920 7,605.5 5,661.0 13.21 GAS LIFT 5.968 Camco MMG 2.920 7,656.6 5,710.8 12.18 SLEEVE 4.520 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE Baker CMU 2.812 7,704.0 5,757.2 11.61 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT 2' ABOVE FULLY LANDED) Baker Seal Assy 3.000 7,706.3 5,759.5 11.59 PBR 5.870 BAKER 80-40 PBR Baker 80-40 2.970 7,720.0 5,772.9 11.45 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE Baker KBH-22 3.000 7,720.9 5,773.8 11.45 PACKER 5.956 BAKER SAB-3 PACKER Baker SAB-3 3.250 7,725.8 5,778.6 11.43 EXTENSION 4.500 80-40 MILL OUT EXTENSION Baker Mill Out Extensio n 3.730 7,745.0 5,797.4 11.37 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO Camco DS 2.750 7,752.0 5,804.3 11.35 WLEG 4.550 WIRELINE ENTRY GUIDE w/ SHEAR OUT SUB, 5" OD Baker PUMP OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Make Model SN ID (in) 7,722.0 5,774.9 11.44 TUBING PLUG Pumped 18.4 bbls of 15.8 ppg class G cement. 17 bbls on bottom and 1.5 bbls on top. 0.000 7,742.0 5,794.5 11.38 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) 3,388.5 2,613.4 51.63 1 GAS LIFT DMY BK 1 0.0 12/12/2020 0.000 5,259.8 3,788.6 52.03 2 GAS LIFT DMY BK-5 1 0.0 1/8/2003 0.000 6,439.7 4,600.0 35.11 3 GAS LIFT DMY BK-5 1 0.0 1/8/2003 0.000 7,116.8 5,199.0 21.15 4 GAS LIFT DMY BK-5 1 0.0 1/8/2003 0.000 7,605.5 5,661.0 13.21 5 GAS LIFT DMY RK 1 1/2 0.0 12/13/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,802.0 7,812.0 5,853.3 5,863.1 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ 7,812.0 7,842.0 5,863.1 5,892.6 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ 3S-10, 8/13/2022 1:34:39 PM Vertical schematic (actual) PRODUCTION; 26.4-8,113.0 FLOAT SHOE; 8,111.5-8,113.0 FLOAT COLLAR; 7,942.7- 7,944.0 IPERF; 7,812.0-7,842.0 IPERF; 7,802.0-7,812.0 TUBING PLUG; 7,722.0 WLEG; 7,752.0 NIPPLE; 7,745.0 CEMENT RETAINER; 7,742.0 XO THREAD; 7,732.0 TUBING COLLAR; 7,731.4 EXTENSION; 7,725.8 PACKER; 7,720.9 ANCHOR; 7,720.0 PBR; 7,706.3 SEAL ASSY; 7,704.0 SLEEVE; 7,656.6 GAS LIFT; 7,605.5 GAS LIFT; 7,116.8 GAS LIFT; 6,439.7 GAS LIFT; 5,259.8 GAS LIFT; 3,388.5 SURFACE; 29.2-3,368.3 FLOAT SHOE; 3,366.6-3,368.3 FLOAT COLLAR; 3,282.2- 3,283.7 PORT COLLAR; 1,013.0- 1,016.0 NIPPLE; 498.1 CONDUCTOR; 30.0-108.0 HANGER; 29.2-31.4 HANGER; 26.4-28.7 HANGER; 24.2 KUP PROD KB-Grd (ft) 33.30 RR Date 1/9/2003 Other Elev… 3S-10 ... TD Act Btm (ftKB) 8,130.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044000 Wellbore Status PROD Max Angle & MD Incl (°) 53.84 MD (ftKB) 2,926.87 WELLNAME WELLBORE3S-10 Annotation Last WO: End DateH2S (ppm) 108 Date 6/6/2014 Comment 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: 8130 ft MD Lease No.: ADL 0380106 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3368 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 8113 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 7753 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Retainer 7742 ft 7722 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1700 1640 1620 IA 410 410 410 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 100 100 100 100 IA 1670 1640 1620 1620 OA 0 0 0 0 Remarks: Attachments: Suspension plug. Inspector Bob Noble and 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 7722 ft MD. MITT & MITIA went well. Location was August 12, 2022 Kam StJohn Plug Verification KRU 3S-10 ConocoPhillips Alaska Inc. PTD 2022320; Sundry 321-150 Photo of Bailer Sampler Returns Test Data: P Casing Removal: Brent Rodgers P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-0812_Plug_Verification_KRU_3S-10_ksj 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: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 2601' 7" L-80 6159' 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 N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 26' 8113' SIZE 26# 26' 62.5# 40# 180' Sr Res EngSr Pet GeoSr Pet Eng Flow Tubing SUSPENDED Perforation: 7802-7812' MD and 5853-5863' TVD (Cemented) 7812-7842' MD and 5863-5893' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH SET (MD) 7720' MD/ 5774' TVD PACKER SET (MD/TVD) 42" 12-1/4" 81 sx ArcticCrete 29'570 sx AS Lite, 300 sx LiteCrete 30' 3368'29' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): CASING WT. PER FT.GRADE 1/5/2003 CEMENTING RECORD 5998103 1670' MD/ 1539' TVD SETTING DEPTH TVD 5998155 TOP HOLE SIZE AMOUNT PULLED 478301 478332 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. N/A 2501' FNL, 993' FEL, Sec. 18, T12N, R8E, UM 1694' FSL, 1044' FWL, Sec. 8, T12N, R8E, UM 1746' FSL, 1060' FWL, Sec. 8, T12N, R8E, UM 9. Ref Elevations: KB: 56.3 ft or BOTTOM 50-103-20440-00-00 KRU 3S-10 ALK4624, ALK 46238130' MD/ 6176' TVD 7722' MD/ 5775' TVD P.O. Box 100360, Anchorage, AK 99510-0360 476266 5993915 Kuparuk River Field/ Kuparuk River Oil Pool ADL0380106, ADL0380107 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 4/12/2023 202-232/ 323-086 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/ GasBlok8-1/2" 7753'3-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 7. Date Spudded: 12/28/2002 RECEIVED by James Brooks on 5/10/2023 at 10:29 AM Suspended 4/12/2023 JSB RBDMS JSB 051823 xGWCB 2023-07-17 Kuparuk River Field/ Kuparuk River Oil Pool 4/12/2023 Susp. KRU 3S-10 Development DSR-6/1/23 Suspended Permit to Drill Number / Sundry 202-232/ 323-086 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1670' 1539' 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. 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. TPI (Top of Producing Interval). Authorized Name and Formation Name at TD:N/A - Suspended 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 Page 1/2 3S-10 Report Printed: 5/9/2023 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) 4/9/2023 00:00 4/9/2023 09:00 9.00 MIRU, MOVE MOB P Mob rig from 1H-102 to CPF 3 0.0 0.0 4/9/2023 09:00 4/9/2023 16:30 7.50 MIRU, MOVE MOB P Mob Rig from CPF 3 to 3S-10. Sub on Location at 4:15 PM 0.0 0.0 4/9/2023 16:30 4/10/2023 00:00 7.50 MIRU, MOVE SVRG P Stage Sub. Start BWM on BOPE. Load Wellhead in Cellar.// Remove rental double gates and replace with Nabors owned doubles // Change out annular element // Taking pictures of all componants re-assembly stack 0.0 0.0 4/10/2023 00:00 4/10/2023 03:00 3.00 MIRU, MOVE SVRG P Performing Between wells maintenance on BOP system 0.0 0.0 4/10/2023 03:00 4/10/2023 07:00 4.00 MIRU, MOVE RURD P Spot Sub over 3S-10 and Pits to Sub. Berm in Rig. Spot Auxiliary equipment, cuttings tank, flow back tank, choke and flowback iron. Hook up steam and air to pits. 0.0 0.0 4/10/2023 07:00 4/10/2023 07:30 0.50 MIRU, MOVE SFTY P PJSM on Rising the Derrick. 0.0 0.0 4/10/2023 07:30 4/10/2023 12:00 4.50 MIRU, MOVE RURD P Working on Acceptance checklist. Raise Derrick and Bridal Down. Hook up Pits Interconnect. Get measurements for riser height. Accept Rig at Noon 0.0 0.0 4/10/2023 12:00 4/10/2023 12:30 0.50 MIRU, WELCTL SVRG P Rig Service. 0.0 0.0 4/10/2023 12:30 4/10/2023 13:15 0.75 MIRU, WELCTL COND P Take on fluid in the Pits. RU Circulating Manifold in the Cellar. 0.0 0.0 4/10/2023 13:15 4/10/2023 14:30 1.25 MIRU, WELCTL KLWL P Fluid pack to tiger tank and PT same to 250/3000 psi. Good Test. Start well Kill Ops pumping down TBG taking returns up the IA at 5 bpm, 300 psi. 0.0 0.0 4/10/2023 14:30 4/10/2023 15:00 0.50 MIRU, WELCTL OWFF P Blow Line down and OWFF for 30 mins. No Flow from TBG or IA. 0.0 0.0 4/10/2023 15:00 4/10/2023 15:15 0.25 MIRU, WELCTL MPSP P Set Type "H" BPV and PT same to 1000 psi for 15 mins. 0.0 0.0 4/10/2023 15:15 4/10/2023 20:15 5.00 MIRU, WHDBOP NUND P ND Wellhead. NU DSA and BOPE. 0.0 0.0 4/10/2023 20:15 4/10/2023 22:30 2.25 MIRU, WHDBOP RURD P Pick up test jt found collar to be missing, pick up 3.5" test donut // Rig up to test BOPs // shell test 2500 psi good test 0.0 0.0 4/10/2023 22:30 4/11/2023 00:00 1.50 MIRU, WHDBOP BOPE P Attempt to shell test leak off found to be blanking plug 0.0 0.0 4/11/2023 00:00 4/11/2023 01:30 1.50 MIRU, WHDBOP WAIT T Wait for FMC to bring xo for pulling blanking plug and install 2 way check 0.0 0.0 4/11/2023 01:30 4/11/2023 02:30 1.00 MIRU, WHDBOP OTHR T FMC pull blanking plug and install 2 way check // Pressure test 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 4/12/2023 Page 2/2 3S-10 Report Printed: 5/9/2023 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) 4/11/2023 02:30 4/11/2023 07:30 5.00 MIRU, WHDBOP BOPE P Start testing BOPE. Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 3-1/2" test joint, UVBR's, LVBR'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=2950 PSI, after closure=1500 PSI, 200 PSI attained =20 sec, full recovery attained = 185 sec. UVBR's= 5 sec, Annular= 30 sec. Simulated blinds= 5 sec. LVBR’s=6 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 1970 PSI. Test gas detectors, PVT and flow show. Test Witness Waived by AOGCC rep Sean Sullivan. 0.0 0.0 4/11/2023 07:30 4/11/2023 08:15 0.75 MIRU, WHDBOP RURD P Rig down test equipment // Pull 2-way check 0.0 0.0 4/11/2023 08:15 4/11/2023 08:45 0.50 PROD1, RPCOMP BHAH P Pick up spear BHA 0.0 26.0 4/11/2023 08:45 4/11/2023 09:30 0.75 PROD1, RPCOMP THGR P Spear tubing hanger // Pull off seat 95K // Pull hanger to rig floor and lay down 26.0 0.0 4/11/2023 09:30 4/11/2023 17:30 8.00 PROD1, RPCOMP PULL P LD 3.5" completion F/7680' to surface 7,680.0 0.0 4/11/2023 17:30 4/11/2023 18:00 0.50 PROD1, RPCOMP RURD P RD tubing handling eq. 0.0 0.0 4/11/2023 18:00 4/11/2023 18:15 0.25 COMPZN, WHDBOP FRZP P Freeze protect casing to 250' with 12 BBL's LEPD diesel. 0.0 0.0 4/11/2023 18:15 4/11/2023 19:15 1.00 COMPZN, WHDBOP NUND P ND BOP's 0.0 0.0 4/11/2023 19:15 4/11/2023 20:30 1.25 COMPZN, WHDBOP NUND P NU TBG head and 7-1/16" dry hole tree. 0.0 0.0 4/11/2023 20:30 4/12/2023 00:00 3.50 DEMOB, MOVE RURD P Rig down to move 3S-17 Rig Released 00:00 4/12/23 Rig: NABORS 7ES RIG RELEASE DATE 4/12/2023 Spear tubing hanger // Pull off seat LD 3.5" completion F/7680' to surface Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC) 7,718.0 3S-10 3/18/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Add Perforations 3S-10 5/7/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic 9.0 11/1/2009 lmosbor General Notes: Last 3 entries Com Date Last Mod By TREE: FMC / GEN 5 / 5M TREE CONNECTION: TOP 5.75"" ACME W/3.5"" EUE 8RD THREAD 1/8/2003 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 29.2 3,368.3 2,600.8 40.00 L-80 BTC PRODUCTION 7 6.28 26.4 8,113.0 6,158.9 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,681.0 Set Depth … 7,752.9 Set Depth … 5,805.2 String Ma… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,704.0 5,757.2 11.62 SEAL ASSY 5.870 LOCATOR SUB & PBR SEAL ASSEMBLY (SPACED OUT 2' ABOVE FULLY LANDED) Baker Seal Assy 3.000 7,706.3 5,759.5 11.59 PBR 5.870 BAKER 80-40 PBR Baker 80-40 2.970 7,719.9 5,772.8 11.45 ANCHOR 4.740 KBH-22 ANCHOR TUBING SEAL NIPPLE Baker KBH-22 3.000 7,720.9 5,773.7 11.45 PACKER 5.956 BAKER SAB-3 PACKER Baker SAB-3 3.250 7,725.8 5,778.6 11.43 EXTENSION 4.500 80-40 MILL OUT EXTENSION Baker Mill Out Extensio n 3.730 7,744.9 5,797.3 11.37 NIPPLE 4.500 CAMCO D NIPPLE w/ 2.75" NO GO Camco DS 2.750 7,752.0 5,804.3 11.35 WLEG 4.550 WIRELINE ENTRY GUIDE w/ SHEAR OUT SUB, 5" OD Baker PUMP OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,879.2 4,180.5 46.49 CIBP 5.61" CIBP MID-ELEMENT AT 5880', OAL 1.6' LEGACY HPBP 000- 5610- 002 5/5/2023 0.000 7,681.0 5,734.7 11.89 CUT WELLTEC MECHANCIAL TUBING CUT, TATTLE-TAIL INDICATED 3.61" BLADE TRAVEL, CUT WAS CALIPERED PER RWO ENGINEER REQUEST 3/19/2023 2.992 7,722.0 5,774.9 11.44 TUBING PLUG Pumped 18.4 bbls of 15.8 ppg class G cement. 17 bbls on bottom and 1.5 bbls on top. 8/12/2022 0.000 7,742.0 5,794.5 11.38 CEMENT RETAINER 2.725 ALPHA FH 1 TRIP SLEEVE VALVE CEMENT RETAINER 8/1/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,772.0 5,792.0 4,108.5 4,121.7 5/7/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEG PHASE 7,802.0 7,812.0 5,853.3 5,863.1 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ 7,812.0 7,842.0 5,863.1 5,892.6 C-4, 3S-10 1/15/2003 6.0 IPERF 2.5" HSD PJ 3S-10, 5/9/2023 12:59:07 PM Vertical schematic (actual) PRODUCTION; 26.4-8,113.0 IPERF; 7,812.0-7,842.0 IPERF; 7,802.0-7,812.0 TUBING PLUG; 7,722.0 CEMENT RETAINER; 7,742.0 PACKER; 7,720.9 CUT; 7,681.0 CIBP; 5,879.2 APERF; 5,772.0-5,792.0 SURFACE; 29.2-3,368.3 CONDUCTOR; 30.0-108.0 KUP PROD KB-Grd (ft) 33.30 RR Date 1/9/2003 Other Elev… 3S-10 ... TD Act Btm (ftKB) 8,130.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032044000 Wellbore Status PROD Max Angle & MD Incl (°) 53.84 MD (ftKB) 2,926.87 WELLNAME WELLBORE3S-10 Annotation Last WO: End DateH2S (ppm) 108 Date 6/6/2014 Comment SSSV: NIPPLE ! " # $! % " &&&&&&&&&&&&&&&&&&& ' $ (" " ) *$ +, *# - # ./$ 0/ 1 $ $ " # # ! 2 ,2 3 $ 4* 56 $ 7 895 7 * :*5 7 * ;*5 7 + #* :* + #* ;* : 5 7 5:*7 < =5:*7 1-8>$ " / 6 = ; = ;:*5 7;*5 7 ' - " != * ? = +, *# # (+ * ) != " /6 /$< * 6 .;# * @ @ @ 6A@ @"" #@/$< ! "$ "+ " B " #$ @"" # ! $ / ? : / 6" //C:/ >23 $ +, 23 $ ;+*?3 # " ::/ / $+ D+ @"" * " " + @ + .0.> 01'8> )10> $ 018'%01('>:* 1810> )1)-%)14->;* -%9'E =?= ?%-= ;" * $!$ @ ---4> 1-> * :*5 7 .E 4%)91E 01> 81> --.1> .)4>0E 6%18 00)-> 81> '.8> !" !# $$# !% & ' + 6 F 6 F /6$*@ " $ + ;/ $" ::/ / $ & $&$# !(# !% '!& #& '8"')'18 &)* +,!&)* - .) ?,88-.8G GF44)8 . ). .. " =G/ / %!). $9 / 0! 1 !( 2 !/ 0! 1 !#! @ :*5 7 00'>:*)00(>;* (14>:*(40>;* * ;*5 7 B 0/ # !# ! !# B$ * ! * !!% !# ' /#+ < = C =H 54807'.-%(- 8%(8- # 89'8'& 1 2! 4!!12!5! !6!56! !2 !5! 17 By Samantha Carlisle at 10:30 am, Mar 21, 2022 Jill Simek Digitally signed by Jill Simek Date: 2022.03.16 12:20:41 -08'00' '/% ; '65 6XVSHQVLRQ DSSURYHG WKURXJK 3 $ LQFOXGLQJ VXUIDFH DEDQGRQPHQW PXVW EH FRPSOHWHG E\ ; ; 97/ -/& Jeremy Price Digitally signed by Jeremy Price Date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³*´FHPHQWWKURXJKDFHPHQWUHWDLQHUDWDSSUR[LPDWHO\IW.%WKHQSODFLQJ EEORQWRSRIWKHUHWDLQHU$WDJDQGSUHVVXUHWHVWZLOOFRQILUPSODQQHG7RSRI&HPHQWLQ WXELQJDWaIW.% 3URFHGXUH 6OLFNOLQH/LWWOH5HG6HUYLFHV 2EMHFWLYH 'ULIWIRUFHPHQWUHWDLQHUSHUIRUPLQMHFWLYLW\WHVWWRFRQILUP DGHTXDWHUDWHVIRUFHPHQWLQJRSHUDWLRQV &RQGXFW6DIHW\0HHWLQJDQG,GHQWLI\+D]DUGV,QVSHFWZHOOKHDGDQGSDG FRQGLWLRQWRLGHQWLI\DQ\SUHH[LVWLQJFRQGLWLRQV 586OLFNOLQHDQG37(TXLSPHQWDVUHTXLUHG 5,+ZLWKGXPP\PHFKDQLFDOFHPHQWUHWDLQHUWRROVWULQJGRZQWRIW.% 5LJXS/56:LWKaEEOVGLHVHOSHUIRUPVWHSUDWHLQMHFWLYLW\WHVWIURP± ESPLQòESPLQFUHPHQWVXSWRDPD[LPXPSUHVVXUHRISVLWRHQVXUH DGHTXDWHUDWHVIRUFHPHQWLQJRSHUDWLRQV5HFRUG5HVXOWV',6&8665(68/76 :,7+:(//,17(59(17,216(1*,1((5 5'02 &RLOHG7XELQJ&HPHQWLQJ 2EMHFWLYH 3ODFHDFHPHQWSOXJDFURVVWKHSHUIRUDWLRQVDQGVTXHH]HVRPH FHPHQWLQWRSHUIRUDWLRQV &HPHQW9ROXPH&DOFXODWLRQV 72&DSSUR[LPDWHO\IW.%LQWXELQJ x´SURGXFWLRQFVJIWEHORZSHUIVWRWXELQJWDLO EEOIW IW± EEOV xò´WXELQJWXELQJWDLOWRIW.% EEOIW IW±IW EEOV x 6TXHH]HYROXPH EEOV x 7RWDOYROXPH EEOV (QVXUHDQDSSURYHGVXQGU\KDVEHHQUHFHLYHGIURP$2*&& &RQWDFW&HPHQWHUVDZHHNEHIRUHWKHVFKHGXOHG6XVSHQGGDWHWRDOORZ DGHTXDWHWLPHIRUSLORWWHVWLQJRIWKH3 $FHPHQWGHVLJQ7KHMRELVGHVLJQHGIRU EEOVRI&ODVV³*´FHPHQW &RQGXFW6DIHW\0HHWLQJDQG,GHQWLI\+D]DUGV,QVSHFWZHOOKHDGDQGSDG FRQGLWLRQWRLGHQWLI\DQ\SUHH[LVWLQJFRQGLWLRQV -6 58&RLO7XELQJ8QLWDQG376XUIDFH(TXLSPHQWDVUHTXLUHG 5HIHUHQFHVFKHPDWLFDQGWXELQJGHWDLOVIRUGHSWKFRUUHODWLRQ8VH &DPFR'QLSSOHDWIW.%IRUFRUUHODWLRQ 5,+ZLWKFHPHQWUHWDLQHUWDNLQJUHWXUQVXSWKH&7[7XELQJDQQXOXV'RQRW SXPSZKLOH5,+ 6HWFHPHQWUHWDLQHUDWDSSUR[LPDWHO\IW.% PLGGOHRISXSMRLQWDERYH' QLSSOH RUDVGHHSDVWKHUHWDLQHUZLOOVDIHO\GULIW &ORVHLQWKH&7[WXELQJDQQXOXVDQGOLQHXSWRSXPSGRZQWKHFRLOWXELQJ 3XPSEEOVRIGLHVHOWKURXJKWKHUHWDLQHUWRYHULI\SURSHUVHWDQGLQMHFWLYLW\ UHTXLUHGIRUFHPHQWLQJRSHUDWLRQV ESPDWSVL 3XPSEEOVIUHVKZDWHUVSDFHU 3XPSEEOVRISSJ&ODVV³*´&HPHQW,IVTXHH]HSUHVVXUHLVVHHQ EHIRUHSXPSLQJWRWDOFHPHQWYROXPHVWRSSXPSLQJDQGEHJLQQH[WVWHS 6KXWGRZQXQVWLQJIURPUHWDLQHU /D\LQUHPDLQLQJEEOFHPHQWDERYHUHWDLQHU HTXDWHVWRa¶RIFHPHQW DERYHWKHUHWDLQHUOHDYLQJ72&a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hW Z^ -6 6XVSHQG'LDJUDP ^hW Z^ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM,.....SIGN REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r` Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r"' Other:Pump OA cement shoe I� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development p' Exploratory r 202-232 3 Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20440-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380106,3801076 KRU 3S-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary Total Depth measured 8130 feet Plugs(measured) none true vertical 6176 feet Junk(measured) none Effective Depth measured 7940 feet Packer(measured) 7721 true vertical 5989 feet (true vertical) 5774 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108 SURFACE 3339 9.625 3368 2601 PRODUCTION 8087 7 8113 6159 1 Perforation depth: Measured depth: 7802'-7842' True Vertical Depth: 5853'-5893' O j i 2 8 'L 1`U Tubing(size,grade,MD,and TVD) 3.5, L-80, 7753 MD, 5805 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PACKER @ 7721 MD and 5774 TVD NIPPLE-CAMCO DS NIPPLE w/2.875"NO GO @ 498 MD and 497 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 178 7752 7334 -- 1038 Subsequent to operation shut-in 14 Attachments(required per 20 AAC 25 070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work. Oil Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG J 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-266 Contact Tyson Wiese C,265-4250 Email Tyson.M.Wiese@conocophillips.com Printed Name T son iese Title Sr.Wells Engineer Signature Phone:263-4250 Date VII, 1 v45 Ni .,T� in- -'dl4/i5 7 RBDMS, JUL - 1 2015 Form 10-404 Revised 5/2015 0 A1 7. 71Submit Original Only KUP PROD 3S-10 ' ConocoPhillips- ``' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) [m„,,,,inips 501032044000 KUPARUK RIVER UNIT PROD 53.84 2,926.87 8,130.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) --Rig Release Date 3S-10.3/1520159.37.15 AM SSSV:NIPPLE 108 6/6/2014 Last WO: 33.30 1/9/2003 Vertical schematic(actual/ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,820.0 11/15/2013 Rev Reason:GLV C/O,H2S hipshkf 3/15/2015 HANGER;24.2 '.1111111 ----- Casing S rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T7D(... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15062 30.0 108.0 108.0 6250 H-40 WELD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 292 3,368.3 2,600.8 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread PRODUCTION 7 6276 26.4 8,113.0 6,158.9 26.00 L-80 BTCM I Tubing Strings ���� Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(IL Set Depth(TVD)(...Wt(Ibttt) Grade Top Connection TUBING 3 1/2 2.992 24.2 7,752.9 5,805.2 9.30 L-80 EUE 8RD CONDUCTOR,30 0-108 0 i Completion Details Nominal ID NIPPLE,498.1 v Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 24.2 24.2 0.07 HANGER FMC GEN 5 TUBING HANGER 2.992 498.1 497.3 5.59 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 IL 7,656.6 5,710.8 12.18 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 2.812"NO 2.812 GO PROFILE / 7,704.0 5,757.2 11.61 SEAL ASSY LOCATOR SUB&PBR SEAL ASSEMBLY(SPACED 3.000 /ib riV167--* Li9 OUT 2'ABOVE FULLY LANDED) Ape -4 7,706.3 5,759.5 11.59 PBR BAKER 80-40 PBR 2.970 1 / 7,720.0 5,772.9 11.45 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 3.000 SURFACE.29.2-3.368.3 7,720.9 5,773.8 11.45 PACKER BAKER SAB-3 PACKER 3.250 7,725.8 5,778.6 11.43 EXTENSION 80-40 MILL OUT EXTENSION 3.730 7,745.0 5,797.4 11.37 NIPPLE CAMCO D NIPPLE w/2.75"NO GO 2.750 GAS LIFT.3,388.5 g- 7,7521 5,804.3 11.35 WLEG WIRELINE ENTRY GUIDE w/SHEAR OUT SUB,5"OD 3.000 iPerforations&Slots I Shot . Dens GAS LIFT;5,259.8 Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,802.0 7,812.0 5,853.3 5,863.1 C-4,3S-10 1/15/2003 6.0 (PERF 2.5"HSD PJ 7,812.0 7,8420 5,863.1 5,8926 C-4,3S-10 1/15/2003 6.0 IPERF 2.5"HSD PJ Mandrel Inserts St GAS LIFT,6,439.7II atii Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 3,388.5 2,613.4 Camco KBUG- 1 GAS LIFT DMY BK 0.000 0.0 3/11/2015 M 2 5,259.8 3,788.6 Camco KBUG- ' 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 M GAS LIFT;7.116.8it 3 6,439.7 4,600.0 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 M 4 7,116.8 5,199.0 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 M 5 7,605.5 5,661.0 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/26/2013 GAS LIFT,7.605.5 Notes:General&Safety End Date Annotation 11/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic 9.0 SLEEVE:7.656.6 1. I I I SEAL ASSY;7,704.0 P8R,7,706.3 ANCHOR.7720.0 ;i4i PACKER;7,720.9 EXTENSION,7,725.8 TUBING COLLAR.7.731 4 00 THREAD.7,732.0 l,. NIPPLE.7745.0 WLEG,7.752.0 ^ IPERF,7,802.0-7.812.0- IPERF;7,812.0-7,842.0--, PRODUCTION,26.4-8,113.0 a• 3S-10 WELL WORK SUMMARY ' DATE SUMMARY 2/18/2015 (AC EVAL) : SI TIFL (UNABLE TO PERFORM TIFL DUE TO IA-FL @ 1710'). 3/9/2015 TAG FILL @ 7829' SLM; SET 2.75" CA-2 PLUG © 7745' RKB; SET CATCHER ON PLUG © 7742' RKB. RIG DOWN DUE TO PHASE 2. IN PROGRESS. 3/10/2015 PULLED DV @ 7606' RKB; CIRCULATED 210 BBLS INHIBITED SEAWATER & 81 BBLS DIESEL, U-TUBE FOR FREEZE PROTECT; CMIT TO 2500 PSI PASSED; SET DV @ 7606' RKB. IN PROGRESS 3/11/2015 WEATHER DELAYED START; PULLED OV& REPLACED w/ DV© 3388' RKB; MITT TO 2500 PSI PASSED. 3/13/2015 PULLED CATCHER © 7742' RKB & CA-2 PLUG @ 7745' RKB. COMPLETE 5/23/2015 PUMPED 23 BBLS METHANOL DWN F/LAND TBG FROM VALVE SHELTER (JOB COMPLETE) 6/4/2015 Squeeze cement into OA shoe. Ready for DHD 6/11/2015 (AC EVAL): MITOA-PASSED © 1800 PSI. OF rot ,s THE STATE Alaska Oil and Gas 1-.--+�7. �, OfA LASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "offi1 Main: 907 279.1433 O4'ALAS' Fax• 907 276 7542 www.aogcc.alaska gov SCANNED► MAY 1 4 H015 3 �- Tyson Wiese caox- Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-10 Sundry Number: 315-266 Dear Mr. Wiese: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this L day of May, 2015 Encl. STATE OF ALASKA ` 3KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Ji 1.Type of Request. Abandon r Rug for Redrill r Perforate New Pool r Repair w ell 7' Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate E Alter casing r Other Pump OA Cement Shoe l7 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number: Development . ConocoPhillips Alaska, Inc. Exploratory r r 202-232 3.Address. Stratigraphic r• Service 6.API Number: P.0 Box 100360,Anchorage,Alaska 99510 50-103-20440-00 • 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F. t/ KRU 3S-10 • 9.Property Designation(Lease Number): 11Q3 10.Field/Pool(s). ADL 2bra4e'38O IO(o t 380/o? Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth ND(ftt Plugs(measured) Junk(measured). 8130 • 6176 - 79'it) S 9 gS i none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' SURFACE 3339 9.625 3368' 2601' RECEIVED PRODUCTION 8087 7 8113' 6159' MAY 0 77 �s / AOGCC Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade: Tubing MD(ft): 7802'-7842' . 5853'-5863' 3.5 L-80 7753 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SAB-3 PACKER MD=7721 TVD=5774 NIPPLE-CAMCO DS NIPPLE w/2.875"NO GO MD=498 TVD=497• 12.Attachments: Description Summary of Proposal pr 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development F.7. Service r" 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/20/2015 Oil 1' • Gas r WDSPL E Suspended r 16.Verbal Approval: Date: WINJ r GINJ f- WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Tyson Wiese @ 263-4250 Email: Tyson M.Wiese(o�conocophillips.com Printed Name Tyso1 Wiese Title: Walls 111111 Engineer Signature �(\VJ(Ot Phone:263-4250 Date S/9 /1;015 U Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 31c- 214 L Plug Integrity r BOP Test r Mechanical Integrity Test I— Location Clearance r Other. Spacing Exception Required? Yes ❑ No y Subsequent Form Required. /0 _ A 0 4- P901-1-46%— APPROVED BY Approved by: P / --) COMMISSIONER THE COMMISSION Date: 5'6 _/C— V7t 5-/67/5- Approved apple tion a _v lid for 12 months trom the date of approval. Form 10-403(Revised 10/2012) Sic 1 / 1- /r 0 R 1 G+ J0nttachmentsin Duplicate 11 15 I \ �y 3S-10 OA Cement Shoe Permit to Drill #: 202-232 4/30/2015 The objective of the proposed 3S-10 OA Cement shoe is to allow for pressure testing of the 7" x 9 5/8" Surface CasingAnnulus. The cement shoe willprovide a base for ConocoPhillips topressure test against, in p order to locate and estimate the size of a suspected shallow surface casing leak. An OA cement shoe was not um ed at the time of original completion in 2003. p p 9 Proposed OA Cement Shoe Procedure: Pumping Services: (OA cement shoe) IA 1 0psi, BleedOA to 0 psi. 1. Bleed to 0 2. RU 1502 X-over and hardline to the OA prior to the job. 3. RU Cement Pump Equipment.and E ui ment. PT lines. 4. Monitor Wellhead during all pumping, looking for signs of fluid returns from the conductor. 5. Pump 30 bbls of diesel to establish injectivity and ensure rates are adequate for cementing. 6. Pump 100 bbls of 90 deg F Seawater to flush the outer annulus. 7. Pump 20 bbls of CW100 to further clean up the outer annulus. 8. Pump 5 bbls of Freshwater Spacer 9. Pump 39 bbls of 15.7 ppg AS1 cement (10 bbl squeeze volume), utilizing lost circulation material to aid in supporting the 1,000' cement plug. 10. Displace the cement plug with 5 bbls of Freshwater Spacer, and 61 bbls of Diesel F.P., leaving a 1,000' cement plug in the OA. 11. Shutdown pumps and WOC for 72 hours. RDMO. DHD: (MIT-OA) 1. After WOC for at least 72 hours, perform MIT-OA to 1,500 psi. 2. If MIT-OA fails, record the estimated LLR w/diesel. Perform SCLD to locate leak. 3. RDMO. Submit 10-404 to AOGCC. TW • KUP PROD 3S-10 • ConocoPhillips " Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) Cnrocatiao, 501032044000 KUPARUK RIVER UNIT PROD 53.84 2926.87 8,130.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) •'Rig Release Date 3S-10,3/1520159:37:15 AM SSSV:NIPPLE 108 6/6/2014 Last WO: 33.30 1/9/2003 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,820.0 11/15/2013 Rev Reason:GLV C/O,H2S hipshkf 3/15/2015 HANGER',24.2 is Casing Strings -' - Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len II...Grade Top Thread CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELD Lasing Description OD(in) ID(in) Top(ftKB( Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 292 3,368.3 2,600.8 40.00 L-80 BTC _ Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULoe(I...Grade Top Thread PRODUCTION 7 6.276 26.4 8,113.0 6,158.9 26.00 L-80 BTCM Tubing Strings ! .,,^ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/t) Grade Top Connection TUBING 31/2 2,992 24.2 7,752.9 5,805.2 9.30 L-80 EUE 8RD CONDUCTOR;3oaloeo-. Completion Details Nominal ID NIPPLE;498.1 o Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com Ire) 24.2 24.2 0.07 HANGER FMC GEN 5 TUBING HANGER 2.992 498.1 497.3 5.59 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 ` 1. 1 7,656.6 5,710.8 12.18 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 2.812"NO 2.812 GO PROFILE 7,704.0 5,757.2 11.61 SEAL ASSY LOCATOR SUB 8 PBR SEAL ASSEMBLY(SPACED 3.000 [ ] OUT 2'ABOVE FULLY LANDED) 3 7,706.3 5,759.5 11.59 PBR BAKER 80-40 PBR 2.970 3 L 7,720.0 5,772.9 11.45 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 3.000 SURFACE.29.2-3.368 3- 7,720.9 5,773.8 11.45 PACKER BAKER SAB-3 PACKER 3.250 - 7,725.8 5,778.6 11.43 EXTENSION 80-40 MILL OUT EXTENSION 3.730 7,745.0 5,797.4 11.37 NIPPLE ' CAMCO D NIPPLE w/2.75"NO GO 2.750 GAS LIFT,3.388 5 7,752.0 5,804.3 11.35 WLEG WIRELINE ENTRY GUIDE w/SHEAR OUT SUB,5"OD 3.000 Perforations&Slots Shot Dens GAS LIFT,5.259 8-1 Top(ND) Btm(ND) (shetslf Top(NCB) Btu,(ftKB) (ftKB( (ftKB) Zone Date t) Type Com 7,802.0 7,812.0 5,853.3 5,863.1 C-4,3S-10 1/15/2003 6.0 IPERF 2.5"HSD PJ 7,812.0 7,842.0 5,863.1 5,892.6 C-4,3S-10 1/15/2003 6.0 IPERF 2.5"HSD PJ Mandrel Inserts st GAS UFT;6,439.7 ah Ott Top(TVD) Valve Latch Port Size TRO Run N Top(RKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com - -I 3,388.5 2,613.4 Camco KBUG- 1 GAS LIFT DMY BK 0.000 0.0 3/11/2015 M 2 5,259.8 3,788.6 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 M GAS LIFT;7,116.6III 3 6,439.7 4,600.0 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0'1/8/2003 M 4 7,116.8 5,199.0 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 ' M 5 7,605.5 5,661.0 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/26/2013 GAS LIFT;7605.5 -• Notes:General&Safety End Date Annotation ' 11/1/2009 NOTE'.VIEW SCHEMATIC w/Alaska Schematic 9.0 1 I SLEEVE;7,656.6 SEAL ASSY;7,704.0 P56;7,706.3 L-g ANCHOR;7,720.0 tJ PACKER;7,720.9 EXTENSION;7,725.8 TUBING COLLAR;7,731.4 X0 THREAD;7,732.0 NIPPLE;7,745.0IFAI WLEG;7,752.0111 (PERF:7,802.57.612.0- (PERE;7,812.0.7,842.0 PRODUCTION;26.4-8,113,0 I Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, February 17, 2015 7:45 AM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Kuparuk gas lifted producer 3S-10 (PTD# 202-232) Reported with sustained inner casing pressure above 2000 psi. Attachments: image001.png; 3S-10 Schematic.pdf; 3S-10 90 Day TIO plot.JPG Chris and Jim Kuparuk gas lifted producer 3S-10(PTD# 202-232)was reported with sustained inner casing pressure above 2000 psi. The well was shut in on the 1st of Feb 2015 and has remained shut in since then. The well has 7" 26 lb L-80 casing with a burst rating of 7240 psi. The IA was found at 205 psi which does not exceed 45%of the burst rate. The plan forward is to conduct diagnostic work utilizing slick line, a-line and/or DHD until the source of high IA pressure is identified and mitigated. If the source of pressure cannot be identified the well will be secured and a plan for corrective action will be formulated. Depending on the outcome of the intervention work, the appropriate notifications will be submitted. Please let me know if you disagree with this plan. Attached are a well bore schematic and a 90 day T/I/O plot. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 SCANNED MAR 0 4 2015 Cell phone: (907) 943-0450 WELLS TEAM conocoPniNips om: NSK Problem Well Supv Sen ridgy, October 31, 2014 1:59 PM To: Wal Chris D (DOA); Regg, James B (DOA); guy.schwartz@alaska.gov Cc: Senden, . ler; NSK Problem Well Supv Subject: Kuparuk g i ed producer 3S-10 (PTD# 202-232) Reported with sustained inner casing pressure above 2000 psi. Jim, Guy and Chris, Kuparuk gas lifted producer 3S-10(PTD# 202-232) was reported with sustained inner casing pressure above 2000 psi. The well was shut in on the 28th of Oct 2014 and has remained shut in since then. The well has 7" 26 lb L-80 casing with a burst rating of 7240 psi. The IA was found at 2160 psi which does not exceed 45%of the burst rate. DHD performed a failing TIFL today confirming the need for well intervention work. The plan forward is to conduct diagnostic work utilizing slick line, a-line and/or DHD until the source of high IA pressure is identified and mitigated. If the source of pressure cannot be identified the well will be secured and a plan for corrective action will be formulated. Depending on the outcome of the intervention work,the appropriate notifications will be submitted. Please let me know if you disagree with this plan. Attached are a well bore schematic and a 90 day T/I/O plot. KUP PROD 3S-10 conocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) Lnrxa,Prampt 501032044000 KUPARUK RIVER UNIT PROD 53.84 2,926.87 8,130.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3S-10,2/6/20142:1840 PM SSSV:NIPPLE 160 12/13/2012 Last WO: 33.30. 1/9/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 77,820.0 11/15/2013 Rev Reason:PULLED PLUG AND CATCHER lehalif 2/6/2014 - ---a Casing Strings HANGER;24.2- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft)(5) Set Depth(TVD)...Wt/Len(I...Grade Top Thread r CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELD � m Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade -Top Thread SURFACE 95/8 8.835 29.2 3,368.3 2,600.8 40.00 L-80 BTC Casing Description 'OD(In) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 26.4 8,113.0 6,158.9 26.00 L-80 BTCM Tubing Strings Tubing Description String Ma...ID(in) Top)ftKB) Set Depth(k..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection ._ + TUBING 31/2 2.992 24.2 7,752.9 5,805.2 9.30 L-80 EUE 8RD Completion Details CONDUCTOR;30.0-108.0 • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl('I Item Des Com (In) NIPPLE.,499.1 8 24.2 24.2 0.07 HANGER FMC GEN 5 TUBING HANGER 2.992 !1498.1 497.3 5.59 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 [ - 1 7,656.6' 5,710.8 12.18 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 2.812"NO 2.812 GO PROFILE 7,704.0' 5,757.2 11.61 SEAL ASSY LOCATOR SUB 8 PBR SEAL ASSEMBLY(SPACED 3.000 l OUT 2'ABOVE FULLY LANDED) J 7,706.3 5,759.5 11.59 PBR BAKER 80-40 PBR 2.970 �. 7,720.0 5,772.9 11.45 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 3.000 SURFACE;292-3,368.3--I l 7,720.9 5,773.8 11.45 PACKER 'BAKER SAB-3 PACKER 3.250 7,725.8 5,778.6 11.43 EXTENSION 80-40 MILL OUT EXTENSION 3.730' 7,745.0 5,797.4 11.37 NIPPLE CAMCO D NIPPLE w/2.75"NO GO 2.750 GAS LIFT;3,388.5 7,752.0 5,804.3 11.35 WLEG WIRELINE ENTRY GUIDE w/SHEAR OUT SUB,5"OD 3.000 Perforations&Slots Shot Dena aTop(TVD) BM(TVD) (ohotan GAS LIFT;5,259.8 Top(ftKB) Btm(ftKB) (f/KB) (ftKB) Zona Date 9 Type PJCom 7,802.0 7,812.0 5,853.3 5,863.1 C-4,3S-10 1/15/2003 6.0 IPERF 2.5"HSD 7,812.0 7,842.0 5,863.1 5,892.6 C-4,3S-10 1/15/2W3 6.0 IPERF 2.5"HSD PJ Mandrel Inserts St ati C Non o Top(TVD) Valve Latch Port Size TRO Run GAS LIFT,6,439.7ri Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 3,388.5 2,613.4 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 11/15/2013 M i--' 2 5,259.8 3,788.6 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 M ' 3' 6,439.7 4,600.0 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 ILEM GAS LIFT;7116.a 4 7,116.8 5,199.0 Camco KBUG- ' 1'GAS LIFT DMY BK-5 0.000 0.0 1/8/2003 M 5' 7,605.5 5,661.0 Camco MMG ' 11/2 GAS LIFT DMY RK 0.000 0.0 11/26/2013 Notes:General&Safety ' ' End Date Annotation GAS LIFT;7605.5 11/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic 9.0 I SLEEVE,7.856.8 1. '-I SEAL ASSY,7,704.0 PBR;7,706.3 ANCHOR;],]20.0 • • PACKER;7,7209 TTT I EXTENSION;7,7258 TUBING COLLAR;7,731.4 XO THREAD;7,7320 NIPPLE;7,7450 WLEG;7,752.0 IPERF,7,8020-7,8120- II IPERF,7,812.07,842.0-. I PRODUCTION;26.4-8,113.0 • W oo 2 1c a! 111 LU U Z Z Lel O O W m O tY .t m a e O no o O CL r 4-- 17 a o u x u W I f/! O O U.S CO CO Ce S Ol de r N VI kr) O O W N N 2 =tN p 7 N CV 0 1 0 0 5 n Q ,d6ap 0 CI n CO 0 -,ot oU f 1 f I f 1 `w o I 1 1 I 1 I ) r...., 1 V, Ui wy LL W V C ai Z cn cn < { C i U Y R r w HLL ---"'o Z C a V CI; C, n Cii l'Ir- c: a o • CA CD. Cv i > ? 2 �'' ."'�� tsQ I I f 0 1 a 10 a o 0 0 0 �0 I R I P S ` o _ ❑ 0 N N as is VIM �} v1C W ISd r Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 ~- ~9~ Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 ~can Needed OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner RESCAN t~Olor Items: o Greyscale Items: DI~AL DATA ~.z( Diskettes, No. I o Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: Helen ~ o Other:: " Date: '-f 5" OS- :J 151 VV1 Project Proofing I BY: Helen ~ Date:!.j- ð OC$'" 151 vvvP Scanning Preparation s x 30 = /~~O + ~ (P = TPTAL PAGES J 5~ (COunt./dp~. er .n~Ynclude cover sheet) mP Date: '-¡- ó¡ ÓÕ 151 / I BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: IS 7 (Count does include ~r sheet) Page Count Matches Number in Scanning Preparation: V YES Helen ~ Date: 4-/b/DS If NO in stage 1, page(s) discrepancies were found: YES NO BY: NO /s/ rvvP Stage 1 BY: Helen Maria Date: 151 Scanning is complete at this point unless rescanning is required. 11111111111111 "III ReScanned III BY: Helen Maria Date: 151 Comments about this file: Quality Checked 11I1111111111111111 • Page 1 of 1 Regg, James B (DOA) .~ ~._~ ,~~~m~,~_ ~ _ __ _ . From. NSK Problem Well Supv [n1617@conocophillips.com] r ~ ~~ Z't?'~ Z3Z Sent: Saturday, July 24, 2010 1:52 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Smith, Travis T Subject: 3S-10 (PTD# 202-232) Report Of TxIA Communication Attachments: 3S-10 Wellbore Schematic.pdf; 3S-10 TIO Plot.pdf Jim/Tom/Guy, Kuparuk gaslifted producer 3S-10 (PTD# 202-232) is exhibiting signs of TxIA communication while shut in. Subsequent to being shut in, the IA pressure increased to 2375 psi. The well is equipped with 7", 26 ppf, L-80 production casing with a calculated internal yield pressure of 7240 psi. An IA pressure of 2375 /psi represents less than 33% of the burst pressure rating of the production casing which is below th limit set forth in C0494. A gaslift valve is the suspected source of communication, so slickline will troubleshoot and repair if possible. The well will be a e o e SCP report and will be fixed by 8/19/10 ~% or remain SI. "--' Attached are a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 '., 8/10/2010 P~J z.~Z- Z~ ,Z Well Name 3S-10 Notes: End Date 7i30i2010 Days 120 Start Date 4 1 '2010 Annular Communication Surveillance 2500 WHP _ _ ----- _. ------- 160 IAP _ OAP _ _ WHT yA 140 2000 i i 120 ll '~ 100 1500 LL 80 ~ Q ~VN'T 1000 60 40 500 - 1~ 20 i ~`~ ! 0 ~ :~pr-10 May-10 Jun-10 Jul-10 ~~ DGI _.~~.. -oor ,~MGI i eoo~ ° ~PWI ~ 5000 m "~SWI 0 40 ~BLPD ~ 3000 _. _. - _. _ _ I ' 2000 ; 1000 - 0 • • __ _ / ~ -_ , KUP 3S-10 COtlOCOP~'lll~t~'35 _ l ~ Well Attributes _ aX Angle & MD ~ TD Welibore APIIUWI _ _ Field Nama _ ,_ ___„_ Well status Intl (j 1.1D (ttKB) .:~t Btm (tiHB( '~`I' ~~ 501032044000 KUPARUK RIVER UNIT PROD 53.84 2,926.87 8,130.0 Comment H2S (ppm) Date Annotation End Date KB{3rtl (R) Rig Release Date "' SSSV: NIPPLE 220 1/6Y2008 Last WO: 33.30 1/9/2003 Well GOnf -35-10. 11f12009224.23 PM Schemane~na~al ~~----- -- Annum i^~ Depth (ttKB) End Date Annotation Lasf Mod ... End Date Last 1 , 7 .937.0 10/17/2009 Rev Reason: TAG Imosbor 11/1/2009 Casinc Strin s ~ ~ - -- - Casir,iy Uesciption String 0... String ID ... Top (ttKB) Se[ Depth (f... Set Depth (TVD) .- String Wt... String ... Scnng Top Thrtl ~~~I"`-' ~ _ 'i: CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELD HANGER, 24- - .-,; ~ ~ "~- I ~ ;, ~" Casing Description String 0... String ID ... Top (ttKB) Sat Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd , SURFACE 95/8 8.835 29.2 3,368.3 2,601.4 40.00 L-80 BTC _ Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ~ ~ PRODUCTION 7 6.276 26.4 _8,113.0 6.158.9 26.00 L-80 BTCM Tubing Strings _ _ . Tuhing Descripdon String 0... i 5[r g ID ... _ !Top (RKB) Set Depth (f... Set Depth (ND) . S[ ing Wt... St ng ... String Top Thrd ~ _ TUBING I 3 1/2 ! 2 992 9.30 L SP I 24.2 7,752.9 ~ 5,805.2 ~ FI IF ARr1 f ~~ ~ ils Com letion Deta _ _ _ _ t ~ Top Depth _ __ _ CONDUCTOR. ~ (ND) Top Intl 30-108 ~ Top (RKB) (RKB) (°) Item Description Comment ID (in) 24.2 24.2 -0.53 HANGER FMC 3 1/2" GEN 5 Tbg Hanger w/ 3-1/2" tbg. Pup (2.55') on btm 2.992 NIPPLE, 498 { ~ ggg,1 497.3 5.59 NIPPLE 3.5" Camco"DS" Nipple w/2.875" NO GO 2.875 7,656.6 5,710.8 11.66 SLEEVE 3.5" Baker CMU sliding sleeve w/Camco 2.812" no go profile, EUE 8RD 2.812 ~_ ~ h; 7,704.0 5,757.2 11.50 SEAL ASSV Locator Sub 8 PBR Seal Assembly (Spaced out 2' above fully landed) 3.000 ~.. ! ~ 7,706.3 5,759.5 11.49 PBR Baker 31/2" 80-40 PBR 2.970 i' 7,720.0 5,772.9 11.45 ANCHOR KBH-22 Anchor Tubing Seal Nipple 3.000 E 7,720.9 5,773.8 11.45 PACKER 3 1/2 x 7" Baker SAB-3 Packer 5.956" OD x 3.25" ID 3.250 ~ c ~ 7,725.8 5,778.6 11.43 EXTENSION 4-1/2" 80-40 Mill out Extension 3.730 suRFACE,~ q ~ 7,732.0 5,784.8 11.41 XO X/03-1/2'X4-1/2" 2.992 29-3.369 --- -' 7,745.0 5,797.4 11.37 NIPPLE 3.5" Camco"D" Nipple w/2.75" NO GO 2.750 i 7,752.0 5,804.3 11.35 WLEG 3 1/2"WLEG with Shear out Sub 5" OD 3.000 GAS LIFT. t -~-. ____ _. _.. _ - _. _. _-__ GAS GAS LIFT, 6,440 GAS LIFT, 7,177 GAS LIFT, 7,fi06 SLEEVE, 7,657 REAL ASSV, 7,704 PBR, 7.706 ANCHOR, 7,720 PACKER, 7,721 EXTENSION, 7,726 TUBING COLLAR, 7,731 XO, 7,732 NIPPLE, 7,745 WLEG, 7,752 IPERF, , 7,802-7,812 IPERF, , 7,812-7,842 Pertorations_8 Slots ___ ___ ~__ ' Too INDI Btm 1ND1 ~ ~ Dens I I - Notes: General & l X .~-. ~!+ L _i _ _'" Y.. .. . J ~ ~-- '~ ~~ I i .~ ~_ , ~~ -. _-_-..rY. --i i 1 ~1,'li II ~, 1 ' _J l "1 f- ~II '4 '~ _`~ -~ Details Top Dei, (ND Zone I Date Port OD TI~Valve Latch Size TRO RUn Iinl Sarv ~I TYPa TYPe lin) (Pa0 PRODUCTION, 26-8,113 TD, 8,130 Scblumbepgep NO. 4054 Schlumberger -DCS 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1\\ ')0\,',11'. 'I' .'JJ nÎ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ()Qé) - ~6 d Field: Kuparuk Well BL Color Log Description Date Job# CD 11/28/06 . 3B-13 11415652 PROD PROFILE W/DEFT 11/16/06 1 35-07 11502019 SBHP SURVEY 11/19/06 1 3S~10 11502020 SBHP SURVEY 11/19/06 1 1 E-24A 11502021 SBHP SURVEY 11/20/06 1 1 Y -23 11502022 PROD PROFILE WIDEFT 11/23/06 1 1 H·17 11502023 SBHP SURVEY 11/24/06 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-09 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25/06 1 Please sign and return one copy ofthis transmittal to Beth atthe above address or fax to (907) 561-8317. Thank you. ~ ê -ft-- . . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 99501 .~,,~ ,:'t.~¡~;:'':~ ~ l¡¡:illiO ".' >0:....>-', ¡J b cl D;}.- g..Õ ~ '"35-10 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 of2.5 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 irlhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~f~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Schlumberger NO. 3429 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 07/08/05 ~tJ~~~ðð- Î""fì~ =', ',:.;.ç._y 0 ß LU\)J sCANNt;.L H ~ Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL ,/ 2G-02 If¡ '-( -i).. f 11047334 BHP SURVEY 06/30/05 1 , 2G-13 I~ ~i - i J. ", 11047336 BHP SURVEY 07/01105 1 )_ 2G-11 I~·., -i ('] 11047337 BHP SURVEY 07/01/05 1 y 1Y-14)3~~ 01\ 11022907 LEAK DETECTION LOG 06/30/05 1 :j 3H-19/8"7 'P(JJ 11022907 PRODUCTION PROFILE 06/28/05 1 \/, 1J-03 ,~Gí - C;" 'f 11022893 PRODUCTION PROFILE 06/17105 1 .) 1 L-09 /tíO·· ~ j <( 11022895 PROD PROFILE W/DEFT 06/19/05 1 ,ii. 3S-10 .). t/).. - 13l. 11001235 PROD PROFILE W/DEFT 06/14/05 1 ) 3F-04 iJ:J" )...),8 11022891 INJECTION PROFILE 06/15/05 1 1Y-26A ¡ ~~J'II ~ 11022892 PROD PROFILE W/DEFT 06/16/05 1 ;.I1E-112)(¡\..j-Ü'11 11047339 INJECTION PROFILE Ul{.. 07/03105 1 ..i 1 E-1 02 ).. \; '-1 ~ ;J,J I 11047340 INJECTION PROFILE \.;iC 07104/05 1 SIGNED: l-);/ (, ~~ 'J " DATE: I. f tJdlj Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color --~ CD _/ ''\ ~' )/ ·à,..... <':- _ -.,--' - ( :¿~ J---" 5~h~ ~ú-o ~ DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022320 Well Name/No. KUPARUK RIV UNIT 3S-10 Operator CONOCOPHILLlPS ALASKA INC Ç'1 vte!. ...4 ~ ~ ~.:4 AP'j ~o. 50-103-20440-00-00 MD 8130 TVD 6176 Completion Date 1/5/2003 Completion Status 1-01L -----.------ ---- -------.- REQUIRED INFORMATION Mud Log No Samples No --~-~--- --- ------- ------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes. Dens/Neutron Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ ------------- ,ED 0 11686 LlS.JiféiÏfication r",-~ir/4fl- Log Log Run Scale Media No 1 2 5 Blu 2 Rpt- "'-,·LlS Verification L.<Q.g..--/ ' Rpt L- ,ED 0 42ertõration ~trectional Survey 11686 LI.§.-Y~ion r r'ô t / I~ ~ 0 £..ßirectional Survey .... ~og..·-_....-" ~{)dÜction Blu :~~t LIS V~rifir.a.tion _1~~1I'c~,1 I i Log Temperature k?~// C __~~~_ 12598 Gamma Ray {/O- Well Cores/Samples Information: Blu Name Interval Start Stop Received Sent Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 3348 8098 Open 4/17/2003 REPLACED BY NEW DATA RCVD 07/24/2003 3348 8098 Open 7/24/2003 REPLACES DATA RCVD 04/17/2003 7550 7937 Case 217/2003 0 8130 Open 2/5/2003 3348 8098 Open 7/24/2003 REPLACES DATA RCVD 04/17/2003 0 8130 Open 2/5/2003 3000 7835 Case 5/8/2003 33"12 3000 7835 Case 5/8/2003 3377 8130 Open 4/23/2004 MWD, DGR, CNP, SLD Sample Set Number Comments '-' -,~, DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022320 Well Name/No. KUPARUK RIV UNIT 3S-10 Operator CONOCOPHILLlPS ALASKA INC MD 8130 TVD 6176 Completion Date 1/5/2003 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? '¥-+-N-" Daily History Received? &'N &N Formation Tops Analysis Y / N Received? --- -------------- -- ---- --~-- ------- Comments: Compliance Reviewed By: \ \ r Date: API No. 50-103-20440-00-00 UIC N -- - if M6'- 2.G~S-- ',--,# ') r '~ ~(!;) z. - J- :3 Z- /¿S-7 ¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 20, 2004 RE: MWD Formation Evaluation Logs 3S-10, AK-MW-22206 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 38-10: Digital Log Images 50-103-20440-00 1 CD Rom ch,~ !t~/o1 !If RECEIVED þ,PR 2 3 2004 Alaska Oil & Gas Cons. Commission Anchorage 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003/1st 21104 2003 / 2nd 9972 2003 / 3rd o 2003 / 4th o Total Ending Volume (bbls): 31076 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Printed Name: Form 10-423 Rev. 9/2003 D or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 100 100 o o 200 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 303-033 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/11/2003 Volume (bbls): Number of days disposal occurred 388* 388 0 21204 0 10072 0 0 0 0 26 388 31664 ' 39 Pressure vs. Time D Step Rate Test D Date: Title: D t-l J "\ EO...._ l...e~.Á * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~"\i:;-~_ Kc." ,'; ì ~ 0 ,..-~ f INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-232 38-10 50-103-20440-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 3/4/2003 3/31/2003 38-21,38-08 13 4/1/2003 4/13/2003 38-21, 38-23 o o '''- 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 I ó ý' Phone Number: '2- b ç-' 6-£> S 0 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 388* 388 21104 100 0 21204 26 3/4/2003 3/31/2003 38-21 38-08 9972 100 0 10072 13 4/1/2003 4/13/2003 38-21, 38-23 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 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 303-033 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/11/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 1 st 2003 / 2nd 2003/3rd 2003 / 4th Total Ending Volume (bbls): 31076 200 388 31664 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Step Rate Test 0 * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~. ~'-\. -L) \-L~ "-...c... " Signature: Date: t)c-l.5 \- e.-._ ~ Printed Name: Title: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-232 38-10 50-103-20440-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ..~. ..,.~ 39 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. \ (?-{, (0'( Phone Number: urb~SC) Submit in Duplicate ) y ConocoPhillips 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 ) I?~CI2II i _ I " VJ;..,'"h I..' 'lJ A . . O;~ 'V~k( Ql' . . 200J GaSCbI1. ~, 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. ;ø; ~~( MJZ / ConocoPhillips Problem Well Supervisor Attachment :t:.\- '\ ~ t'<)~ <t ~,~(""\.~" ~,,-<t ~"'\-. +0 Cr ~\\ 'o~c-~" cA-~~ ~~~~ '>~<!:.. ",~r.ù \\..../ ~<t.. <"'-«- "'~~ -\0 S<,.)~. 14\\ o~+~ "TÖ<:'" ~-\-'"'S~~ \'::)~'"'1 U\Q..G\ +,",-<ë. S'-..)~~. \--..Jo.Ç.ù,4-~<L' <:1.<:.."\\0,"" t'\<"l...ct.~~''i. ft-)!.¥?\~ Á - ö ~ .,.' ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well Toe Volume Sacks Name PTD# Type ft BBLS Cement 3S-03 2030910 Prod 8 0.6 3.6 3S-07 2021870 Prod 8 1.5 9.1 3S-09 2022050 Inj 14 2.5 15.1 3S-10 2022320 Prod 12 1.5 9.1 3S-14 2022210 Inj 3 1.5 9.1 3S-15 2022540 Prod 8 0.8 4.8 3S-17 A 2030800 Prod 12 1.1 6.6 3S-18 2022060 Prod 10 1.1 6.6 3S-19 2030960 Prod 5 1.1 6.6 3S-21 2030310 Inj 5 0.5 3.0 3S-22 2030110 Inj 7 0.9 5.4 3S-23 2030450 Prod 2 0.3 1.8 ) \, ~ WELL LOG TRANSMITTAL ?D2. -2..ò:L ((CoSb To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 03, 2003 RE: MWD Fonnation Evaluation Logs 38-10, AK-MW-22206 1 LDWG fonnatted Disc with verification listing. API#: 50-103-20440-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVED Date: Signed: ~~ JUL 24 200·3 AtSeK!10H & Gas Cons. Commi98ion AnchOftY:Jß Note: This Data Replaces Any Previous Data For "Veil 38-10. TU BING (24--7753, 00:3.500, 10:2.992) SEAL (7704-7706, 00:5.870) Anchor Nipple (7720-7721, 00:4.740) PACKER (7721-7726, 00:5.956) Perf (7802-7812) Perf (7812-7842) ~OOUCTION (26-8112, 00:7.000, Wt26.00) Cøno(:oPhiIUpIAlaka, 'nç~ -- [] ]. ~~-Ii I JIi:. .,. ](1: 7)11 i~: fI ]:··I:;r, III'. : "':" :; : .~~ . ~. -I¡:.' __.... ,1/. . .". . 1 ilf· ..,.::. -- .-. i j: [.; "', ~ ,·········'1,1 ) "3; j ~Od ~.~ ø( 3S-10 API: 501032044000 SSSV Type: NIPPLE Well Type: PROD Orig Completion: Last W/O: Annular Fluid: Ref Log Date: TO: 8112 ftKB Max Hole Angle: 0 deg @ Top 26 28 28 Bottom 8112 3368 108 Bottom 7753 TVD 7753 Wt 9.30 V Mfr V Type V OD Latch DMY DMY DMY DMY DMY 1.0 1.0 1.0 1.0 1.5 Description FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' NIPPLE WINO GO PROFILE BAKER CMU W/2.812" NO GO PROFILE LOCATOR SUB & PBR SEAL ASSEMBLY BAKER 80-40 PBRISBR BAKER KBH-22 ANCHOR TUBING SEAL NIPPLE 7721 7721 7726 7726 7745 7745 7752 7752 8112 8112 General Notes Date Note 1/8/2003 TREE: FMC I GEN 5 I 5M TREE CONNECTION: TOP 5.75" ACME W/3.5" EUE 8RD THREAD KRU 35-10 Angle @ TS: deg @ 7803 Angle @ TO: deg @ Rev Reason: NEW WELL, PERF, TAG, set DMY Last Update: 1/16/2003 TVD 8112 3368 108 I Grade I L-80 Port TRO BK-5 BK-5 BK-5 BK-5 RK 0.000 0.000 0.000 0.000 0.000 Reference Log: 24.18' RKB Last Tag: 7930 Last Tag Date: 1/14/2003 Casing String - ALL STRINGS Description Size PRODUCTION 7.000 SURFACE 9.625 CONDUCTOR 16.000 Tubing String - TUBING Size I Top 3.500 24 Periorations Summary Interval I TVD I Zone I Status 1Ft SPF I Date I Type I Comment 7802 - 7842 7802 - 7842 C-4 40 6 1/15/2003 IPERF 2.5" HSD PJ Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 3389 3389 CAMCO KBUG-M 2 5260 5260 CAMCO KBUG-M 3 6440 6440 CAMCO KBUG-M 4 7117 7117 CAMCO KBUG-M 5 7606 7606 CAMCO I'vTv1G Other (,lugs, equip., etc.' - JEWELRY Depth TVD Type 24 24 HANGER 498 498 NIP 7657 7657 SLEEVE 7704 7704 SEAL 7706 7706 PBR 7720 7720 Anchor Nipple PACKER BAKER SAB-3 PACKER EXTENSION BAKER MILL OUT EXTENSION NIP CAMCO '0' NIPPLE W/2.75" NO GO PROFILE WLEG BAKER SHEAR OUT SEAT SHOE 7" WEATHERFORD SURE-SEAL MODEL 303 FLOAT SHOE Wt 26.00 40.00 62.50 Grade L-80 L-80 H-40 Thread BTCM BTCM WELD Thread EUE8RD o o o o o Date Run 1/8/2003 1/8/2003 1/8/2003 1/8/2003 1/14/2003 Vlv Cmnt ID 3.500 2.875 2.812 2.970 2.970 2.993 3.250 3.730 2.750 3.000 6.151 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job # Log Description Date BL 35-21 ~(\.1--0~~ I 5BHP SURVEY 04/18/03 1 1B-08A I q 7-1J.. I INJECTION PROFILE 04/17/03 1 35-09 ~~~OS INJECTION PROFILE 04/07/03 1 35-10 dDa- 3 Ö) PRODUCTION PROFILE 04/08/03 1 1G-13 ~3-I<./O PRODUCTION PROFILE 04/09/03 1 35-21 t~3-( 31 5CMT 04/18/03 1C-174 ~3-~Î 23113 U51T 04/01/03 1 G-03 J 'd.-/4'1 INJECTION PROFILE 04/24/03 1 1 C-135 ó< LJ/ - ~~n PRES5ITEMP SURVEY 04/23/03 1 SIGNE~mÚ~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 05/05/03 NO. 2765 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color -,. CD 1 1 '-' RECEIVED ~ItA Y 0 8 2003 PJaska OH & Gas Cons. Commi5S00 AnchOf!Qe ;;g~ -e3 0- Annular Disposal during the second quarter of2003: 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 lC-190, lC-174, lC-178, lC-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 lC-184, lC-170, lC-172 3S-0SB 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 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-38 ID-1I 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 ID-I03 IC-IS 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-l 04 ) ) , ~ Dd--d~ } lin tç, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Aprilll, 2003 RE: MWD Formation Evaluation Logs 38-10, AK-MW-22206 1 LDWG formatted Disc with verification listing. API#: 50-103-20440-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ Signed:(~~ ~ RECEIVED APR 1 -( 2003 Alaska OH & Gas Cons. Ccmmimon Anchorsge Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-l8 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 J an 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-l7 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CD2-36, CD2-51 (' 2003 3S-l0 21104 100 0 21204 388 0 21592 March March 3S-21,3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 Total Volumes into Annulifor which DisposalAuthorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 2002 2P-4l5A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October 2002 2002 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 Source Wells 2P-427, Heavenly CD2-13, CD2-37, CD2- 35 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-38, CD2-44, CD2- 29, CD2-13 CD2-50, CD2-46, CD2- 22 (' ~ECEIVED APR 1 6 Z003 Qj o Q.; , 9J LN ~ Alaska Oil & Gas Cons. Commission Anchorage 0 Y) Œ Annular Disposal during the first quarter of 2003: I ð 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 15 Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 \ CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2.;08, CD2-36, CD2-51 t j." 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21,3S-08 2003 2003 1 C-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during thefirst quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 \. 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, l 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 ~ ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 February 12, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-10 (APD # 202-232) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations for the Kuparuk well 3S-1 O. 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 ..-<.,.....,. î ._ .~~', þ 1'\ ~: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of well Classification of Service Well Oil 0 Gas D 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D :. . .Abandorred,·;D I ' ;' . :'\ '~ . " c ~ r~'.", " );'i'(E. ¡ I·IÇ·P~,.¡; Service ~; fi'W.; f '~.'\:.".'dIIir.·-~ {~~U~¡)' V~ §j, .. " ., ¡,to "~IS$ '~\ t···- '.. .\~ ~~:;.~,,;::~:; #,....r (ASP: 476266, 5993915) 7. Permit Number 202-232 I 8. API Number 50-103-20440 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3S-10 11. Field and Pool Kuparuk River Oil Pool Kuparuk River Field ~ ,.' F: P ; r:;1 t,: ~"¡', :i~,.i.! , ,~.~':-::-;:'~=J:=~~' ~ 2501' FNL, 993' FEL, Sec. 18, T12N, R8E, UM At Top Producing Interval 1694' FSL, 1044' FWL, Sec. 8, T12N, R8E, UM At Total Depth 1746' FSL, 1060' FWL, Sec. 8, T12N, R8E, UM (ASP: 478332, 5998155) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 28 feet ADL 380107 I 380106 ALK 4624 I 4623 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. December 28,2002 January 5,2003 JanuarØ:2003,;!D 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 8130' MD 16176' TVD 7940' MD I 5989' TVD YES 0 No D (ASP: 478301, 5998103) 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set Land Nipple @ 498' 16. No. of Completions 21. Thickness of Permafrost 1670' MD 22. Type Electric or Other Logs Run GR/Res, Dens/Neutron 23. CASING SIZE WT. PER FT. 30" X 16" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3368' Surface 8113' HOLE SIZE CEMENTING RECORD AMOUNT PULLED 42" 81 sx ArcticCrete 8.5" 570 sx AS Lite, 300 sx LiteCrete 250 sx Class G w/GasBlok 12.25" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 7753' PACKER SET (MD) 7721' 7802' - 7842' MD 5853' - 5893' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 17, 2003 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 1/30/2003 7.5 hours Test Period> 1749 1829 0 95% 1211 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (carr) press. 285 psi not available 24-Hour Rate> 5139 6223 0 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A l1'~ ,:~" r~~~ ;c I I'~ ·~I~ ,....( -' ,~-, . I) '" (' ~ l) 'v- Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Fr-P I 9 200? Submit in duplicate RBOMS BFL 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include intelVal tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Kuparuk Base Kuparuk 7803' 7841' 5854' 5892' Annulus left open - freeze protected with diesel. E 'IE 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869 Signed~ l ~ R. ThJnas Title Kuparuk Drilling Team Leader Date ¿/()( ~.5 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 "ì ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-10 3S-1 0 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Description of Operations Spud Date: 12/28/2002 End: Group: · Sub prom - To Hours Code COde 12/27/2002 17:00 - 18:00 1.00 MOVE DMOB MOVE PJSM on rig move. RID service lines to pits. Jack up and move pit module out of way. 18:00 - 19:30 1.50 MOVE MOVE PJSM. Jack up & move sub base f/3S-14 to 3S-10 (80'). Spot sub over well. Set mats 19:30 - 20:30 1.00 MOVE MOVE Move in & spot Pit complex. Hook up support lines. Start receiving water @ 2100 hrs. 20:30 - 22:30 2.00 MOVE MOVE Lay herculite for ball mill. Move ball mill. Spot in place. 22:30 - 23:30 1.00 MOVE MOVE Lay herculite and plywood fl injection skid. Move and spot injection skid. 23:30 - 00:00 0.50 MOVE MOVE NU 20" diverter system. Install riser. Torque bolts on diverter while installing first section of 16" diverter line. Rig acccepted @ 2300 hrs 12/27/02 12/28/2002 00:00 - 03:00 3.00 WELCTL NUND RIGUP NU 20" diverter system, build berms around rig, mixing spud mud. 03:00 - 06:00 3.00 DRILL PULD RIGUP Mix spud mud. Bring bit, stab, and x-o to rig floor. DC's are in pipe shed. 06:00 - 07:00 1.00 DRILL OTHR RIGUP Rig down Kelly hose. Ice plug in middle of hose. Steam both ends to thaw plug. Re-install kelly hose. 07:00 - 08:00 1.00 DRILL OTHR RIGUP PJSM wI HOWCO slickline. RU wireline sheave in derrick to use HOWCO fl gyro WL. Sperry Sun gyro hand. 08:00 - 08:30 0.50 WELCTL BOPE RIGUP Perform diverter test. Function test knife valve and hydril. Test accumulator. Witness of test waived by AOGCC rep John Crisp. 08:30 - 09:30 1.00 DRILL OTHR RIGUP Pressure test mud line to 3500 psi to test kelly hose. Fill stack, check fl leaks. 09:30 - 10:00 0.50 RIGMNT RGRP RIGUP Air boots on riser leaking. Increase air pressure on air boots fl riser. 10:00 - 13:00 3.00 DRILL PULD RIGUP PU BHA # 1. Stand back in derrick stand of DC's. MU BHA # 1, orient tools. 13:00 - 15:00 2.00 DRILL DRLG SURFAC Directional drill 12 1/4" hole f/108' to 166'. ART = .5 hrs AST = .5 hrs (Bit balling up while sliding) 15:00 - 15:30 0.50 DRILL SURV SURFAC Gyro survey @ 166' wI HOWCO slick line and Sperry Sun survey equipment. 16:30 - 17:30 1.00 DRILL DRLG SURFAC Directional Drill 121/4" hole f/166' to 346 (180') ART = 1.25 hrs AST = 2.0 hrs Drill wI 8-20 WOB, 85 RPM, MM 63-82 RPM, 425-548 gpm, 1050 psi, torque on bttm 1000 ftllb, torque off bttm 900 ftllb *** Approx 1.5 hours spent trying to unball bit. Add lubricants, & walnut hulls to mud. 19:30 - 20:00 0.50 DRILL SURV SURFAC Gyro survey @ 346' wI HOWCO slick line and Sperry Sun survey equipment. 20:00 - 23:30 3.50 DRILL DRLG SURFAC Directional Drill 12 1/4" hole fl 346' to 710' (346') ART = 1.25 hrs AST = 1.75 hrs Drill wI 10-25 WOB, 85 RPM, MM 63-82 rpm, 425-548 gpm, 1050-1720 psi, torque on bttm 1000 ftllb to 4000 ftllb, torque off bttm 1000 ftllb 23:30 - 00:00 0.50 DRILL OTHR SURFAC RID HOWCO wireline sheave in derrick. RID HOWCO. RID Sperry Sun survey tools. 12/29/2002 00:00 - 12:00 12.00 DRILL DRLG SURFAC Directional drill 12 1/4" hole f/71 0' to 1843' (1133') TVD = 1656' ART = 1 hr AST = 7.5 hrs Drill wI 30-40 k WOB, 80 rpm, mm 66-77 rpm, 150-175 spm= 440 to 513 gpm wI 1400-1700 psi PU wt 56-75 k SO wt 56-70 k Printed: 1/21/2003 1:13:04 PM ) ) 8age20f to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-1 0 3S-1 0 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Description of Operations Spud Date: 12/28/2002 End: Group: Date Frorn - ToHbursCbde î~Je Phase 12/29/2002 00:00 - 12:00 12.00 DRILL DRLG SURFAC Rot wt 54-75 k 12:00 - 00:00 12.00 DRILL DRLG SURFAC Directional drill 12 1/4" hole fl 1843' to 3082' (1239') TVD = 2417' ART = 5.25 hr AST = 2 hrs Drill wI 1-40k WOB, 80-100 rpm, mm 82-84 rpm, 186-191 spm = 545-560 gpm wI 2130-2600 psi PU wt 75- 99 k SO wt 64-74 k Rot wt 75-83 k 12/30/2002 00:00 - 03:30 3.50 DRILL DRLG SURFAC Directional drill 12 1/4" hole f/3082' to 3377'(295') TVD = 2606' ART = 2 hrs AST = 0 Drill w/40 k WOB, 100 rpm, mm 84 rpm, 193 spm, = 563 gpm wI 2600 psi. PU wt 105 k SO wt 85 k Rot wt 85 k 03:30 - 06:00 2.50 DRILL CIRC SURFAC Circ and condition mud and hole f/ 9 5/8" casing. Circ bttms up- 6000 strokes, pump hi vis sweep, continue to circ fl total of 23000 strokes(3 bttms up), pump dry job. 06:00 - 11 :30 5.50 DRILL TRIP SURFAC Monitor well. POOH f/9 5/8" casing. POOH, tight spot @ 1658'. Back ream thru f/1658' to 1598'. Shut down pumps. Slack off, took weight @ 1621'. Attempted 3 times to get past--no go. POOH fl hole opener. Tight spot @ 1318'. Con't POOH to BHA @ 167'. 11 :30 - 13:00 1.50 DRILL OTHR SURFAC UD float sub, drain motor, break bit, set back stand wI motor. Clean bit up. Bit was balled up wI lots of clay. 13:00 - 14:00 1.00 RIGMNT RSRV SURFAC Lubricate Rig and top drive. Change out dies in grabber fl TD. Grease crown sheaves. 14:00 - 14:30 0.50 DRILL OTHR SURFAC MU BHA # 2 (Hole opener). 14:30 - 15:30 1.00 DRILL TRIP SURFAC RIH wI hole opener to 1350'. Took 20/30k weight. 15:30 - 16:00 0.50 DRILL REAM SURFAC Ream fl 1350' to 1365' wI 106 spm wI 324 psi, 40 rpm, torque 5000-6000 ft/lb torque. 16:00 - 16:30 0.50 DRILL REAM SURFAC RIH fl 1365' to 1640'. Took 25/40k weight @ 1640'. MU top drive. Ream 1640' to 1660' w/1 09 spm wI 360 psi, 45 rpm, torque 5000-6000 ft/lb. 16:30 - 17:00 0.50 DRILL TRIP SURFAC RIH fl 1690' to 2741'. No problems. 17:00 - 17:30 0.50 DRILL TRIP SURFAC Fill pipe and break circ @ 2741'. Continue to RIH to TD @ 3377' wI no problems 17:30 - 21 :00 3.50 DRILL CIRC SURFAC Break circ slowly, work up to 220 spm (650 gpm)wl 1425 psi. Circ and condition mud and hole fl casing. Circ one calc bttm's up then pump 31.5 bbls of Hi-vis 10.5 ppg sweep wI 3 #/bbl nut plug, follow wI total of 24,000 strokes (1675 bbls). By 14,000 strokes (977 bbls) -most of cutting & nut plug out of hole. 21 :00 - 23:00 2.00 DRILL TRIP SURFAC Monitor well, blow down top drive. POOH (SLM) f/3377' to 1825'. Tight @ 1825' up to 50 k overpull = 130k. Wipe up & down through 1825' twice wI no pump & no rotation. Con't POOH, hit another tight spot @ 1768'. Could not work through wI 50K over pull. RIH to 1978', did not see anything @ previous 1825' area. Set down @ 1890', worked by 1890', POOH to 1880' tight. RIH to 1978' Printed: 1/21/2003 1:13:04 PM ) ) Legal Well Name: 3S-1 0 Common Well Name: 3S-1 0 Event Name: ROT - DRILLING Contractor Name: n1268@conocophillips.com Rig Name: Nabors 7ES HoursCodé ·Sub Code 12/30/2002 23:00 - 00:00 1.00 DRILL REAM SURFAC 12/31/2002 00:00 - 03:30 3.50 DRILL REAM SURFAC 03:30 - 04:00 0.50 DRILL REAM SURFAC 04:00 - 07:00 3.00 DRILL CIRC SURFAC 07:00 - 11 :00 4.00 DRILL TRIP SURFAC 11 :00 - 13:00 2.00 CASE RURD SURFAC 13:00 - 13:30 0.50 CASE SFTY SURFAC 13:30 - 17:30 4.00 CASE RUNC SURFAC 17:30 - 23:00 23:00 - 23:30 23:30 - 00:00 1/1/2003 00:00 - 06:30 06:30 - 08:00 Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Spud Date: 12/28/2002 End: Group: Back ream wI 1211/4" hole opener f/1978" to 1692' wI 100 rpm's , 185 spm (542 gpm), 734 psi. Back ream with 121/4" HO assembly fl 1692' to 1215'. RIH fl 1215' to 1978'. Washed @ 1420',1660',1698' thru 1735', then ran in hole fl 1735' t 01978'. Circ and condition hole @ 1978', run in 1 more stand to 2074', then RIH to 2169' Raising MW fl 9.5 ppg to 9.7 ppg, raise FV f/140 to 170. POOH pumping fl 2169' to 931'. POOH, stand back HWDP & flex DC's fl 931' to surface. UD Hole opener. Hole took good fill. RU to run 9 5/8" surface casing. PJSM wI co. rep and tool pusher on running 9 5/8" casing. Run 9 5/8" 40#/ft L-80 BTC casing using Frank's fillup tool to 2025'. Jt # 48 taking weight 5.50 CASE RUNC SURFAC Circ casing in hole using Frank's fillup tool every joint. Circ while running every joint-washing and working pipe in hole. Good returns at all times. Circ wI 85 spm = 349 psi. Circ required probably to 3006' üt # 72) Hole lots better: continued to circ in hole. Circ to jt # 80 in hole. Ran hngr & landing joint in hole wI out circ. Circulated a total of 14,800 strokes (1033 bbls) wI running fl 2025' to TD @ 3368' Casing landed @ 2300 hrs 12/31/2002. 0.50 CASE OTHR SURFAC Remove Frank's fillup tool, blow down top drive, MU Dowell cement head. 0.50 CEMENTCIRC SURFAC Circulate and condition mud and hole fl cement. Circ @ 85 spm wI 378 psi while recip casing. PU wt 160 k SO wt 90 k 6.50 CEMENTCIRC SURFAC Circulate and condition mud and hole fl cement. Circ @ 85 spm wI 378 psi while recip casing. PU wt 145 k SO wt 95 K Circ @ 115 spm (8bpm) from 0100 to 0630 hrs. Circ to lower vis fl 152 to 102, YP fl 46 to 25. Final circ rate 8 115 spm (8 bpm) wI 560 psi. Last 70 bbls of mud had nutplug fl marker. Total volume circulated prior to cement 3163 bbls. (523 bbls @ 6 bpm, 3163 bbls @ 8 bpm Held PJSM on cementing while circulating. 1.50 CEMENT PUMP SURFAC Dowell pumped 10 bbls CW 100 (8.3 ppg), tested lines to 3500 psi, pumped 40 bbls CW 100 (8.3 ppg) @ 6.5 bpm wI 280 psi, dropped bttm plug, pumped 50 bbls MudPush XL with red dye marker (10.5 ppg) @ 8 bpm wI 380 psi. Mixed and pumped 434.5 bbls (570 sx wI 4.28 yield) (10.7 ppg) lead cement Arctic Set @ avg rate of 8 bpm wI 290 psi. Observed nut plug @ shakers. Switched to tail cement. Pumped 119.6 bbls (300 sx wI 2.4 yield)) Lite Crete cement @ 8 bpm wI 530 psi. Dropped top plug. Dowell pumped 20 bbls water, followed by rig displacing wI 230.3 bbls of 9.8 ppg mud @ avg rate of 8 bpm (115 spm) wI 830 psi. Recip casing until 50 bbls mud displaced (70 bbls total fluid behind Printed: 1/21/2003 1:13:04 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-1 0 3S-1 0 ROT - DRILLING n 1268 @ conocophillips.com Nabors 7ES Date Sub From-To Hours Code Code 1/1/2003 06:30 - 08:00 08:00 - 09:00 09:00 - 12:00 12:00 - 13:00 13:00 - 15:30 15:30 - 16:30 16:30 - 19:30 19:30 - 20:00 20:00 - 00:00 1/2/2003 00:00 - 03:30 Pagø40flO Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Spud Date: 12/28/2002 End: Group: 1.50 CEMENT PUMP SURFAC plug), then landed casing in landing ring. Slowed mud displacement to 4 bpm fllast 10 bbls wI 475 psi. Bumped plug wI 1000 psi. Rig pumps 95% eff. CIP @ 0850 hrs 1/1/03 65 bbls 10.7 ppg cement returned to surface. 1.00 CEMENT DISP SURFAC Dowell pumped 20 bbls water, followed by the rig pumps displacing wI 230.5 bbls of 9.8 ppg mud @ avg rate of 8 bpm (115 spm) wI 830 psi. Recip casing until 50 bbls mud displaced (70 bbls total fluid behind plug), then landed casing in FMC 16" landing ring. Last down weight 50k. Slowed mud displacement to 4 bpm fllast 10 bbls wI 475 psi prior to bump. Bump plug w/1 000 psi. Rig pump eff 95%. CIP @ 0850 hrs 1/1/03. 65 bbls 10.7 ppg cement returned to surface. 3.00 CEMENTOTHR SURFAC Bleed off pressure, floats held. RID cementing equip. Flush out diverter stack! UD landing joint, UD casing elevators. Change to drilling bales & elevators. Flushed mud out of mud manifold. 1.00 DRILL PULD SURFAC UD motor and DC's left standing in derrick fl BHA # 1. 2.50 WELCTL NUND SURFAC Nipple down 20" diverter equipment. 1.00 WELCTL NUND SURFAC Nipple up FMC Gen V 7" casing head & 3 1/2" tubing spool. Take measurements to Rotary table. Rotary table to lower lockdown screws (7" casing head) 26.43" Rotary table to upper lockdown screws (3 1/2" tubing spool) 24.18" 3.00 WELCTL NUND SURFAC Nipple up 135/8" 5,000psi BOPE. 0.50 WELCTL OTHR SURFAC RU to test BOPE. 4.00 WELCTL BOPE SURFAC Test 135/8" BOPE. Annular tested to 350 psi low & 3500 psi high. Held each test 10 minutes. Test to 350 psi low and 5000 psi high all other BOPE. All tests held 10 minutes. Witness of BOPE test waived by AOGCC inspector John Crisp. 3.50 WELCTL BOPE SURFAC Finish testing 135/8" BOPE. Held each test 10 minutes. Test to 350 psi low and 5000 psi high all other BOPE. All tests held 10 minutes. Work on thawing out frozen choke line. Continue cleaning pits and injection pit. Rig down test equipment after BOP test. Insatll wear bushing. Service top drive. Slip 35' drilling line on drawworks drum. PU 5" drill pipe from pipe shed, RIH 60 joints. POOH wI 60 joints 5" drill pipe, stand back in derrick. 03:30 - 04:00 0.50 WELCTL OTHR SURFAC 04:00 - 05:00 1.00 RIGMNT RSRV SURFAC 05:00 - 07:30 2.50 DRILL TRIP SURFAC 07:30 - 08:30 1.00 DRILL TRIP SURFAC 08:30 - 13:00 4.50 DRILL OTHR SURFAC 13:00 - 14:00 1.00 DRILL TRIP SURFAC 14:00 - 15:30 1.50 RIGMNT RGRP SURFAC 15:30 - 17:00 1.50 DRILL TRIP SURFAC 17:00 - 18:00 1.00 DRILL CIRC SURFAC Pickup bottom hole assembly from pipe shed. Orient tools, upload MWD, load source. Shallow hole test MWD tools. Pickup DC's and stabilizer, RIH wI 5" HWDP and jars. Run in hole wI BHA # 3 (8 1/2" bit), picking up 5" drill pipe from pipe shed, run in hole. Rotate through TAM Port collar @ 1013'. Fix hydraulic leak and trouble shoot & fix electrical problem on iron roughneck. Continue RIH, tag up on cement @ 3277'. POOH to 3212'. Hook up blower hose on top drive. Blow air through kelly hose to check top drive circulation system to be ok. Break circulation. Stage pumps to 450 gpm (153 spm) with 1400 psi. Printed: 1/21/2003 1: 13:04 PM .) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-1 0 38-10 ROT - DRILLING n 1268 @conocophillips.com Nabors 7ES Date From.. To Hou rs Code·· Sub· Phase ·Code 1/2/2003 17:00 - 18:00 1.00 DRILL CIRC SURFAC 18:00 - 18:30 0.50 CASE MIT SURFAC 18:30 - 19:00 0.50 CASE MIT SURFAC 19:00 - 20:00 1.00 CEMENT DSHO SURFAC 20:00 - 20:30 0.50 DRILL CIRC SURFAC 20:30 - 21 :00 0.50 DRILL CIRC SURFAC 21 :00 - 21 :30 0.50 DRILL OTHR SURFAC 21 :30 - 22:00 0.50 DRILL CIRC SURFAC 22:00 - 23:00 1.00 DRILL LOT SURFAC 23:00 - 23:30 0.50 DRILL OTHR SURFAC 23:30 - 00:00 0.50 DRILL DRLG INTRM1 1/3/2003 00:00 - 00:00 1/4/2003 00:00 - 12:00 Spud Date: 12/28/2002 End: Group: Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Description of Operations MM = 148 rpm RU to test 9 5/8" 40#/ft L-80 BTC casing. Test 9 5/8" 40#/ft L-80 BTC casing to 2500 psi f/30 minutes. Chart test. Drill cement, plugs, Float collar @ 3282', cement, Float shoe @ 3368', rat hole & 25' of new hole to 3402' MD (2621' TVD) Circulate and condition mud in hole. Circulate out cement cuttings. Displace 9.5 ppg mud in hole to new Low solids non dispersed 9.4 ppg mud. Clean under shakers and possum belly. Clean throughs in pits. Circulate and condition mud for FIT using new 9.4 ppg mud. Set back one stand. Perform LOT with 9.4 ppg and 1075 psi. Pump down drill pipe and annulus. Bleed back 1 bbl fluid after test. Rig down test equipment. Blow down 2" hose and kill line. RIH one stand. Drill 8 1/2" hole f/ 3402' to 3497' (95'). ART = .25 hrs AST = .25 hrs 24.00 DRILL DRLG INTRM1 Directional drill 8 1/2" hole f/ 3497' to 6350' (2853') 6350' MD = 4528'TVD ART = 13.75 hrs AST = 1.25 hrs Drilled w/1 0-25k WOB Pumping 180-197 spm 527-577 gpm Pump pressure on bottom 1600-2800 psi Pump pressure off bttm 1450- 2485 psi MM = 174-190 rpm Torque on bttm = 6000- 11000 ft/lb Torque off bttm = 5000-10500 ft/lb PU wt = 110-120 k SO wt = 80-95 k Rot wt = 90-120 k SPR @ 5778' MD (4113' TVD) # 1 pump @ 43 spm = 220 psi @ 57 spm = 300 psi # 2 pump @ 43 spm = 220 psi @ 57 spm = 300 psi 12.00 DRILL DRLG INTRM1 Directional drill 8 1/2" hole f/ 6350' to 7494' (1144') TVD = 5550' ART = 6 hrs AST = 2 hrs Drill w/ 10-30 k WOB, 167spm-194 spm, 490-569 gpm, MM 161-188 rpm, pump pressure off bttm 2408-3100 psi, pump pressure on bttm 2720 psi to 3310 psi, PU wt 145-190 k, SO wt 95-106k, Rot wt 120-135k, torque on bttm 10-14k, torque off bttm 10-13 k. While drilling @ 7208', gas units peaked to 1600 then went to 400 while circ prior to connection. Raised MW f/ 12.1 ppg to 12.3 ppg. While drilling @ 7303', gas units peaked to 1655 units, came down prior to connection. SPR @ 6826' (4933' TVD) w/ 11.5 ppg mw # 1 @ 35 spm = 210 psi @ 45 spm = 300 psi # 2 @ 35 spm = 210 psi @ 45 spm = 300 psi Printed: 1/21/2003 1:13:04 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .ConocoP.hiUipsAlaska .OperationSSulTul1aryRep.ort Page 60f10 38-1 0 3S-1 0 ROT - DRILLING n1268 @conocophillips.com Nabors 7ES Spud Date: 12/28/2002 End: Group: Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Description of Operations Date ·Sub From-To . Hours Code Code> Phase 1/4/2003 00:00 - 12:00 12:00 - 17:30 17:30 - 21 :00 21 :00 - 00:00 12.00 DRILL DRLG INTRM1 SPR @ 7303' (5373' TVD) wI 12.3 ppg mw # 1 @ 35 spm = 320 psi @ 45 spm = 400 psi # 2 @ 35 spm = 300 psi @ 45 spm = 380 psi PU wt = 180 k SO wt = 100 k Rot wt = 135 k torque on bttm = 12500 ft/lb torque off bttm = 13000 ft/lb 5.50 DRILL DRLG INTRM1 Directional drill 8 1/2" hole fl 7494' to 7876' (382') TVD = 5926' ART = 3.75 hrs AST = .75 hrs Drill wI 10-30 k WOB, 167-170 spm, 490-498 gpm, MM 161-164 rpm" pump pressure off bttm 2400-2950 psi, pump pressure on bttm 2700-3310 psi, PU wt 190-225k, SO wt 103-110 k, Rot wt 135-150 k, torque on bttm 12000-16000 ft/lb, torque off bttm 12000-14000 ft/lb. While drilling @ 7770', gas units peaked to 5300 units 3.50 DRILL CIRC INTRM1 Circ and raise mud wt to 12.6 ppg. Before 12.6 ppg reached surface, started lossing mud @ 120 bph. With slower pump rates, losses decreased to 60 bbl/hr. lowered mud wt to 12.3 wI additions of LCM as well. LCM consisting of OM seal @ 10 ppb, Liquid casing @ 10 ppb, walnut fine @ 3 ppb, AuqaGel @ 10 ppb = total 33#/bbl Made a connection @ 1800 hrs. (7876' MD) Total losses @ 1800 hrs =198 bbls while circulating. Well flowed 4 bbls back during pumps off. Circ bttms up wI 370 gpm wI 1530 psi, ECD= 13.1 ppg , lossing 60 bph Calc BU 5400 strokes. @ 5400 strokes gas increased to 200+ units @ 5543 strokes 1300 units @ 5600 strokes 1900 units @ 5900 strokes, max gas= 2234 units, decreasing to 300 units by 6500 strokes 3.00 DRILL DRLG INTRM1 Control drill @ 100 ft/hr fl 7876' to 8066' mud losses to hole 70 bph. 2100 hrs to 2230 hrs= loss of 100 bbls. ART = 2 hrs AST = 0 hrs Drill wI 10k WOB, 160 spm,470 gpm, MM 154 rpm, pump pressure on bttm 2500 psi, pump pressure off bttm 2300 psi, PU wt 230 k, SO wt 115 k, Rot wt 150 k. Background gas running 160-180 units while drilling. ECD's running 13.2 to 13.5 ppg Made a connection @ 2240 hrs @ 7971' MD (6019' TVD) , well flowed back 7 bbls while making conn. Calc BU = 5467 strokes @ 5500 strokes 250 units @ 5800 strokes 1600 units @ 6100 strokes, max gas = 2569 units Printed: 1/21/2003 1 :13:04 PM ) ) ConocÓPhiUipsAlaskél Operätl()nsSurn rTlaryFh~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-1 0 38-1 0 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land 8pud Date: 12/28/2002 End: Group: Date From -To Hours· Code SUb Pha.se Code ..< 1/4/2003 21 :00 - 00:00 3.00 DRILL DRLG INTRM1 Decreasing to 1000 units by 6400 strokes, then to 500 units @ 6500 strokes, 300 units @ 6700 strokes. @ 7200 strokes 190 units. 1/5/2003 00:00 - 01 :30 1.50 DRILL DRLG INTRM1 Control drill81/2" hole f/8066' to 8130'. (TVD = 6175') ART = .75 hrs AST = 0.0 hrs 01 :30 - 06:00 4.50 DRILL CIRC INTRM1 Circ while working pipe. Adding load of 12.3 ppg mud to mud pit fl vac truck. Circ a bttm's up @ 470 gpm, then reduce rate to 300 gpm (102 spm)wl 1185 psi. monitor well. 06:00 - 10:00 4.00 DRILL TRIP INTRM1 Monitor well. POOH 15 stands f/8130' to 6826'. Pumped some stands out to ensure good hole fill. Tight @ 6912'. Pump & rotate through tight spot. No trouble wI RIH. 10:00 - 14:00 4.00 DRILL CIRC INTRM1 Circ, bringing rate up in 50 gpm increments checking to make sure hole is stable. Circ @ 320 gpm until BU. Then 400 gpm. Max gas units 968 units. Slow pump rate to 250 gpm & Raise weight fl 12.3 to 12.5ppg. Raise pump rate to 300 gpm, monitor hole for losses prior to POOH, OK. PU wt 230k wI circ. PU wt wlo pumps 250k SO wt 11 0 k Rot wt 160k Torque on bttm 14,000 to 14,500 ft/lb Torque off bttm 15,000 ft/lb SPR @ 8130' (TVD = 6175') # 1 @ 35 spm = 250 psi # 1 @ 45 spm = 325 psi # 2 @ 35 spm = 250 psi # 2 @ 45 spm = 320 psi While circ -Max gas 957 units @ 5600 strokes pumped, decreased to 236 units by 6400 strokes 14:00 - 19:00 5.00 DRILL TRIP INTRM1 Monitor well, POOH to shoe. Tight @ 6240'. Backream 6250'·5490' POOH 5490'·5015' Backream 5015'-4825' POOH 4825' - 3300' (shoe) Hole took 1.73 bbls over calc displacement. 19:00 - 20:30 1.50 RIGMNT RSRV INTRM1 Monitor well. Clean rig floor. Service top drive, blocks, crowntugger sheaves and manrider sheaves. 20:30 - 21 :30 1.00 RIGMNT RSRV INTRM1 Slip & cut 98' of drilling line. 21 :30 - 23:00 1.50 RIGMNT RGRP INTRM1 Alllen head bolts that attatch drilling line wear strip to drawworks kickback flange were rounded out due to overtorque. (Adjusted link tilt clamps on top drive) *** Hole took total of 4 bbls while @ shoe. Time 1900 hrs to 2300 hrs. 23:00 - 00:00 1.00 DRILL TRIP INTRM1 RIH wI BHA # 3 to 4731'. Monitor returns while trip in hole. 1/6/2003 00:00 - 04:30 4.50 DRILL TRIP INTRM1 Continue RIH slow f/4731' to 8130'. As long as running speed less than or equal to 45 ft/min, good displacement. No Problems. Fill pipe, break circ @ 4731' Fill pipe, break circ @ 6159' Fill pipe, break circ @ 7590' Printed: 1/21/2003 1:13:04 PM ) ) ConocoPhillips Alas~ä Operati.onsSUI11~aryR~port Pagé·8.·of10 Legal Well Name: 3S-1 0 Common Well Name: 3S-10 Spud Date: 12/28/2002 Event Name: ROT - DRILLING Start: 12/28/2002 End: Contractor Name: n1268 @conocophillips.com Rig Release: 1/9/2003 Group: Rig Name: Nabors 7ES Rig Number: Land ..·Date From~To Hours Code' Description of Operations 1/6/2003 00:00 - 04:30 4.50 DRILL TRIP INTRM1 Fill pipe once on bttm @ 8130, bring pumps up slowley (3 bpm stagging to 6 bpm=250 gpm) watching returns. 04:30 - 08:00 3.50 DRILL CIRC INTRM1 Circ & condition mud @ 85 spm =6 bpm=300 gpm w/1 047 psi. Max gas 23 units. Circ 2+ BU, no mud losses. Then increase rate to 102 spm=7.48 bpm=314 gpm wI 1345 psi. Hole taking 12-15 bbllhr @ this rate. SPR @ 8130' (6176'TVD) wI 12.5 ppg mud # 1 @ 35 spm = 275 psi @ 45 spm = 390 psi # 2 @ 35 spm = 250 psi @ 45 spm = 390 psi 08:00 - 08:30 0.50 DRILL CIRC INTRM1 Spot 46 bbls Steel Seal pill on bottom. 08:30 - 14:00 5.50 DRILL TRIP INTRM1 Pull 15 stands wet. Pump dry job, blow down top drive. Rotate first stand out due to overpull. SLM out of hole. PU wt 250k SO wt 11 0 k Rot wt 160k Torque 15,000 ftllb. POOH to BHA @ 921'. 14:00 - 16:00 2.00 DRILL TRIP INTRM1 Monitor well stand back 5" HWDP. Monitor well. UD single Flex DC & stabilizer. Clean rig floor. PJSM, Remove nuke sources. PU single Flex DC. Stand back Flex DC. 16:00 - 17:30 1.50 DRILL OTHR INTRM1 Plug in to Sperry Sun DC. Download information. 17:30 - 19:30 2.00 DRILL OTHR INTRM1 Flush BHA wI 15 bbls water. Pull MWD probe. UD smart tools. Pull float. adjust motor to zero deg., Break off bit, UD motor. Hole fill OK. 19:30 - 20:00 0.50 DRILL OTHR INTRM1 Clear and clean rig floor. Drain stack. Pull wear bushing. 20:00 - 21 :30 1.50 CASE RURD INTRM1 Rig up to run 7" 26 #/ft L-80 BTC-Mod. 21 :30 - 22:00 0.50 CASE SFTY INTRM1 PJSM fl running casing. Will be trying Nabors fillup tool. 22:00 - 00:00 2.00 CASE RUNC INTRM1 Run 7" 26 31ft, L-80, BTC-mod casing. PU shoe track & circ through FC & Float shoe @ 3.5 bpm wI 400 psi. Check float equip. Continue to run casing to 814' (Joint # 19) 1/7/2003 00:00 - 03:00 3.00 CASE RUNC PROD Cont RIH with 7" Csg to 1,925' with Partial Returns, (Circ a Csg Cap at 896') 03:00 - 03:30 0.50 CASE CIRC PROD Est Circ, Circ Hole at 3 BPM, ICP @ 670 Psi, FCP @ 543 Psi, 12.3 MW In & Out Had 420 Vis Mud After Est Circ & Decreased to 73 after Circ thick Mud Out, Pumped 105 bbls Total, Lowered 12.5 ppg MW to 12.3 ppg While RIH with Csg 03:30 - 05:00 1.50 CASE RUNC PROD Cont RIH with 7" csg @ 20'/Min to 2,861', Not Getting Calc Displacement 05:00 - 06:30 1.50 CASE CIRC PROD Circ & Cond Mud, Circ 3 Btms Up, Initial rate 2 BPM @ 724 Psi, Increased Final Rate to 6 BPM @ 565 Psi with No Losses 12.3 ppg Mw In & Out 06:30 - 07:30 1.00 CASE RUNC PROD RIH with 17 Add Jts (78 Total) of 7" Csg to 3,326' (9 5/8" Csg Shoe) 07:30 - 08:00 0.50 CASE CIRC PROD Circ Hole @ 95/8" Csg Shoe @ 4 BPM @ 405 psi, St Wt Before Circ 134K Up, 79K Down, After Circ 105K Up Wt & 64K Dwn 08:00 - 13:00 5.00 CASE RUNC PROD Cont RIH with 7" Csg, Circ 1,000 Stks @ 4,262' & 1,350 Stks @ 4,893' Due to Not Getting Calc Displacement, Initial Rate 2 Bpm, Final Rate 4 Bpm @ 595 Psi, Cont RIH @ 30'/Min to 5,535'. 13:00 - 13:30 0.50 CASE CIRC PROD Broke Circ & Staged rate Up to 4 BPM, ICP 660 Psi, FCP 510 Psi, Pumped 154 bbls of 12.3 ppg Mud. 13:30 - 14:00 0.50 CASE RURD PROD LD Nabors Fill-Up Tool Due to Check Valve Failure, MU Franks Fill-Up Printed: 1/21/2003 1:13:04 PM .) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) CpnocoPhilliþsAIt:iska .. ·Oþétation$.Sql11l11aryRE!Pott . 3S-1 0 3S-1 0 ROT - DRILLING n1268@conocophillips.com Nabors 7ES Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land Spud Date: 12/28/2002 End: Group: Date Sub From- To Hours Code Code Phase 117/2003 13:30 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 00:00 1/8/2003 00:00 - 00:45 00:45 - 02:00 0.50 CASE 1.00 CASE 0.50 CASE RURD PROD RUNC PROD CIRC PROD Tool Cont RIH with 7" Csg @ 30'/Min to 6,430', PU Wt 150K, Dwn WT 85K Est Circ @ 3.2 Bpm, ICP 560 Psi, FCP 530 Psi, Lost Approx 10 bbls Mud after Pumping 60 bbls and Had Full Returns After, Pumped 105 bbls total, After Circ, Up Wt 150K, Dwn Wt 94K Cont RIH with 7" Csg @ 30'/Min to 7,100' (167 Jts Total in Hole) PU Wt 170K, Dwn Wt 90K Est Circ @ 3 BPM @ 580 psi, Staged up to 4 BPM, FCP@ 520 psi, Pumped 234 bbls (1.3 x Ann Cap) of 12.3 MW, @ Btms up had 12.7 ppg MW Out, Max Gas @ Btms Up 30 Units, Had slight Losses Initially and Regained Full Circ, Had 12.3 ppg Mud In & Out Fin RIH @ 30'/min with 7" Csg to 8,084', MU Landing Jt and Landed Csg in Head, Landed Csg with Float Shoe @ 8,112' and Float Collar @ 7,942', Ran a Total of 190 Jts of 7" 26#, L-80 BTC-Mod Csg (Total Including Fit Equip 8,084.23') Ran Centralizers Per Well Plan, Thread Locked Conn Below Float Collar, Up Wt 235K, Down Wt 11 OK LD Franks Fill-Up Tool & MU Cement Head Thawed Out Mud Manifold on Rig Floor Circ & Cond Mud for Cmtg, Est Circ @ 1 Bpm @ 320 Psi, Attempted to Reciprocate pipe, PU to 375K Up Wt and was Unable to Reciprocate Pipe, Staged rate up to 5 Bpm, ICP @ 650 Psi, FCP 600 Psi after Pumping 837 bbls (4 x Ann Cap) Max Gas @ Btms Up 200 Units, Final BGG 20 Units, 12.3 ppg Mw In & Out with 49 Vis & 18 YP, Held PJSM on Cmtg Csg & Batch Mixed Cement & Weighted Mud Push While Circ Hole, 1 st Hr Lost Approx 5 bbls of Mud then had Full Returns Rig Up Dowell, Batch mix 15 bbls CW100 @ 8.3 ppg, 30 bbls MudPUSH @ 13.4 ppg, 250 sxs (52 bbls) @ 15.8 ppg Class "G" GasBLOK and 1/4 #/sack celloflakes wi + .300%BWOC D65, .020%BWOC B155, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 5 bbls CW100, Test lines to 4,0000 psi, Pump 15 bbls CW100, Drop #1 btm plug, Reload head, Pump 30 bbls MudPUSH at ave. rate of 5 bpm at 950 psi, Drop #2 btm plug, Pump 52 bbls cmt at ave rate of 5 bpm at 1,200 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 225 bbls of 8.5 ppg seawater at rate of 5 bpm at 975 psi until MudPush around shoe, Slowed rate to 4.0 bpm @ 820 psi until last 30 bbls of displacement then slowed rate to 3 bpm @ 1700 psi & bumped plug wi total of 308 bbls, Bumped plug wi 2300 psi, Checked Floats & Held, Bled back 2.3 bbls for a total of 305.7 total bbls displaced (Calculated 304.1 bbls), CIP @ 02:00 hrs 1/9/03, Had good circ. thru out job- no noticeable mud loss, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. RD Cement Head, LD Landing Jt, Blow Down Dowell's Line and Flushed Out BOP's and Surface Lines, Blow Down Lines to Pumps. Set 7" Pack-off & Ran in Lock Down's, Tested Pack-off to 5,000 psi Changed Out Long Elevator Bales & Fin Rd 7" Csg Tools PU & RU Nabors 31/2" Handling Tools for Completion Cleaned Up Around Rig Floor Held PJSM, 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 1/2", 9.3#, L-80 tbg - Camco "DS" nipple wi 2.813 profile - 1 jt tubing - pup - Camco MMG wi DCR shear 02:00 - 04:00 2.00 CEMENT RURD PROD 04:00 - 05:00 1.00 WELCTL OTHR PROD 05:00 - 06:30 1.50 CEMENT RURD PROD 06:30 - 07:30 1.00 CMPL TN RURD CMPL TN 07:30 - 08:30 1.00 RIGMNT RSRV CMPL TN 08:30 - 18:00 9.50 CMPL TN RUNT CMPL TN 1.00 CASE RUNC PROD 1.00 CASE CIRC PROD 2.00 CASE RUNC PROD 0.50 CASE RURD PROD 0.50 RIGMNT RGRP PROD 3.50 CASE CIRC PROD 0.75 CEMENT PUMP PROD 1.25 CEMENT DISP PROD Printed: 1/21/2003 1: 13:04 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ÇohocoPhillipsAlaska ()perationsSu.n1mary.. Rep()rt 3S-1 0 3S-1 0 ROT - DRILLING n 1268 @conocophillips.com Nabors 7ES Date Sub From-To Hours Code Code Phase 1/8/2003 08:30 - 18:00 18:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 23:30 1/9/2003 23:30 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 06:00 06:00 - 11 :00 11 :00 - 12:30 12:30 - 13:30 13:30 - 14:30 14:30 - 19:30 19:30 - 20:00 20:00 - 22:30 22:30 - 00:00 9.50 CMPL TN RUNT CMPL TN 2.00 CMPL TN DEOT CMPL TN 1.00 CMPL TN PCKR CMPL TN 1.00 CMPL TN SOHO CMPL TN 1.50 CMPL TN DEOT CMPL TN 0.50 WELCTL OTHR CMPL TN 3.00 RIGMNT RGRP CMPL TN 0.50 CMPL TN RURD CMPL TN 2.50 WELCTL NUND CMPL TN 5.00 CMPL TN NUND CMPL TN 1.50 CMPL TN RURD CMPL TN 1.00 CMPL TN RURD CMPL TN 1.00 RIGMNT RSRV CMPL TN 5.00 CMPL TN OTHR CMPL TN 0.50 WELCTL OTHR CMPL TN 2.50 MOVE RURD MOVE 1.50 MOVE DMOB MOVE Pägerl0Ôf1.0 Spud Date: 12/28/2002 End: Group: Start: 12/28/2002 Rig Release: 1/9/2003 Rig Number: Land DescriptipnofOperations valve - pup - RIH with Completion Assembly with 4 GLM's Per Well Plan, Ran 241 Jts of 3 1/2" 9.3# L-80 EUE-Mod Tbg to 7,752', Up Wt 95K, Own WT 60K RU to Test 7" Csg, Tested Lines to 3,700 psi, Tested Csg to 3,500 Psi for 30 Min, Good Test Drop 2" Ball - MU Pump in Sub - Position Packer on Depth. With Ball on Seat Pressure Tubing to 2,500 psi for 5 min, No Loss, Bled to -0-, Slacked Off 15K, Pressure Up to 3000 psi, held 5 min. Bled Pressure Down to 1,000 Psi, PU to 130K & Sheared PBR, Press Up to 3,200 psi & Sheared Ball Seat - Pressure up tubing to 3,700 psi, Bled to -0- & Rd Circ Hose, SIM Op's Performed LOT on 7" x 9 5/8" Ann for Injectivity Test and Broke Down at 600 psi for a 16.7 ppg EMW, Flushed Annulus with 313 bbls Water and Freeze Protected with 75 bbls Diesel, (388 bbls Total Pumped Down 3S-1 0 Ann) LD Landing Jt & Spaced Out, MU Hanger & Landed 31/2" Tbg, Ran in Lock Downs, Landed with WLEG @ 7,752', Pkr Set @ 7,720', GLM's Per Well Plan with Camco "OS" Nipple with 2.875" No Go @ 498' RU & Tested 31/2" Tbg to 3,500 psi for 15 Min, Good Test, Bled to 1,500 psi, Press Up on 31/2" x 7" ann and Pressure Tested to 3,500 psi for 15 Min, Good Test, Bled Tbg Press to -0- and Sheared RP Valve, Bled Well to -0-, RD Test Lines & Blew Down Same Installed TWC in Wellhead Cleaned Up Around Rig Floor, Pipe Shed & Pit Room LD 31/2" Handling Tools, Subs & XO's Held PJSM, NO 13 5/8" BOP Stack & Set Back Moved Tree into Cellar & NU Gen V 5K# Tree & adadpter Spool, Had to Move Adapter Spool 2 Bolt Holes to Line Up Tree, RU & Tested Tree to 5,000 Psi, Pulled TWC. Addressed housekeeping issues in cellar. Sim Op, Began Cleaning Mud Pits RU to Freeze Protect Well Down Tbg Taking Returns Out Ann Installed 20" extension on Drip Pan Serviced Top Drive, Blocks & Drawworks, Sim Op's Attempted to Freeze Protect Well, Pumped 5 bbls Down Tbg & OCR Valve Plugged, RU & Pumped Down Backside with 5 bbls & had Good Returns, Pumped Down Tbg 5 bbls & OCR Valve Plugged RU to LD Excess DP, LD 93 Jts Of 5" DP & 3 63/4" Flex Dc's, Sim Op Freeze Protected Well Pumping 268 bbls Diesel Down Ann Taking Returns Out Tbg Installed BPV and Secured Well Secured Rig Floor & Cellar for Rig Move, Prep Inj Skid & Ball Mill, Fin Cleaning Mud Pits and Hauling Off of Fluids from Pits @ 22:00 Hrs Moved Out Inj Skid & Ball mill, Pull Matting Boards & Herculite, Hook trucks Onto Mud Pits Released Rig at 24:00 Hrs 1/9/03 to Move to 3S-15 Printed: 1/21/2003 1:13:04 PM Date 12/28/02 01/09/03 01/14/03 01/15/03 ') ) 3S-10 Event H ¡story Comment STAND BY FOR RIG. RAN GYRO TOOL @ 1001 & 3001. [STANDBY] RIG SUPPORT. TAGGED FILL & DRIFTED TO @ 7930' RKB WI 23.51 OF 2.53" DUMMY GUN1S, REPLACED SHEARED SOV @ 7605' RKB WI DV, PT TBG & IIA TO 2500# GOOD TEST [TAG, GLV, MIT, PT TBG-CSG] TAGGED PBTD @ 79381, MADE JEWELRY LOG WI BHPff SURVEY. PERF. 7812'-78421 MD (UNDERBALANCED), AND 78021-78121 MD (BALANCED) WI 2.5" HSD, 6 SPF, PJ. LOGGED POST PERF. RAN STATIC BHPff. POOH, RDMO, LEFT WELL SHUT IN, NOTIFIED DSO OF STATUS. [PERF] Page 1 of 1 1/21/2003 ) ) AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITVE Re: Distribution of Survey Data for Well 3S-10 Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window I Kickoff Survey Projected Survey: 0.00' MD 0.00' MD (if applicable) 8,130.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ O~-d~ 27 -Jan-03 RECEIVED FE8 05 2003 AlileKlon & G88 Coni, ~ ~ Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 3S Pad 35-10 ~/ Job No. AKMW22206, Surveyed: 5 January, 2003 Survey Report 31 January, 2003 Your Ref: 501032044000 Surface Coordinates: 5993914.52 N, 476266.35 E (70023'40.2172" N, 150011'35.1779" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -- Surface Coordinates relative to Project H Reference: 993914.52 N, 23733.65 W (Grid) Surface Coordinates relative to Structure: 70.92 N, 188.88 W (True) Kelly Bushing: 56.30ft above Mean Sea Level Elevation relative to Project V Reference: 56. 30ft Elevation relative to Structure: 0.20ft S¡ ..... tray-sUI! D F.t.I.L.~ .~..~. ~_~.> ~~>~YI.C:;iE?!:i A Halliburton Company Survey Ref: svy10014 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-10 Your Ref: 501032044000 Job No. AKMW22206, Surveyed: 5 January, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO /1000) 0.00 0.000 0.000 -56.30 0.00 0.00 N 0.00 I; 5993914.52 N 476266.35 E 0.00 Tolerable Gyro 83.00 0.250 272.000 26.70 83.00 0.01 N 0.18W 5993914.53 N 476266.17 E 0.301 -0.07 MWD Magnetic 199.14 1.790 18.700 142.82 199.12 1.73 N 0.15 E 5993916.25 N 476266.50 E 1.616 1.63 260.00 3.150 12.000 203.62 259.92 4.27 N 0.80 E 5993918.79 N 476267.16 E 2.281 4.20 379.89 4.660 19.030 323.23 379.53 12.10 N 3.07E 5993926.61 N 476269.46 E 1.319 12.24 22.550 414.35 470.65 19.77 N 6.01 E 5993934.27 N 476272.42 E 1.135 20.44 '- 471.38 5.650 561.27 5.440 22.060 503.82 560.12 27.80 N 9.31 E 5993942.29 N 476275.75 E 0.239 29.11 651 .77 9.230 21.010 593.56 649.86 38.56 N 13.52 E 5993953.04 N 476280.00 E 4.190 40.63 740.45 12.700 25.080 680.61 736.91 54.03 N 20.21 E 5993968.49 N 476286.73 E 4.007 57.48 830.34 16.680 27.820 767.55 823.85 74.40 N 30.42 E 5993988.82 N 476297.01 E 4.493 80.26 927.42 19.490 25.160 859.82 916.12 1 01.39 N 43.81 E 5994015.77 N 476310.48 E 3.016 110.38 1022.37 22.560 24.890 948.44 1004.74 132.25 N 58.21 E 5994046.59 N 476324.98 E 3.235 144.44 1118.35 25.880 26.140 1035.96 1092.26 167.77 N 75.20 E 5994082.05 N 476342.08 E 3.500 183.81 1213.66 29.550 27.590 1120.32 1176.62 207.29 N 95.25 E 5994121.50 N 476362.26 E 3.915 228.11 1307.10 32.020 27.840 1200.59 1256.89 249.62 N 117.50 E 5994163.76 N 476384.64 E 2.647 275.89 1402.35 35.930 26.280 1279.57 1335.87 297.02 N 141.67 E 5994211 .09 N 476408.96 E 4.205 329.08 1497.92 39.740 25.780 1355.03 1411.33 349.69 N 167.38 E 5994263.68 N 476434.84 E 3.999 387.69 1592.92 42.070 25.910 1426.83 1483.13 405.67 N 194.50 E 5994319.57 N 476462.14 E 2.454 449.89 1691.84 44.930 25.590 1498.57 1554.87 467.00 N 224.08 E 5994380.81 N 476491.91 E 2.900 517.97 1787.02 48.360 23.500 1563.91 1620.21 529.95 N 252.79 E 5994443.67 N 476520.82 E 3.941 587.15 1879.88 52.750 26.330 1622.90 1679.20 594.94 N 283.03 E 5994508.55 N 476551.27 E 5.280 658.83 1975.33 50.290 28.290 1682.29 1738.59 661.33 N 317.29 E 5994574.84 N 476585.74 E 3.037 733.50 2070.17 51.320 28.470 1742.23 1798.53 725.99 N 352.23 E 5994639.39 N 476620.88 E 1.096 806.90 -' 2165.64 49.620 28.750 1802.99 1859.29 790.64 N 387.48 E 5994703.92 N 476656.34 E 1.795 880.42 2260.39 50.920 27.600 1863.55 1919.85 854.87 N 421.88 E 5994768.05 N 476690.94 E 1.659 953.20 2355.63 52.030 24.940 1922.88 1979.18 921 .68 N 454.84 E 5994834.75 N 476724.12 E 2.476 1027.69 2450.77 51.970 26.050 1981.45 2037.75 989.35 N 487.11 E 5994902.32 N 476756.60 E 0.922 1102.65 2547.31 51.870 25.230 2041.00 2097.30 1057.86 N 519.99 E 5994970.72 N 476789.70 E 0.677 1178.64 2642.66 52.770 26.460 2099.28 2155.58 1125.77 N 552.89 E 5995038.52 N 476822.81 E 1.390 1254.10 2737.57 53.000 26.250 2156.55 2212.85 1193.58 N 586.49 E 5995106.24 N 476856.63 E 0.300 1329.78 2834.18 53.290 24.960 2214.50 2270.80 1263.29 N 619.90 E 5995175.84 N 476890.25 E 1.110 1407.08 2926.87 53.840 23.100 2269.55 2325.85 1331.40 N 650.26 E 5995243.85 N 476920.83 E 1 .720 1481.62 3022.59 50.840 23.270 2328.03 2384.33 1401.05 N 680.08 E 5995313.40 N 476950.88 E 3.137 1557.33 3119.03 51.130 22.360 2388.74 2445.04 1470.12 N 709.14 E 5995382.38 N 476980.15 E 0.792 1632.18 3214.49 50.960 20.540 2448.76 2505.06 1539.20 N 736.28 E 5995451.38 N 477007.52 E 1 .493 1706.24 31 January, 2003 - 15:52 Page 2 of 5 DriJ/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 35-10 Your Ref: 501032044000 Job No. AKMW22206, Surveyed: 5 January, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3312.97 51 .740 21.900 2510.27 2566.57 1610.89 N 764.12 E 5995522.98 N 477035.59 E 1.338 1782.94 3433.61 51.560 24.360 2585.13 2641.43 1697.89 N 801.28 E 5995609.85 N 477073.02 E 1.606 1877 .46 3528.55 50.590 25.320 2644.78 2701.08 1764.91 N 832.31 E 5995676.78 N 477104.25 E 1.289 1951.31 3623.12 50.180 24.550 2705.08 2761.38 1830.97 N 863.02 E 5995742.74 N 477135.18 E 0.762 2024.16 3716.40 49.510 24.180 2765.23 2821.53 1895.92 N 892.43 E 5995807.59 N 477164.80 E 0.780 2095.44 '- 3812.37 51.470 25.940 2826.29 2882.59 1962.97 N 923.81 E 5995874.55 N 477196.38 E 2.484 2169.47 3905.41 51.360 25.840 2884.31 2940.61 2028.40 N 955.56 E 5995939.88 N 477228.35 E 0.145 2242.20 4001.49 50.590 25.230 2944.81 3001.11 2095.75 N 987.74 E 5996007.12 N 477260.74 E 0.941 2316.84 4096.78 50.030 24.670 3005.67 3061.97 2162.23 N 1018.67 E 5996073.51 N 477291.88 E 0.742 2390.16 4192.47 51 .270 27.210 3066.34 3122.64 2228.76 N 1051.05 E 5996139.93 N 477324.47 E 2.427 2464.14 4285.92 50.870 26.810 3125.07 3181.37 2293.52 N 1084.06 E 5996204.59 N 477357.69 E 0.542 2536.81 4382.08 50.600 24.510 3185.93 3242.23 2360.62 N 1116.30 E 5996271.59 N 477390.14 E 1.873 2611.25 4476.45 50.080 25.210 3246.16 3302.46 2426.54 N 1146.84 E 5996337.41 N 477420.89 E 0.794 2683.90 4572.38 49.580 24.860 3308.04 3364.34 2492.95 N 1177.86 E 5996403.72 N 477452.12 E 0.591 2757.20 4667.84 51.990 27.290 3368.39 3424.69 2559.36 N 1210.39 E 5996470.03 N 477484.86 E 3.203 2831.14 4763.10 52.310 28.170 3426.85 3483.15 2625.94 N 1245.39 E 5996536.49 N 477520.07 E 0.803 2906.29 4856.48 51.920 29.140 3484.19 3540.49 2690.61 N 1280.73 E 5996601.05 N 477555.61 E 0.920 2979.87 4952.78 52.100 28.380 3543.47 3599.77 2757.15 N 1317.24 E 5996667.47 N 477592.34 E 0.649 3055.64 5047.98 52.120 28.540 3601.93 3658.23 2823.20 N 1353.04 E 5996733.41 N 477628.35 E 0.134 3130.66 5141.57 51. 940 26.770 3659.52 3715.82 2888.54 N 1387.29 E 5996798.64 N 477662.80 E 1.503 3204.38 5236.72 52.060 27.530 3718.10 3774.40 2955.26 N 1421.50 E 5996865.25 N 477697.23 E 0.642 3279.33 5332.35 51.950 28.120 3776.97 3833.27 3021.91 N 1456.68 E 5996931.79 N 477732.62 E 0.500 3354.62 5427.92 51.780 27.610 3835.98 3892.28 3088.36 N 1491.81 E 5996998.13 N 477767.96 E 0.456 3429.72 ~ 5523.23 51.500 27.710 3895.13 3951.43 3154.56 N 1526.51 E 5997064.21 N 477802.87 E 0.305 3504.40 5618.66 51.140 27.330 3954.77 4011.07 3220.62 N 1560.93 E 5997130.17 N 477837.50 E 0.489 3578.85 5712.23 50.700 27.730 4013.76 4070.06 3285.04 N 1594.50 E 5997194.48 N 477871.27 E 0.576 3651.43 5809.78 48.230 27.590 4077.15 4133.45 3350.70 N 1628.92 E 5997260.03 N 477905.90 E 2.534 3725.51 5905.19 45.840 27.640 4142.18 4198.48 3412.56 N 1661.28 E 5997321.78 N 477938.45 E 2.505 3795.27 6000.51 45.580 26.530 4208.74 4265.04 3473.30 N 1692.34 E 5997382.43 N 477969.71 E 0.877 3863.47 6096.44 42.990 25.290 4277.41 4333.71 3533.54 N 1721.62E 5997442.57 N 477999.18 E 2.847 3930.44 6192.40 40.750 23.720 4348.86 4405.16 3591.80 N 1748.20 E 5997500.75 N 478025.95 E 2.577 3994.47 6285.46 38.810 24.360 4420.38 4476.68 3646.18 N 1772.45 E 5997555.05 N 478050.37 E 2.131 4053.99 6380.26 36.430 23.300 4495.46 4551.76 3699.10 N 1795.84 E 5997607.90 N 478073.93 E 2.602 4111.83 6476.67 34.290 21.920 4574.08 4630.38 3750.59 N 1817.31 E 5997659.32 N 478095.56 E 2.369 4167.56 6572.01 32.130 22.570 4653.85 4710.15 3798.93 N 1837.07 E 5997707.59 N 478115.47 E 2.296 4219.69 31 January, 2003 - 15:52 Page30f5 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-10 Your Ref: 501032044000 Job No. AKMW22206, Surveyed: 5 January, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (tt) (tt) (tt) (tt) (tt) (tt) (ft) (0/100tt) 6668.87 29.830 23.320 4736.88 4793.18 3844.84 N 1856.49 E 5997753.44 N 478135.04 E 2.408 4269.50 6763.87 27.270 23.320 4820.33 4876.63 3886.53 N 1874.46 E 5997795.08 N 478153.14 E 2.695 4314.87 6859.54 25.000 25.120 4906.21 4962.51 3924.97 N 1891.72 E 5997833.46 N 478170.53 E 2.513 4356.99 6954.64 24.220 26.180 4992.67 5048.97 3960.67 N 1908.86 E 5997869.11 N 478187.78 E 0.942 4396.59 7050.00 21.510 25.1 00 5080.53 5136.83 3994.06 N 1924.91 E 5997902.45 N 478203.93 E 2.876 4433.64 25.690 5169.83 5226.13 4025.44 N 1939.81 E 5997933.78 N 478218.93 E "_./ 7145.82 21.000 0.577 4468.38 7237.68 20.780 24.630 5255.65 5311.95 4055.08 N 1953.73 E 5997963.38 N 478232.95 E 0.476 4501.13 7336.10 20.190 24.670 5347.85 5404.15 4086.39 N 1968.10 E 5997994.64 N 478247.41 E 0.600 4535.57 7431.70 18.960 24.930 5437.92 5494.22 4115.46 N 1981.53 E 5998023.67 N 478260.94 E 1.290 4567.60 7526.20 16.280 23.230 5527.98 5584.28 4141.56 N 1993.23 E 5998049.73 N 478272.72 E 2.887 4596.19 7621.32 12.600 28.110 5620.08 5676.38 4162.97 N 2003.38 E 5998071.11 N 478282.94 E 4.072 4619.88 7717.00 11 .460 30.060 5713.66 5769.96 4180.41 N 2013.06 E 5998088.51 N 478292.67 E 1.265 4639.78 7811.79 11 .150 30.120 5806.61 5862.91 4196.48 N 2022.37 E 5998104.56 N 478302.04 E 0.327 4658.30 7908.00 10.850 30.690 5901.05 5957.35 4212.32 N 2031.66 E 5998120.37 N 478311.38 E 0.332 4676.59 8003.24 10.560 30.990 5994.64 6050.94 4227.51 N 2040.73 E 5998135.53 N 478320.49 E 0.310 4694.20 8069.48 10.170 31.750 6059.80 6116.10 4237.68 N 2046.93 E 5998145.68 N 478326.73 E 0.624 4706.06 8130.00 10.170 31.750 6119.37 6175.67 4246.77 N 2052.56 E 5998154.75 N 478332.38 E 0.000 4716.68 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.3' MSL. Northings and Eastings are relative to 2501' FNL, 993' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2501' FNL, 993' FEL and calculated along an Azimuth of 25.410° (True). - Magnetic Declination at Surface is 25.248°(14-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 8130.00ft., The Bottom Hole Displacement is 4716.78ft., in the Direction of 25.795° (True). 31 January, 2003 - 15:52 Page 4 of 5 DriJIQuest 3.03.02.004 Western North Slope Comments Measured Depth (ft) 8130.00 6175.67 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-10 Your Ref: 501032044000 Job No. AKMW22206, Surveyed: 5 January, 2003 ConocoPhillips Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4246.77 N 2052.56 E Projected Survey -~ Survey tool proaram for 3S-10 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 83.00 31 January, 2003 - 15:52 0.00 83.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 83.00 8130.00 83.00 Tolerable Gyro 6175.67 MWD Magnetic ---- Page50f5 DrillQuest 3.03.02.004 Schlumberger NO. 2840 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth 01/31/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Sepia 1R-14 J ?:5- J '5 J LEAK DETECTION LOG 01/09/03 1 2G-15 18'-1-1::' I LEAK DETECTION LOG 01/08/03 1 1 G-11 1~~"IM ( LEAK DETECTION LOG 01/10/03 1 1A-08 I ì 'X-alD LEAK DETECTION LOG 01/07/03 1 2U-02 I~....OOS LEAK DETECTION LOG 01/11/03 1 2N-349A dOD-/3'1 INJECTION PROFILE 12/20/02 1 3S-09 ~-aD5 JEWELRY LOG/PSP 12124/02 1 1C-22 aDd·~~d PERF RECORD & POST PERF SBHP 01/17/03 1 3S-10 ~d "d3~ PERF/JEWELRY/PSP 01/15/03 1 1Y-21 I 3 - J Dd STATIC PRESSITEMP LOG 01/14/03 1 1 Y -34 1'1 3-0~ f STATIC PRESSITEMP LOG 01/14/03 1 SIG~ ~ LL~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD Color -- ·c~ RECCIVED FEB 07 2003 Alaalœ or¡ & Gas Cons. Cornrni!eion AnchCf!gÐ ) Conocóí'hilUps ) 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 January 31, 2003 (l '-'S)D,?:) 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-10 Dear Sir or MadaIn: Phillips Alaska, Inc. hereby requests that 3S-10 be permitted for annular pumping of fluids occurring as a result of drilling operations, per r1egulation 20 ACC 25.080. It is intended to begin annular disposal operations on 3S-10 by 212012003. 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 Drilling Report during cement job 5. Casing and Fonnation 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 Existing Adjacent Wells 10. Details on wells 3S-07, 3S-09, and 3S-14. If you have any questions or require further information, please contact Scott Lowry at 265-6869, or Randy Thomas at 265-6830. Sincerely, /~;¡¡ f L¡ Scott Lowry Drilling Engineer ) ) Note to File Well 3S-10 PTO 202-232 Sundry 303-033 ConocoPhillips Alaska, Inc. requests approval for annular disposal in the subject well. This note analyzes information submitted by the applicant, affirms me- chanical integrity of all wells within 3S-10's area of review (AOR), and recom- mends approving this request for annular disposal. 3S-10 9-5/8" surface casing was cemented with 435 bbls lead cement followed by 120 bbls tail cement, totaling about 2000/0 excess cement relative to gauge wellbore. 65 bbls of lead cement circulated to surface during initial placement, during which full returns circulated. Successful placement of such volumes of cement indicates that 3S-1 O's surface casing is adequately cemented. The formation below the 9-5/8" casing shoe supported an 17.0 ppg EMW leak off test. Applied pressure dropped 615 psi (from 1175 psi) during pump in and stabi- lized at 370 psi for 10 minutes. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 16.4 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pressure reached a maximum of 630 psi. The pressure then stabilized and shut in pressure varied between 580 psi and 400 psi over 10 minutes. Cementing records indicate mechanical integrity of the wells (38-07, 38-09, 38-14) within 38-10's AOR. The surface casing in this well is set below the West Sak Fm. in the Colville mudstone interval. This interval has frequently been used for successful annular disposal operations in the western portion of the KRU. The above referenced in- jectivity test is typical for the Colville mudstone. This formation has a well docu- mented history of receiving and confining typical annular disposal volumes below the surface cåsing shoe. Well 3S-10 is located within the EPA granted surface down KRU aquifer exemp- tion area. Based upon information submitted, AOGCC recommends approval of Conoco- Phillips's request for annular disposal in Well 3S-10 (PTO 202-232). W&Â- ¿Is lOv~ Winton Aubert Petroleum Engineer AOGCC ~/è: 0-Äo::> 3 Robert Crandall Geologist AOGCC ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) \AlGA- -z-/sl t9'~ ).A vf.> 2 / s-j iJ ;;. YJ/S <.J IÒ!t:2.:S 1. Type of request: APPLICATION FOR SUNDRY APPROVALS Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2501'FNL,993'FEL,Sec. 18,T12N, R8E,UM At top of productive interval 1694' FSL, 1044' FWL, Sec. 8, T12N, R8E, UM At effective depth At total depth 1746' FSL, 1060' FWL, Sec. 8, T12N, R8E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8130 6176 7940 5989 Casing Conductor Surface Production Length 80' 3340' 8085' Size 30" x 16" 9.625" 7" Perforation depth: measured 7802' - 7842' true vertical 5853' - 5893' Tubing (size, grade, and measured depth 3.5", 9.3#, L-BO @ 7753' Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _XX Exploratory Stratigraphic _ Service (asp's: 476266, 5993915) (ASP: 478301,5998103) (ASP: 478332, 5998155) feet Plugs (measured) feet feet Junk (measured) feet Cemented 81 sx Arctic Crete 570 sx AS Lite, 300 sx LiteCrete 250 sx Class G // Re-enter suspended well _ Time extension Stimulate Variance Perlorate 6. Datum elevation (DF or KB feet) RKB 28 7. Unit or Property name Other _X /' Annular Disposal Kuparuk River Unit 8. wellnUmb¡ 3S-1 0 9. Permit number / approval number 202-232 / 10. API number 50-103-20440 11. Field / Pool Kuparuk River Field I Kuparuk Oil Pool Measured Depth 108' 3368' 8113' True vertical Depth 108' 2601' 6159' \. . ::,.. ~ . ~ l \...: ()OOj''''' t. u A!as~m Wi & iJ31Sì CmßàŒ¡~~¡~i~a¡ , ¡ Plnch!)ra~:Îe¡ .. . Packers & SSSV (type & measured depth) Baker SAB-3 pkr @ 7721' , Landing nipple @ 498', No SSSV Description summary of proposal _XX Detailed operations program BOP sketch Refer to attached morning drilling reports, surface cement details and casing detail sheets, Leak-Off Tests _XX 14. Estimated date for commencing operation ./ 15. Status of well classification as: February 20, 2003 16. If proposal was verbally approved 13. Attachments Oil _XX /' Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'~ \ ~ R. Thomas I Title: Kuparuk Drilling Team Leader Gas Suspended _ Questions? Call Scott Lowry 265-6869 ·~...f c.l rv ) Date Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. .::<03 ~..3 Plug integrity _ BOP Test Location clearance --.J -O....J '') ~ " " Mechani.~all~tegrity T:st _. Subsequent form required 10- Qe.po rof of Ols."L-HIA./çp: cJ.í.·~po.sl't.l. 't,,, bZy A;;t.-( 1.1 ~ · °,-50 (e) (J... ') I Rl ;.; ~ v.,~ .,...t..-e ¡ e. l ~ $ f' 0 ~ ~ ( r ~ s ~ k ,~<. W;Aµ ~ f B '!-CR.( d . .[,~ l l~, (A,'-f\-k~ /4'.. P7·~ S ~ u-< G t-eL-\. M œ l' c.(,V\i ,'-1:\ i-Lt I e..~ IL c ~f- t- -e c;,. f . \. \ r 1 Approved by order of the Commission Commissioner Date ~ \ \ V Ut<I~INAL SIGNED BY V M l. BiU:: ~ R B n M S B F l FEB I 2 200] SUBMIT IN TRIPLICATE Form 1 0-403 Rev 06/15/88 · .; J \. ) ) Annulus Disposal Transmittal Form - Well 35-10 A. Designation of the well or wells to receive drilling wastes: B. The depth to the base of freshwater aquifers and permafrost, if present. 38-10 No Aquifers / Base Permafrost = +/- 1546' TVD RKB ,,/ C. A stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the Cement top all that is open / open annulus and other information sufficient to support is interbedded claystone, siltstone and shale with a commission finding that the waste will be confined and occasional minor non-hydrocarbon bearing sands. will not come to the surface or contaminate freshwater. D. A list of all publicly recorded wells within one-quarter 8ee attached horizontal plane clearance plot indicating mile and all publicly recorded water wells within one mile three wells (38-07,38-09,38-14) within 1/4 mile of the of the well to receive drilling waste. surface casing shoe of 38-10. There are no potable water wells within one mile of 38-10. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. G. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: H. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: I. Any additional data required by the Commission to confirm containment of drilling wastes: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 2,000 psi. 8ee attached calculation page. 8ee attached: cementing reports, LOT / FIT reports and casing reports. 8ee attached casing summary sheet and calculation pages. ~ ~ :J :J en en en en Q) Q) C. 0. (¡; (¡; "'C "'C ct1 ct1 Q) Q) .s::. .s::. ïñ ïñ a. 0. 0 0 It) It) ('I) ('I) ..... ..... + + iE: iE: ïñ ïñ a. 0. ..... ..... ..... ..... 0 0 en en ct1 ct1 <.9 <.9 L Well 3S-10 Date 1/30/2003 ~ 9 5/8" Surface Csg ----------- .--- --- --TÕC-Ë-ŠC@-7"ÕÕ3' MDI 5093' TVD Z~ 31/2"Tb£ L ~ 7" Production Csg ) TVD 2601 ft. ) Assumptions g ,,:t) Maximum injection pressure of 1500 psi '" 1 ~ @ I ~ PP1 } l"'S'O t \ Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is .4316 psi/ft Gas lift gas pressure is 0.11 psilft + 1350 psi header pressure Maximum Pressure at Surface Shoe Max Disposal MW /" 12.0 ppg 2000 psi .¡ Max Pressure at Surface Shoe = ") 1!Q "\ l7. /,01 :. ~~ t030 +. d,t;Ll'lA J" ~ " ~s.1..~ O~ 2.. ¡ 1t.)(¡Ô~1 )'= ~OC r' -~ L ! 1-Ùt.")l2hOI): ':!- I~ol- .0; Max Pressure at Surface Shoe ffO~-<' Max Press=Max Disposal Press+(Max Disposal MW)(.052)(TVD)-(Fluid WI. On Backside)(.05~)(TVD) (LOT performed on surface casing shoe to 17.0 ppg EMW or 2~ psi) ./ Production Casinq Size Wt. Grade Pcollapse @ 100% Pcollapse @ 85% Gas Depth (TVD) Gas Gradient Max Disposal Pressure Gas Lift Header Pressure 7.000 In. 26.00 Ibs. L 80 5410 psi 4599 psi 5093 ft. 0.11 ppg 1500 psi 1350 psi Maximum Mud Weight = (to collapse casing) 18.9 ppg -¿o () 0 <.. '2.. ~ 0 , >' \(,1~' Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradlent)(Gas TVD)+Gas Lift Header Pressure-Max Disposal Press (TVD)(.052) Surface Casinq Size Wt. Grade Pburst @ 100% Pburst @ 85% Fluid Weight on Backside Max Disposal Pressure 9.625 In. 40.00 Ibs. L 80 5750 psi 4888 psi 8.3 ppg 1500 psi Maximum Mud Weight = (to burst casing) 33.3 ppg Surface Casing Burst MMW = Pb@85%+(Fluld Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) ) ) Casing Detail ,9 5/8" Surface CasinQ œ.PHILLlPS Alaska, Inc. . .. . . A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 57 to 80 24 Jts Jts 3 to 56 54 Jts Jts 1 to 2 2 Jts Nabors 7ES RT to Lnd Ring UO groove center(Load shoulder= 29.21: FMC Gen V Hanger (Pup = 2.011) (00 of hngr 15.25") 9-5/8" 40# L-80 BTC Csg TAM Port Collar 9 5/8" L-80 BTC (00 11.25", 108.81) 9-5/8" 40# L-80 BTC Csg Weatherford Model 402 Float Collar (00 10.64", 108.865") 9-5/8" 40# L-80 BTC Csg Weatherford Model 303 Float Shoe (00 10.64",108.865") TO 12 1/4" Surface Hole Rat hole 8.731 12-1/4" T.D. @ 3377' MD 2607' TVD 9-5/8" Shoe @ 33681 MD 26011 TVD RUN TOTAL 15 BOWSPRING CENTRALIZERS - 2 on jt.#1 (31 to 51 above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 51 below Float Collar) 1 per jt on Jt #3 - #12 (Total of 15 centralizers & 4 Stops) 1 in middle of jt #56,1 in middle of jt# 57 both on stop rings. Total of 95 Jts. On location (Incl extra FC & TL jt.) don It have extra FC jt on loc. Total of 8 Jts. Outside shed (Including extra float equip.) Total of 87Jts. Inside shed Run Total of 80 Jts f/ pipe shed Leave total of 7 jts in pipe shed. Use Best-a-Life 2000 pipe dope MU torque 8,800 ft/lb Remarks: Up Wt - 145k On Wt - 95k Block Wt - 30k Drifted all casing to 8.679" Well: 38-10 Date: 12/31/2002 LENGTH 29.25 2.19 981.55 3.00 2266.22 1.50 82.86 1.70 DEPTH TOPS 29.25 31.44 1012.99 1015.99 3282.21 3283.71 3366.57 3368.27 3377.00 Supervisor: Mike Thornton I Granville Rizek ) ') MPHILLlPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-10 95/8",40# L-80 BTC 12/31/02 PAGE: RIG: 1 of 2 Nabors 7ES Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet II 43.23 26 43.02 51 42.83 76 43.80 101 126 151 176 39.63 27 43.21 52 43.21 77 38.86 102 127 152 177 I 38.12 28 37.10 53 43.04 78 42.69 103 128 153 178 42.88 29 43.19 54 43.33 79 39.22 104 129 154 179 42.61 30 43.28 55 42.82 80 40.30 105 130 155 180 42.01 31 38.33 56 . 3+ 4Q,é+ 106 131 156 181 43.43 32 39.02 57 3a 4d-:-73 107 132 157 182 ¡m~IJ¡: 43.16 33 43.30 58 38.66 ~ ~ 108 133 158 183 I 43.50 34 43.33 59 41.47 84- ~ 109 134 159 184 43.15 35 36.82 60 42.98 g& ~ 110 135 160 185 43.16 36 36.72 61 38.81 00 ~ 111 136 161 186 ~¡¡Î¡i¡i 43.35 37 37.89 62 42.72 &7- ð&:47 112 137 162 187 13 43.12 38 43.26 63 37.53 88 113 138 163 188 14 42.19 39 38.03 64 39.68 89 114 139 164 189 15 42.92 40 42.72 65 39.99 90 115 140 165 190 16 43.33 41 43.27 66 43.29 91 116 141 166 191 17 38.68 42 42.48 67 42.79 92 117 142 167 192 18 42.60 43 42.85 68 43.80 93 118 143 168 193 19 43.36 44 43.07 69 36.30 94 119 144 169 194 20 43.35 45 43.25 70 42.58 95 120 145 170 195 21 43.34 46 42.69 71 42.67 96 121 146 171 196 22 43.29 47 42.89 72 38.16 97 122 147 172 197 23 39.81 48 42.93 73 39.17 98 123 148 173 198 24 43.32 49 42.81 74 42.82 99 124 149 174 199 25 38.63 50 39.17 75 40.65 100 125 150 175 200 Tot 1056.17 Tot 1034.63 Tot 1034.96 Tot 474.60 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3600.36 DIRECTIONS: TOTAL JOINTS THIS PAGE = 87 FLOAT SHOE = 1.70 FLOAT COLLAR = 1.50 HANGER = 2.19 RKB to starting head UD groove = 29.25 ) ) _PHILLIPS Alaska, Inc. œ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-10 95/8",40# L-80 BTC 12/31/02 PAGE: RIG: 2 of 2 Nabors 7ES Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 3600.36 DIRECTIONS: TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 87.00 AVERAGE JT = 41.38 ') ) C9nocQPhiHipsAla$ka .:" .".. . ..;. .".. .:.. . ", Ç~l'11ènti rig·. Repôtt Legal Well Name: 3S-10 Common Well Name: 3S-10 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: Spud Date: 12/28/2002 1 Report Date: 1/1/2003 12/28/2002 End: '" ... .... .... .. .. . . ..·..çE!mf!nt<Job .Type: prim.¡;¡~Y · · SqUeeze Open Hole Hole Size: sa TMD: (ft) sa Date: SO Type: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Kevin Anderson Pipe Movement: Reciprocating Rot Time Start: : Ree Time Start:23:00 Time End: : Time End: 08:30 Avg Torque: (ft-Ibf) Drag Up: 145 (Ibs) Cmtd. Csg: $queeieCaslng Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Max Torque: (ft-Ibf) Drag Down: 95 (Ibs) Type: Cement Casing Volume Excess %: Meas. From: 65 Time Circ Prior To Cementing: 6.00 Mud Circ Rate: 336 (gpm) Mud Circ Press: 560 (psi) Start Mix Cmt: Start Slurry Displ: Start Displ: End Pumping: End Pump Date: Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: (bbl/min) (bbl/min) Y 475 (psi) 1,000 (psi) 5 (min) Y Returns: Total Mud Lost: (bbl) Cmt Vol to Surf: 65.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Mud Data Type: Spud Mud Density: 9.8 (ppg) Vise: 102 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PVNP: 25 (cp)/28 (lb/100ft2) Gels 10 see: 9 (lb/100ft2) Gels 10 min: 18 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (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) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol:50 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/30/2003 4:07:54 PM ) ) Legal Well Name: 3S-10 Common Well Name: 3S-10 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/28/2002 1 Report Date: 1/1/2003 12/28/2002 End: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) !)t~g~'N(): 1!)IUrtY No: 20f 4 Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol:50 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: 1,940.00 (ft}To: (ft) Water Source: Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name 079 S001 046 065 0124 053 044 Description: ARCTIC SET Class: G Cmt Vol: 434.5 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Slurry Vol570 (sk) Water Vol: 262.4 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Stage No: 1SlurryNo:30f4-Additives Type Concentration Units 1.50 %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.10 %BWOC 30.00 %BWOC Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 3,368.00 (ft}To: 1,940.00 (ft) Cmt Vol: 119.6 (bbl) Water Source: Slurry Vol:300 (sk) Test Data Thickening Time: 5.32 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Purpose: PRIMARY Mix Water: 19.34 (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Units 9.00 %BWOW Class: G Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 53.1 (bbl) Other Vol: () Purpose: TAIL Mix Water: 7.44 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/30/2003 4:07:54 PM ) ) Legal Well Name: 38-10 Common Well Name: 38-10 Event Name: ROT - DRILLING Report #: Start: 8pud Date: 12/28/2002 1 Report Date: 1/1/2003 12/28/2002 End: Type Cónceritratidn 0.50 %BWOC 0.60 %BWOC 1.00 %BWOC . . .. . .. . . . . . . . .. . .. .. '. .. . .. . . ~tageNo.: <1 Slurry LNo:4'ôf4 .. Additives. D79 D46 D65 Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Interpretation Summary CBl Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Circ & Cond Mud for Cmtg Csg, Lowered Vis from 152 to 102, YP from 46 to 25, Final Circ rate 8.0 Bpm at 560 Psi, Last 70 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg RU Dowell, Pumped 10 bbls CW 100 Chern Wash, Tested Lines to 3,500 Psi, Pumped 40 bbls CW 100 Chem Wash at 8.3 ppg @ 6.5 Bpm @ 280 Psi, Dropped Btm Plug, Pumped 50 bbls of 10.5# Mudpush spacer @ 8.0 bpm @ 380 Psi with Red Dye in Spacer, Mixed & Pumped 434.5 bbls, 570 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 8.0 bpm @ 290 Psi, , Observe Nut Plug at Shaker. Switched to Tail Cmt, Pumped 300 sxs (119.6 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield,Pumped @ 8.0 Bpm @ 530 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Wash Water, Turned over to Rig, Rig Pumped 230.3 bbls of 9.8 ppg mud, Ave Disp Rate 8 bpm @ 830 Psi, Reciprocated Pipe until 50 bbls of displacement away then Pipe got Tight-Landed Pipe, Slowed to 4 bpm @ 475 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 65 bbls of 10.7 ppg Cmt back to Surlace, Had Full Returns throughout Job- CIP at 0850 Hrs 1/1/03 Printed: 1/30/2003 4:07:54 PM ) ) I JOB NUMBER I EVENT CODE 124 HRS PROG 3S-10 ODR SUPERVISOR I RIG NAME & NO. 1 FIELD NAME I OCS NO. Mike Thornton/Granville n1268@conocophillips.com Land Palm CURRENT STATUS ACCIDENTS LAST 24 HRS.? 24 HR FORECAST BOP test, PU DP, MU BHA # 3, RIH, test csg, drill, FIT,drill LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 12/29/2002 3,312.97 51.740 21.900 9.625 (in) @ 3,368.0 (ft) Dr:~srrv(pP9) 9.80 IÞp IECDI IMlJDDA,..A ÓA.II..ycÒsTI FV PVIYP . GELS WLlHTHp· FCIT.SOL ·OIUWAT %SancYMBT j:)1ì/pM 102 25/28 9/18 5.21 21 / /25.0 8.81 WELL NAME PU 5" dp,Mixing new mud FROM 00:00 TROUBLE SUB CIRC 06:30 08:00 1.50 CEMENT P PUMP 08:00 09:00 1.00 CEMENT P DISP ConocoF>hillips . . '.. .". . [)äilylJril Ii I1g~E!PC?r(.. TMD I TVD 1 DFS 3,377.0 2,606.0 4.46 AUTH MD I DAILY TANG 8,126.0 0.00 DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 12/31/2002 391,465 ILEAKOFF AFE 10027780 I NEXT CASING 7.000 (in) @ 8,126.0 (ft) 0.00 ¡·.cuM COST I 0.00 Pf/Mf CI Ca. H2S .LIME . ES I 1 REPT NO. I DATE 6 1/1/2003 ¡CUM. TANG 0.00 CUM INT ANG WI MUD 0.00 CUM COST WI MUD 856,418 AUTH. LAST BOP PRES TEST OPERATiONS S.l.JMMARY PHASE D.ESCRIPTION SURFAC Circulate and condition mud and hole f/ cement. Circ @ 85 spm wI 378 psi while recip casing. PU wt 145 k SO wt 95 K Circ @ 115 spm (8bpm) from 0100 to 0630 hrs. Circ to lower vis f/ 152 to 102, YP f/ 46 to 25. Final circ rate 8 115 spm (8 bpm) w/ 560 psi. Last 70 bbls of mud had nutplug fl marker. Total volume circulated prior to cement 3163 bbls. (523 bbls @ 6 bpm, 3163 bbls @ 8 bpm Held PJSM on cementing while circulating. SURFAC Dowell pumped 10 bbls CW 100 (8.3 ppg), tested lines to 3500 psi, pumped 40 bbls CW 100 (8.3 ppg) @ 6.5 bpm wI 280 psi, dropped bttm plug, pumped 50 bbls MudPush XL with red dye marker (10.5 ppg) @ 8 bpm w/ 380 psi. Mixed and pumped 434.5 bbls (570 sx w/ 4.28 yield) (10.7 ppg) lead cement Arctic Set @ avg rate of 8 bpm wI 290 psi. Observed nut plug @ shakers. Switched to tail cement. Pumped 119.6 bbls (300 sx w/ 2.4 yield)) Lite Crete cement @ 8 bpm wI 530 psi. Dropped top plug. Dowell pumped 20 bbls water, followed by rig displacing wI 230.3 bbls of 9.8 ppg mud @ avg rate of 8 bpm (115 spm) w/ 830 psi. Recip casing until 50 bbls mud displaced (70 bbls total fluid behind plug), then landed casing in landing ring. Slowed mud displacement to 4 bpm f/ last 10 bbls w/ 475 psi. Bumped plug w/ 1000 psi. Rig pumps 95% eft. CIP @ 0850 hrs 1/1/03 65 bbls 10.7 ppg cement returned to surface. SURFAC Dowell pumped 20 bbls water, followed by the rig pumps displacing wI 230.5 bbls of 9.8 ppg mud @ avg rate of 8 bpm (115 spm) w/ 830 psi. Recip casing until 50 bbls mud displaced (70 bbls total fluid behind plug), then landed casing in FMC 16" landing ring. Last down weight 50k. Slowed mud displacement to 4 bpm f/ last 10 bbls w/475 psi prior to bump. Bump plug w/ 1000 psi. Rig pump eft 95%. CIP @ 0850 hrs 1/1/03. 65 bbls 10.7 ppg cement returned to surface. Printed: 1/30/2003 4:08:09 PM ') ) ConocoPhilliþs .. paijlvPrilling Rep9rt 38-1 0 I JOB NUMBER I EVE~DC~DE 124 HRS PROG TMD I TVD I DFS 3,377.0 2,606.0 4.46 I REPT NO. I DATE 6 1/1/2003 WELL NAME 12:00 13:00 13:00 15:30 15:30 16:30 1.00 DRILL P 2.50 WELCTL P 1.00 WELCTL P .. ··OPERATIONSSUMMARY SUB , PHASE· DESCRIPTION OTHR 8URFAC Bleed off pressure, floats held. RID cementing equip. Flush out diverter stack! UD landing joint, UD casing elevators. Change to drilling bales & elevators. Flushed mud out of mud manifold. PULD 8URFAC UD motor and DC's left standing in derrick fl BHA # 1. NUND 8URFAC Nipple down 20" diverter equipment. NUND 8URFAC Nipple up FMC Gen V 7" casing head & 3 1/2" tubing spool. Take measurements to Rotary table. Rotary table to lower lockdown screws (7" casing head) 26.43" Rotary table to upper lockdown screws (3 1/2" tubing spool) 24.18" NUND 8URFAC Nipple up 135/8" 5,000psi BOPE. OTHR 8URFAC RU to test BOPE. BOPE 8URFAC Test 135/8" BOPE. Annular tested to 350 psi low & 3500 psi high. Held each test 10 minutes. Test to 350 psi low and 5000 psi high all other BOPE. All tests held 10 minutes. Witness of BOPE test waived by AOGCC inspector John Crisp. 16:30 19:30 19:30 20:00 20:00 00:00 3.00 WELCTL P 0.50 WELCTL P 4.00 WELCTL P 24 HR SUMMARY: Circ & cond mud & hole fl cement, reduce yield pt fl 48 to 28, reduce PV to 25, maintain 9.8 ppg MW, Dowell pump cement , rig displace, bump plug, chk floats, flush diverter, N/D, NU 135/8" BOPE, RU to test, test BOPE(witness waived by John Crisp- AOGCC) COMPANY' ConocoPhillips Nabors Doyon Universal PERSONNEL DATA NO. HOURS COMPANY 2 8perry 8un 35 Baroid 6 APC . SERVICE NO. HOURS 2 2 2 ITEM MATERIALS I CONSUMPTION ON HAND ITEM 10,715 Fuel (camp) 139 Water, Potable ON HAND Fuel Water, Drilling 4,300 -180 RESERVOIR NAME 38-07 1 R-18 G & I Prudhoe Bay 38-07 38-1 0 38-10 38-1 0 Little Red Pumping service RESERVOIR· ANDINTERV AL· DATA ZONE TOP BASE 1150 1 950 695 0 o 0 65 0 COMMENTS Printed: 1/30/2003 4:08:09 PM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: 3S-10 I Rig: Nabors 7 ES Date: 1/2/2003 Drilling Supervisor: Mike Thornton/Granville Rizek I Pump used: I #1 Mud Pump Type of Test: I Casing Shoe Test LOT/FIT ...1 Pumping down I annulus and DP. ... Hole Size: 8-1/2" i · Casing Shoe Depth I Hole Depth RKB-CHF: 26.4 Ft 3,368 Ft-MD 2,601 Ft-TVD 3,402 Ft-MD 2,621 Ft-TVD CasinQ Size and Description: 9-5/8" 40#/Ft L-80 BTC ... CasinQ Test Pressure InteQritvTest Mud Weight: 9.5 ppg Mud Weight: 9.4 ppg Mud 10 min Gel: 9.0 Lb/100 Ft2 Mud 10 min Gel: 4.0 Lb/100 Ft2 Test Pressure: 2,500 psi Rotating Weight: 91,000 Lbs Rotating Weight: 91,000 Lbs BlocksfTop Drive Weight: 26,000 Lbs BlocksfTop Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 2.2 bbls Estimates for Test: 1163 psi 1·1 I ' 1 bbls :·1 EMW = Leak-off Pressure + Mud Weight = 1030 0.052 x TVD 0.052 x 2ß01 + 9.4 EMW at 3368 Ft-MD (2601 Ft-TVD) = 17.0 ppg PIT 15 Second Shut-in Pressure, psi 400 3000· - Lost 0 psi during test, held 100% - = of test pressure. - ] ¡ .,.."'...."''''1...' L1J 0::: :::> U) U) L1J 0::: a.. 5 10 15 20 25 Shut-In time, Minutes o PIT Point 500 . . 4 o Barrels ~CASING TEST ~LEAK-OFF TEST Comments: Pump rate varied f/ 10 spm to 7 spm while performing LOT. I Volume Input VolumelStroke .... Strokes I....... 0.06981 Bbls/Strk ... I ' Casing Test Pumping Shut-in Strks psi Min psi o 0 0 2600 4 277 1 2600 8 610 2 2600 12 878 3 2600 16 1106 4 2600 20 1355 5 2600 24 1623 6 2600 28 1907 7 2600 32 2208 8 2600 36 2511 9 2600 37 2600 10 2600 15 2600 20 2600 25 2600 30 2600 30 Volume Bled Back _l:SblS Pump Rate: 8.0 Strk/min ... Pressure Integrity Test Pumping Strks psi o 0 1 50 2 170 3 225 4 275 5 360 6 440 7 500 8 600 9 660 10 720 11 750 12 790 13 825 14 850 15 900 16 950 17 990 18 1030 19 1050 20 1075 22 600 24 575 26 575 28 490 30 460 32 460 40 460 50 460 60 460 Volume Pumped 4.2 I:Sbls Shut-in Min psi o 460 0.25 400 0.5 400 1 400 1.5 390 2 390 2.5 380 3 375 3.5 375 4 375 4.5 375 5 370 5.5 370 6 370 6.5 370 7 370 7.5 370 8 370 8.5 370 9 370 9.5 370 10 370 -----' --- Voume Bled Back 1.0 I:Sbls ) ) Casing Detail 7" Intermediate Casina ConocoPhillips Alaska Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 1111 X 711 Hanger Jts 5 to 190 186 Jts 7" 26# L-80 BTCM Csg 1" 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 TD of 8-1/2" hole @ 8130' MD 6176' TVD 7" Shoe @ 8113' MD 6158' TVD Total Centralizers 1- 711 Bow cent.! stop rings 3'-5' above FS jt # 1 & 3'-5' below FC on jt Bowspring centralizer over collar on joints #2 , #3 and #5 thru #26 7" x 8-3/8" Centering guide on every jt. From #113 thru #117 (Total of 5) 7" x 8-3/8" Centering guide on every 3rd Jt. # 180, 183, 186, 189. (Total of 4) Totals: 32 Bowspring, 9 centering guides, 2 Stop collars Total of 209 jts.on location Total of 190 jts. Ran in hole Total out: 10 jts. Inside shed (last jt on tally # 190 in shed - [9 jts Outside shed not on tally) Use "Run-N-Seal" pipe dope Drifted to 6.15111 Remarks: Up Wt = 235k On Wt = 110k Block Wt= 30k Well: Date: LENGTH 26.43 2.32 7913.91 1.31 167.51 1.50 38-10 01/07/03 DEPTH TOPS 26.43 28.75 7942.66 7943.97 8111.48 8112.98 Supervisor: Mike Thornton / G. Rizek Dave Burley/Peter Wilson ') ) ConocoPhillips Alaska CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-10 7", 26# L-80 BTCM 01/07/03 PAGE: RIG: 1 of 2 NABORS 7ES Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet '.................~ :t2ß.t :~t~~~~~f~~~ 42.66 41.25 51 43.30 76 43.28 101 41.39 126 42.44 151 43.12 176 43.18 ........" :tjtJ~ 43.22 27 43.00 52 40.64 77 42.99 102 43.16 127 43.11 152 43.00 177 43.23 II 40.78 28 41.26 53 43.45 78 43.08 103 43.41 128 41.10 153 43.19 178 43.20 40.85 29 43.16 54 43.02 79 43.24 104 41.31 129 42.93 154 42.97 179 43.08 'fI'II"I',','I'I'. ~~~~~H:tI 43.05 30 42.95 55 41.30 80 43.20 105 40.97 130 41.07 155 39.98 :aa@: 43.10 \I:~:(:'(:'( .J.,.,..... ~ta.:rt 43.15 31 43.44 56 43.12 81 41.10 106 43.10 131 43.21 156 41.51 181 43.26 '....................... ::::::::$:::::: 43.04 32 41 .43 57 43.29 82 43.36 107 42.80 132 43.24 157 43.16 182 43.44 !mimr 43.25 33 42.24 58 39.77 83 43.03 108 43.30 133 42.98 158 43.15 }lj,W 43.15 \,1.'.'.'.'.'.-.'.'. :~t~~~Hf 43.41 34 42.96 59 43.19 84 43.44 109 34.88 134 42.96 159 39.56 184 42.95 ~t~f:føt 43.14 35 43.11 60 41.26 85 43.08 110 43.46 135 43.20 160 41.55 185 43.16 'f.:f.:.7:.('j1, 11:!:~m!::f 43.36 36 43.26 61 43.18 86 40.80 111 43.08 136 40.55 161 41.48 186 "¡'1.55 43.42 37 43.03 62 43.19 87 40.84 112 42.86 137 43.14 162 42.96 187 41.72 j¡¡¡¡¡~¡~r 42.25 38 42.26 63 43.93 88 43.15 HäãJ 42.24 138 43.42 163 41.85 188 43.10 .:.:'1:.:.;.:.:.:.;.... ................"... 14 " 2.43 39 43.39 64 43.44 89 43.14 i 42.31 139 43.10 164 43.22 ~~Mì~~~ 42.62 15 -13.26 40 43.00 65 42.59 90 43.18 43.32 140 42.92 165 42.36 190 40.47 .........:,.. :::::;1:ß.:::: 41.31 41 43.25 66 43.19 91 41.22 43.16 141 43.25 166 39.78 +9+ 40.49 !:¡:1Wï1 42.21 42 43.24 67 43.12 92 43.25 42.92 142 43.24 167 41.50 ~ 43.17 ':':":":":":':":':':.. ".................... !:tj~ijl 43.18 43 42.49 68 43.28 93 42.27 118 43.09 143 42.97 168 42.97 ~ 42.23 .:::f....::.::~ i~¡~¡~~~ft¡~¡~ 43.25 44 40.63 69 39.04 94 41.65 119 42.90 144 43.15 169 43.19 .:J.94 43.15 :~~~~~~~~¡~ 42.05 45 43.32 70 43.17 95 41.60 120 43.29 145 42.33 170 40.34 ~ 43.12 :(((((((((. ~t~~lt 43.37 46 42.24 71 43.28 96 43.25 121 43.08 146 43.17 171 41.82 4-9ê 43.15 :::::::::x::~:::~J :~:mgll 41.52 47 42.96 72 43.38 97 43.19 122 43.17 147 41.11 172 43.43 +97 43.07 :t~g~f 43.26 48 41.89 73 43.27 98 43.40 123 43.01 148 41.97 173 41 .44 +9S 39.56 :~¡~¡~11¡:¡~ 43.28 49 43.16 74 43.22 99 41.21 124 43.06 149 43.28 174 43.12 ~ 41.33 t¡25.t 43.16 50 43.26 75 36.83 100 43.15 125 43.12 150 43.15 175 40.59 2QG 43.26 Tot 1 067.86 Tot 1066.18 Tot 1060.45 Tot 1065.10 Tot 1062.39 Tot 1066.99 Tot 1051.24 Tot 1063.74 TOTAL LENGTH THIS PAGE = 8503.95 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 ) ) ARCO ALASKA INC CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-10 7", 26# L-80 BTCM 01/07/03 PAGE: RIG: 2 of 2 NABORS 7ES Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 ~ 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 8503.95 DIRECTIONS: TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 200.00 AVERAGE JT = 42.52 ') ) Legal Well Name: 3S-10 Common Well Name: 3S-10 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/28/2002 2 Report Date: 1/8/2003 12/28/2002 End: Hole Size: 8.500 (in) TMD Set: 8,113 (ft) Date Set: 1/8/2003 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger . Primary .. . Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Cull peper .. Squeeze Open Hole Hole Size: SO TMD: (ft) SO Date: SO Type: Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: No movement Rot Time Start: Ree Time Start: Time End: Time End: RPM: SPM: 'nit Torque: (ft-Ibf) Stroke Length: (ft) Type: Cement Casing Volume Excess %: 75.00 Meas. From: 0 Time Circ Prior To Cementing: 3.50 Mud Circ Rate: 210 (gpm) Mud Circ Press: 600 (psi) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) ·StägeNo:t of1 Start Mix Cmt: 23:30 Start Slurry Displ: 00:26 Start Displ: 00:45 End Pumping: 02:00 End Pump Date: 1/8/2003 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 12.3 (ppg) Visc: 49 (s/qt) Bottom Hole Circulating Temperature:130 (OF) Displacement Fluid Type:Seawater Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: M lid· Data 5.00 (bbl/min) 5.00 (bbl/min) Y 1 ,700 (psi) 2,325 (psi) 2 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch Density Meas By: press scal PV/yP: 23 (cp)/18 (lb/100ft2) Gels 10 sec: 9 (lb/100ft2) Gels 10 min: 14 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 8.4 (ppg) Volume: 308.00 (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: (bbl) Time Compressive Strength 1: Compressive Strength 2: Class: Yield: (ft3/sk) Other Vol: 0 Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/30/2003 4:09:08 PM \} l ) Legal Well Name: 3S-10 Common Well Name: 3S-10 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/28/2002 2 Report Date: 1/8/2003 12/28/2002 End: . . ".' .... . .... . St~ge No: 1Sh..rry~~:~ Of3. Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 7,003.00 (ft}ro: 5,675.00 (ft) Cmt Vol: (bbl) Density: 13.30 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 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) Stage No: 1 Slurry N9: 3013 . Slurry Data Fluid Type: TAIL Description: Gasblok Slurry Interval: 8,113.00 (ft}ro: 7,003.00 (ft) Cmt Vol: 52.0 (bbl) Water Source: Slurry Vol:250 (sk) Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: 32.0 (bbl) Other Vol: 0 Purpose: ZONAL ISOL Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: 3.70 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) D-65 D600G D-47 Type DISPERSANT Gasblok DEFOAMER COncentration Units 0.30 %BWOC Stage No: 1 Slurry :No:30f3 - Additives 2.00G P S 0.20 G P S Printed: 1/30/2003 4:09:08 PM ') ) Legal Well Name: 3S-10 Common Well Name: 3S-10 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/28/2002 2 Report Date: 1/8/2003 12/28/2002 End: $hbeTest Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) H rs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N L9g1Sur,,~y Evaluation 1r1ter~retati()n Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remark$ Rig Up Dowell, Batch mix 15 bbls CW100 @ 8.3 ppg, 30 bbls MudPUSH @ 13.4 ppg, 250 sxs (52 bbls) @ 15.8 ppg Class "G" GasBLOK and 1/4 #/sack celloflakes wi + .300%BWOC D65, .020%BWOC B155, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 5 bbls CW100, Test lines to 4,0000 psi, Pump 15 bbls CW100, Drop #1 btm plug, Reload head, Pump 30 bbls MudPUSH at ave. rate of 5 bpm at 950 psi, Drop #2 btm plug, Pump 52 bbls cmt at ave rate of 5 bpm at 1,200 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 225 bbls of 8.5 ppg seawater at rate of 5 bpm at 975 psi until MudPush around shoe, Slowed rate to 4.0 bpm @ 820 psi until last 30 bbls of displacement then slowed rate to 3 bpm @ 1700 psi & bumped plug wi total of 308 bbls, Bumped plug wi 2300 psi, Checked Floats & Held, Bled back 2.3 bbls for a total of 305.7 total bbls displaced (Calculated 304.1 bbls), CIP @ 02:00 hrs 1/9/03, Had full returns throughout, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. Printed: 1/30/2003 4:09:08 PM ) ) I JOB NUMBER I EVENT CODE 124 HRS PROG 3S-10 ODR SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. Dave Burley/Peter Wilso n1268@conocophillips.com Land Palm CURRENT STATUS ACCIDENTS LAST 24 HRS.? 24 HR FORECAST NU&Test Tree, Freeze Protect Well, LD DP, RD & Move to 3S-15 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 1/4/2003 8,130.00 10.170 31.750 7.000 (in) @ 8,112.0 (ft) DEN?ITY(ppg) I 8.50 IÞPI IECD[ IIVIÚDDATAIDAILYÇOST¡ .IW PVIYP .·GELS WUHTHP Fcrr~SOL qlUWAT .%Sand~BTPh/pl\ll 28 / I / I / / OPERATIONS SUIVIMARY PHASE DESCRIPTION PROD Rig Up Dowell, Batch mix 15 bbls CW100 @ 8.3 ppg, 30 bbls MudPUSH @ 13.4 ppg, 250 sxs (52 bbls) @ 15.8 ppg Class "G" GasBLOK and 1/4 #/sack celloflakes w/ + .300%BWOC D65, .020%BWOC B155, 2.000 gal/sk D600G, .200 gallsk D47, Pump 5 bbls CW100, Test lines to 4,0000 psi, Pump 15 bbls CW100, Drop #1 btm plug, Reload head, Pump 30 bbls MudPUSH at ave. rate of 5 bpm at 950 psi, Drop #2 btm plug, Pump 52 bbls cmt at ave rate of 5 bpm at 1,200 psi, Shut down, DISP PROD Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 225 bbls of 8.5 ppg seawater at rate of 5 bpm at 975 psi until MudPush around shoe, Slowed rate to 4.0 bpm @ 820 psi until last 30 bbls of displacement then slowed rate to 3 bpm @ 1700 psi & bumped plug wI total of 308 bbls, Bumped plug w/ 2300 psi, Checked Floats & Held, Bled back 2.3 bbls for a total of 305.7 total bbls displaced (Calculated 304.1 bbls), CIP @ 02:00 hrs 1/9/03, Had good circ. thru out job- no noticeable mud loss, Displaced entire job with Dowell. Unable to reciprocate Pipe During Cement Job. Check flow- Well static. PROD RD Cement Head, LD Landing Jt, Blow Down Dowell's Line and Flushed Out BOP's and Surface Lines, Blow Down Lines to Pumps. PROD Set 7" Pack-off & Ran in Lock Down's, Tested Pack-off to 5,000 psi PROD Changed Out Long Elevator Bales & Fin Rd 7" Csg Tools CMPL TN PU & RU Nabors 3 1/2" Handling Tools for Completion CMPL TN Cleaned Up Around Rig Floor CMPL TN Held PJSM, MU 3 1/2" completion equipment: WLEG w/ shear out sub / pup - Cameo "D" nipple w/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 31/2",9.3#, L-80 tbg - Cameo "DS" nipple w/2.813 profile - 1 jt tubing- pup - Cameo MMG w/ DCR shear valve - pup - RIH with Completion Assembly with 4 GLM's Per Well Plan, Ran 241 Jts of 31/2" 9.3# L-80 EUE-Mod Tbg to 7,752', Up Wt 95K, Dwn WT 60K DEQT CMPL TN RU to Test 7" Csg, Tested Lines to 3,700 psi, Tested Csg to 3,500 Psi for 30 Min, Good Test PCKR CMPL TN Drop 2" Ball - MU Pump in Sub - Position Packer on Depth. With Ball on Seat Pressure Tubing to 2,500 psi for 5 min, No Loss, Bled to -0-, Slacked Off 15K, Pressure Up to 3000 psi, held 5 min. Bled Pressure Down to 1,000 Psi, PU to 130K & Sheared PBR, Press Up to 3,200 psi & Sheared Ball Seat - Pressure WELL NAME NU Tree 00:45 02:00 1.25 CEMENT P 02:00 04:00 2.00 CEMENT P RURD 04:00 05:00 1.00 WELCTL P OTHR 05:00 06:30 1.50 CEMENT P RURD 06:30 07:30 1.00 CMPL TN P RURD 07:30 08:30 1.00 RIGMNT P RSRV 08:30 18:00 9.50 CMPL TN P RUNT 18:00 20:00 2.00 CMPL TN P 20:00 21 :00 1.00 CMPL TN P ·ConocoF't'I.Uips . p~ilyDrillihg Report TMD I TVD I DFS 8,130.0 6,176.0 11.46 AUTH MD I DAILY TANG 8,126.0 0.00 DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 1/6/2003 391,547 I LEAKOFF AFE 10027780 I NEXT CASING LAST BOP PRES TEST 3.500 (in) @ (ft) 1/2/2003 0.00 ICUMCOsil 0.00 Pf/Mf CI Ca H2S .. LIME· ES / I REPT NO. I DATE 13 1/8/2003 CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 2,058,668 AUTH. Printed: 1/30/2003 4:10:49 PM ) ) 3S-1 0 Cono.coPhi Ilips '" . . ....... . ., . .... ... . . Délily.. Dril n.,gR~port I JOB NUMBER I EVE~DC~DE 124 HRS PROG I T~~130.0 WELL NAME ITVD IDFS 6,176.0 11.46 I REPT NO. I DATE 13 1/8/2003 23:30 00:00 0.50 WELCTL P OPERATIONS SUMMARY PHASE DESCRIPTION CMPL TN up tubing to 3,700 psi, Bled to -0- & Rd Circ Hose, SIM Op's Performed LOT on 7" x 95/8" Ann for Injectivity Test and Broke Down at 560 psi for a 16.4 ppg EMW, Flushed Annulus with 313 bbls Water and Freeze Protected with 75 bbls Diesel, (388 bbls Total Pumped Down 3S-10 Ann) SOHO CMPL TN LD Landing Jt & Spaced Out, MU Hanger & Landed 3 1/2" Tbg, Ran in Lock Downs, Landed with WLEG @ 7,752', Pkr Set @ 7,720', GLM's Per Well Plan with Camco "DS" Nipple with 2.875" No Go @ 498' DEQT CMPL TN RU & Tested 3 1/2" Tbg to 3,500 psi for 15 Min, Good Test, Bled to 1,500 psi, Press Up on 31/2" x 7" ann and Pressure Tested to 3,500 psi for 15 Min, Good Test, Bled Tbg Press to -0- and Sheared RP Valve, Bled Well to -0-, RD Test Lines & Blew Down Same OTHR CMPL TN Installed TWC in Wellhead FRbM 20:00 21 :00 22:00 1.00 CMPL TN P 22:00 23:30 1.50 CMPL TN P 24 HR SUMMARY: Ran & Cemented 7" Csg, Ran 3.5" Completion Assembly Per Well Plan, Tested 7" Csg to 3,500 Psi for 30 Min, Set Pkr, Tested 3.5" Tbg and 3.5" x 7" Ann to 3,500 psi for 15 Min Each & Installed TWC PERSONNEL DATA NO. . HOURS COMPANY. 2 Baroid 34 APC 6 FMC 2 . HOURS· ITEM UNITS gals bbls USAGE 2,736 1,162 MATERIALS/CONSUMPTION ON HAND ITEM 6,586 Fuel (camp) 246 Water, Potable . ON HAND 1,932 14,130 Fuel Water, Drilling 4,710 RESERVOIR NAME 3S-07 1 R-18 G & I Prudhoe Bay 3S-10 3S-10 3S-10 RESERVOIR ANDJNTERVALDATA ZONE TOP BASE 1586 3 700 o 0 o 0 COMMENTS Printed: 1/30/2003 4:10:49 PM PRESSURE INTEGRITY TEST PHilLIPS Alaska, Inc. Nabors 7ES . Date: 1/8/2003 I Pump used: I #1 Mud Pump ....1 Pumping down I annulus. I Hole Depth 7,003 Ft-MD 5,090 Ft-TVD I ...\ Well Name: 3S-10 Rig: Drilling Supervisor: Dave Burley/Peter Wilson Type of Test: I Annulus Leak Off Test for Disposal Adequacy Hole Size: 12-1/4" ... Casing Shoe Depth RKB-CHF: 26.4 Ft 3,368 Ft-MD 2,600 Ft-TVD Casina Size and Description: 9-5/8" 40#/Ft L-80 BTC Chanaes for Annular Adequacy 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 IntearityTest Mud Weight: 12.3 ppg Inner casing aD: 7.0 In. Desired PIT EMW: Estimates for Test: 16.0 ppg 500 psi 0.8 bbls ...j EMW = Leak-off Pressure + Mud Weight = 560 0.052 x TVD 0.052 x 2600 + 12.3 EMW at 3368 Ft..MD (2600 Ft..TVD) = 16.4 PIT 15 Second Shut-in Pressure, psi 500 1000· UJ ex: ::::> en en UJ ex: c.. ~.w............ ~ I ~ I. 500 2 467 Barrels 80S 10 1 S 20 2S 30 Shut-In time, Minutes o PIT Point Comments: ~CASING TEST Initial LOI = 16./ ppg EMW ~LEAK-OFF TEST i Casing Test Pumping Shut-in Strks psi Min psi I Volume Input ... i Strokes i ~ I.... ¡... Volume/Stroke 0.0698 Bbls/Strk ~ o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Bled Back _l::Sbls Pump Rate: 10.0 Strk/min ... Pressure Integrity Test Pumping Shut-in Strks psi Min psi o 0 0 580 4 110 0.25 500 8 240 0.5 460 12 360 1 440' 16 460 1.5 420_ 20 560 2 410 24 600 2.5 410 28 540 3 400 32 540 3.5 400 36 540 4 400 40 600 4.5 400 44 610 5 400 48 610 5.5 400 52 610 6 400 56 600 6.5 400 60 610 7 400 64 620 7.5 400 68 620 8 400 72 620 8.5 400 76 630 9 400 80 630 9.5 400 84 630 10 400 88 630 92 630 96 630 ~. Vo ume Bled Back I::Sbls :s~ +SI-S +EJ.W 3S·1O 70.93 ·188.89 -1597 -1500 -1250 -1000 -750 -500 -250 -0 -250 -500 -750 -1000 -1250 -1500 -1597 I\fELL DEf AILS SortM1;; &.sling L:.titud< Longilud< Slot 599391~.52 ~76266.35 70'23'40.21T.'< 15O'1l'35.178W SJA ANTI-COLLISION SETTINGS Interpolation Method:TVD Interval: 1.00 Depth Range From: 2600.00 To: 2602.00 Maximum Range: 1??oo.00 Reference: Survey: 3S-1O ~- /~. I( ~. \ I \ \<) \ \ \ \ ~.14(3\ ~ ~ . 24 \. ~... .... .............. ~ ......~ 270 COMP A.'¡Y DErAILS WEliPATH DErAILS P~s~l:'_Inc. ïru;,~'" 3S·10 501032044000 o c.JcuJation :\!clhoo: MiniIrum Curvature fc'::~:t ~~~ PIare &ror Surfaœ: Ð.liptical + Casing W=iDg :\"""00: Ruks Based Rig: N·7ES Ref. Datum: 3S·1O:S6.3 omit V-S'l;;k ~~_~ ~ ~~VD 25.SO' 0.00 0.00 OJ)() 1507 1500 1250 1000 \ 90 ._~ 15ûu 1/4 Mile Radius of 38-10 ... 9-5/8" Csg Pt (@ 3368' MD /2601' TVD) 180 U~I Reference Azimuth Angle [deg] vs Centre to Centre Separation [500ft/in] ') ) CO.,.oçoPhiIUþsAlasl<a:,..lnc. [] I,i.!...'.,'.'...·....:.....'...:-....."~ ,f¡,:. ':!!;., 11,;-......',..:.......,..',.'.. ,,': Ill:. ;j; I.-.·.··.-,....·..-'~ it} 1,1\ '1;: 1'.'.'.·.,.'.....".'....'.'·.'-"}( ';1' ~, ..".'..:.....:-..ë,Ii .... P.', ~~Ti:, I! : II I .1 '/ ' . 'i¡·i:!lt:!I'¡'"j J ~I' Ç1~1 ,*!,1~i"~!:~I,t\1\.'1:11(.: ~ ¡'¡ ~,,11 Anchor Nipple (6271-6272, OD :4.740) PACKER (6272-62T7, OD :5,956) ~ U Perf (6388-6413) KRU 3S-07 35-07 API: 501032043000 SSSV Type: Nipple Well Type: PROD Orig 11/21/2002 Completion: LastW/O: Anç¡le @¿ TS: 10 deç¡ @¿ 6388 Angle @ TO: 9 deg @ 6633 Ref Loç¡ Date: TO: 6633 ftKB Max Hole Angle: 30 deg @ 1999 Rev Reason: Tag fill, pull CR LocklGauç¡es Last Update: 1/29/2003 Top Bottom TVD Wt Grade Th rea d 0 108 108 62.50 H-40 WELDED 0 2769 2580 40.00 L-80 BTCM 0 6623 6081 26.00 L-80 BTCM TVD Wt I Grade Th read 5767 9.30 L-80 EUE8RD Status Ft SPF Date Type Comment 25 6 11/26/2002 IPERF 1.5" HSD PJ 2506, 60 deg phasinç¡ Annular Fluid: Reference Log: RKB 24.1 0' Last Tag: 6307 LastTag Date: 1/22/2003 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 6388 - 6413 5849 - 5874 Bottom 6304 Zone C-4 Gas Lift Mandrels/Valves St MD TVD Man Man Mfr Type 1 2790 2598 CAMCO KBUG-M 2 4063 3725 CAMCO KBUG-M 3 4991 4548 CAMCO KBUG-M 4 5637 5131 CAMCO KBUG-M 5 6157 5623 CAMCO MMG Other C3lugs, equip., etc.' - JEWELRY Depth TVD Type 24 24 HANGER 495 495 NIP 6209 5673 SLEEVE-C 6257 5720 PBR 6271 5734 Anchor Nipple PACKER BAKER SAB-3 PACKER EXTENSION 4.5" 80-40 MILLOUT EXTENSION NIP CAMCO '0' NIPPLE WITH NO GO PROFILE WLEG BAKER PUMP OUT SUB TIL V Mfr V Type V OD Latch Port TRO DMY DMY DMY DMY DMY 1.0 1.0 1.0 1.0 1.5 BK-5 BK-5 BK-5 BK-5 RK 0.000 0.000 0.000 0.000 0.000 Description FMC 3.5" GEN 5 TUBING HANGER w/EUE 8RD CONNECTION CAMCO 'OS' NIPPLE WITH NO GO PROFILE BAKER CMU SLIDING SLEEVE - closed BAKER 80-40 PBR BAKER KBH-22 ANCHOR TUBING SEAL 6272 5735 6277 5740 6296 5759 6303 5766 6304 5767 General Notes Date Note 11/21/200~ TREE: FMC/GEN5/S TREE CONNECTION: TOP 5.75" ACME W/3.5" EUE8RD THREAD o o o o o Date Vlv Run Cmnt 11/21/2002 11/21/2002 11/21/2002 11/21/2002 11/24/2002 ID 3.500 2.875 2.813 3.000 2.993 2.992 3.730 2.750 3.000 2.992 ) ) Casing Detail 9 5/8" Surface CasinQ _PHILLIPS Alaska, Inc. . . A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 46 to 70 Nabors 7ES RKB to Landing Ring FMC Gen V Hanger 25 Jts 9-5/8" 40# L-80 BTC Csg TAM Port Collar 40# L-80 BTC 43 Jts 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Collar . 2 Jts 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Shoe Jts 3 to 45 Jts 1 to 2 TO 12 1/4" Surface Hole RUN TOTAL 14 BOWSPRING CENTRALlZERS- 2 on jt. #1 (10' up across stop ring and over collar) 1 on Jt. #2 (across stop ring 10 I below FC) 1 per jt on Jt #3 - #13 Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 160k Dn Wt -130k Block Wt - 70k Well: 3S-07 Date: 11/13/2002 LENGTH 28.80 2.20 969.34 3.00 1681.08 1.48 81.74 1.71 Supervisor: David Burley DEPTH TOPS 28.80 31.00 1000.34 1003.34 2684.42 2685.90 2767.64 2769.35 2776.00 ') ) ConocoPhillips Alaska Cem:enting Report Legal Well Name: 38-07 Common Well Name: 38-07 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 2,767 (ft) Date Set: 11/13/2002 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Sehlumberger Rot Time Start: : Ree Time Start:20:00 P~ge 1.~f 3' Report #: Start: 8pud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 Cement Job Type: Primary 'Squeeze Open Hole , Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Rick Gallegos Cmtd. Csg: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating Time End: : Time End: 00:30 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 150 (Ibs) Type: Cement Casing Volume Excess %: 250.00 Meas. From: 45 Time Cire Prior To Cementing: 3.00 Mud Circ Rate: 336 (gpm) Mud Circ Press: 430 (psi) Stage No: 1 of 1 Start Mix Cmt: 22:43 Start Slurry Displ: 22:44 Start Displ: 00:14 End Pumping: 00:44 End Pump Date: 11/15/2002 Top Plug: Y Bottom Plug: Y Type: Spud Mud Density: 9.8 (ppg) Vise: 75 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) N 315 (psi) (psi) (min) Y Max Torque: (ft-Ibf) Drag Down: 110 (lbs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 45.00 (bbl) Ann Flow After: N Mixing Method: Dir blow Density Meas By: densometer PVIYP: 34 (cp)/31 (lb/100ft2) Gels 10 see: 10 (lb/100ft2) Gels 10 min: 17 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.8 (ppg) Volume: 204.00 (bbl) Mud. Data Stage No: ·.1 Slurry No: 1 of 4 To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: 50.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11 :27:30 AM "- ') Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) ) "ÇonocoPhilHpsAiaska " Cementing, Report: -< ": . .., Pa"g~, 2' :cit""~"," .. Report #: Start: Spud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 Stage No: 1 Slurry No: 2 of 4 Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Slurry Data Fluid Type: LEAD Slurry Interval: 1,605.00 (ft}To: 29.00 (ft) Water Source: Lake water Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 4 Description: ASLite Cmt Vol: 432.0 (bbl) Slurry Vol:590 (sk) Class: Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Water Vol: 280.0 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Stélge No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 2,769.00 (ft}To: 1,605.00 (ft) Cmt Vol: 74.0 (bbl) Water Source: lake Slurry Vol:220 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Class: Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 38.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 19.93 (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 7.45 (gal) Foam Job: N Pressure (psi) (psi) Printed: 11/23/2002 11:27:30 AM ') ') ¡ ConocQ,PhilHps "AI~ska Cementi ngReport-" " "I?a9~ àhf~ Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 C"asing Test " " ,Shoe Test " Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: LogiSurvey Evaluation Interpretation Summary CBl Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield Pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chern Wash, Dropped Btm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt. Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 Bpm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs. Pumped 220 sxs of 12.0 ppg, 2.4 cf/sx Lite Crete tail cmt at 6 bpm 1350 psi. Dropped top plug - cementers displaced with 20 bbls FW - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud . average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe untilllast 80 bbls of displacement· had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. Printed: 11/23/2002 11 :27:30 AM .) ) i, ,I. CO~óCOPhimps,AÎaska .. . . ' . . . ," . Daily,DriUing Report· 3S-07 SUPERVISOR 1 RIG NAME & NO. David Burley/Peter Wilso N1268@ppco.co CURRENT STATUS I JOB NUMBER I EVE~DC~DE 124 HRS PROG I FIELD NAME I OCS NO. Nabors 7ES Kuparuk River ACCIDENTS LAST 24 HRS.? TMD I TVD 1 DFS 2,776.0 2,586.0 5.00 AUTH MD I DAILY TANG 6,611.0 0.00 DAILY INT W/O MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 11/11/2002 312,453 LEAKOFF AFE WCD.K3S.0045.01 I NEXT CASING 9.625 (in) @ 2,770.0 (ft) 0.00 I CUM bpST I pflMf CI Ca ' H2S / WELL NAME ND Divertor 24 HR FORECAST NU Wellhead & BOPS, Test BOPE, PU 8 1/2" Drlg Assembly LITHOLOGY .1 JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 11/12/2002 2,701.33 25.450 54.050 16.000 (in) @ 108.0 (ft) ,'DJ:NSI"!"(ppg) I 9.80 ppl IECD IMUDDATA DAILY:COST ,FV'. PVIYP:, GELS ,WUHTHP FCfT.SOL OIUWAT· %SandIMBT : Ph/pM 75 34/31 10/17 5.0/ 2/ I 121.0 I BHA ,NO. :1 2 I' BHA i HO,lE CONDITIONS aHA WT. BELOW JARS STRING WT. UP STBING WT. DN STRING WT. RPT ITEM DESCRIPTION NO JTS Bit Mud Motor Float Sub Pony Collar - Non Mag Stabilizer LWD GR/RES MWD DIR LWD DEN/NEU MWD HOC Crossover Flex Collar - Non Mag Drill Pipe - Heavy Wgt Hyd Jars Drill Pipe - Heavy Wgt 1 1 1 1 1 1 1 1 1 3 9 1 14 LENGTH 1.20 29.28 2.24 6.03 5.26 22.84 9.20 25.13 9.94 2.77 90.42 272.23 31.71 422.20 O.D. 12.250 8.000 8.000 8.000 8.000 8.000 8.000 8.110 8.000 7.750 6.500 5.000 6.250 5.000 TORQUE/UNITS I.D. 4.000 5.250 2.500 2.810 2.875 2.900 3.450 2.900 2.815 2.750 2.813 3.000 2.750 3.000 . ','I, j, P:ag~ :1 'ot.~" ' I REPT NO. I DATE 13 11/13/2002 ICUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,533,678 AUTH. 2,484,894 LAST BOP PRES TEST 0.00 LIME ,E$, BITNO. I 2 BHALENGTH 930.45 . CO~N SIZE CONN TYPE, . BITS BIT I RUN ,. SIZE . M~NUF. TYPE SERIAL, NO. JE.TS QR TFA DEPTH IN· DATE IN I-O-D-L-B-G-O-R 1/ 1 12.250 HTC MX-C1 5012523 24/24/24/1 all 228.0 11/9/2002 0-0------ 2/ 1 rr1 12.250 HTC MX-C1 5012523 24/24/24/1 all 228.0 11/9/20022-3-WT-A-E-1-NO-TD BIT OPERATIONS BIT I RUN I': WOB RPM !'GPM I ,PRE:S,S I f' 8'IT' I HRS', I ·24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP, FROM " TO HOURS CODE TROUBLE SUB: 00:00 02:00 2.00 DRILL P TRIP 02:00 05:30 3.50 DRILL P TRIP 05:30 08:00 2.50 CASE P RURD 08:00 09:00 1.00 CASE Np EQIP RURD 09:00 09:30 0.50 CASE P SFTY 09:30 16:00 6.50 CASE P RUNC PPER'ATIONS SUMMARY PHASE 'DESCRIPTION SURFAC Fin POOH to Flex Collar & LD Collar SURFAC Pulled Sperry Suns Nuclear Source, Downoad MWD, LD MWD & 1.5 deg MM & 12 1/4" Bit SURFAC RU Nabors Csg Tools and GBR Fill-up Tool. SURFAC Made dummy run with Hanger & Landing JT, had to center twenty inch riser to rotary table to allow centralizer on landing joint to pass. SURFAC Held Safety Mtg on Running of 9 5/8" Csg SURFAC MU 95/8" Flaot Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Printed: 11/23/2002 11 :28:57 AM . , . Cc,nQcOr+-hilUps, ·Alas:ka '. , . . D~ily DrUHngReport I JOB NUMBER I EVE~;~DE 124 HRS PROG I T~~776.0 ) WELL NAME 3S-07 ) , page:2Ótø:-:- . . IT~D IDFS . 2,586.0 5.00 I REPT NO. ] DATE 13 11/13/2002 OPERATIONS SUMMARY PHAse DESCRIPTION SURFAC Float Equip, Thread Locked Btm 3 Conn, Ran 43 Jts 9 5/8" Csg, Tam Port Collar, 25 Jts of 9 5/8" Csg, (Total of 70 Jts Ran 2,769.35') While TIH Started taking Wt at 2,626' SURFAC Est Circ at 6.5 bpm at 350 Psi, Washed Csg Down from 2,626' to 2,769', Up Wt W/Pumps on 134K, Dn Wt 94K SURFAC RD Fill Up Tool & MU Cmt Head on Landing Jt & Landed Csg in Hanger SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. SURFAC RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chern Wash, Dropped Btm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt 2,415 Cu ft of Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 Bpm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs, Reciprocated Csg During Cmt Job 24 HR SUMMARY: Fin POOH & LD LWD/MWD with MM & 121/4" Bit, RU Csg Tools, Ran 70 Jts of 95/8" 40# L-80 BTC Csg, Set Csg at 2,769', Circ & Cond Mud for Cmtg, Began Cmtg Csg FROM TO HOURS CODE mOUBLE SUB 09:30 16:00 6.50 CASE P RUNC 16:00 18:30 2.50 CASE P RUNC 18:30 19:00 0.50 CASE P RUNC 19:00 22:00 3.00 CASE P CIRC 22:00 00:00 2.00 CEMENT P PUMP COMPANY ConocoPhillips Nabors Halliburton I Sperry-Sun SERVICE PERSONNEL DATA NO. HOURS COMPANY 3 Doyon Universal 33 APC 4 Baroid SERVICE NO. HOURS, 6 2 2 ITEM . UNITS gals bbls MATERIALS I CONSUMPTION USAGE ON HAND ITEM -14,184 Water, Potable -1 ,420 . ON HAND -638 Fuel Water, Drilling UNITS bbls USAGE Printed: 11/23/2002 11 :28:57 AM ) ) / . .,. '. . '.. . ~Ol1ocoPhilli'ps,' Alaska Daily Drilling .Repo.rt· WELL NAME 3S-07 ¡JOB NUMBER IEVE~DC~DE 124 HRS PROG SUPERVISOR I RIG NAME & NO. 1 FIELD NAME I OCS NO. David Burley/Pete Wilson N1268@ppco.co Nabors 7ES Kuparuk River CURRENT STATUS ACCIDENTS LAST 24 HRS.? '. PaQe lqf 2:; PU Additional 5" DP & TIH TMD I TVD I DFS 2,776.0 2,586.0 6.00 AUTH MD 1 DAILY TANG 6,611.0 0.00 DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 11/11/2002 104,147 ILEAKOFF AFE WCD.K3S.0045.01 I NEXT CASING 108.0 (ft) 9.625 (in) @ 2,770.0 (ft) I REPT NO. I DATE 14 11/14/2002 I CUM. TANG 0.00 CUM INT ANG WI MUD 0.00 CUM COST WI MUD 1,637,825 24 HR FORECAST STAND BACK DP,MU 8 1/2" BHA & PU DP & TIH, Clrc & Test C LITHOLOGY I JAR HRS OF SERVICE 1 BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 11/14/2002 4,444.88 28.090 53.120 16.000 (In) @ AUTH. 2,484,894 LAST BOP PRES TEST 11/15/2002 SURVEY DATA M.D. INCL. ~IMUTH T.V.D. NIS CUM EIW ÇUMSECTlON M.D.· INCL. AZIMUTH T.V.O; N/S CUM' EIW CUM SECtiON.. 2,826.59 27.730 54.470 2,631.19 493.36 736.73 886.33 3,686.65 28.660 56.520 3,393.26 717.67 1,065.85 1,284.54 2,920.33 27.780 53.320 2,714.14 519.09 772.00 929.98 3,781.56 28.500 56.440 3,476.60 742.74 1,103.70 1,329.92 3,015.82 27.020 53.090 2,798.92 545.41 807.19 973.91 3,871.29 28.200 56.440 3,555.57 766.30 1,139.21 1,372.51 3,112.75 26.070 53.400 2,885.63 571.33 841.90 1,017.22 3,968.83 27.580 56.360 3,641.78 791.55 1,177.21 1,418.11 3,208.01 27.560 56.790 2,970.65 595.88 877.14 1,060.17 4,067.28 27.000 56.170 3,729.27 816.61 1,214.75 1 ,463.23 3,303.99 27.130 57.690 3,055.91 619.74 914.22 1,104.21 4,159.66 26.460 56.950 3,811.78 839.51 1,249.42 1,504.76 3,400.18 26.670 57.600 3,141.69 643.03 950.98 1,147.67 4,255.70 28.890 53.190 3,896.83 865.09 1,285.94 1,549.34 3,496.75 28.930 57.270 3,227.11 667.28 988.93 1,192.65 4,350.39 28.880 52.940 3,979.74 892.57 1,322.50 1,595.06 3,591.75 29.130 56.640 3,310.17 692.41 1,027.58 1,238.71 4,444.88 28.090 53.120 4,062.79 919.68 1,358.50 1,640.11 'I' OP:I;:I;tATION,S SUMMARY .PROM :TO HOl,lRS CODE TROUBLE SUB ' Pf;tÀ-SE .. DESCRIPTION 00:00 00:15 0.25 CEMENT P PUMP SURFAC Pumped 220 sxs of 12.0 ppg, 2.4 cf/sx Lite Crete tail cmt at 6 bpm /350 psi. 00:15 01:00 0.75 CEMENT P Drsp SURFAC Dropped top plug - cementers displaced with 20 bbls FR - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud - average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe untilllast 80 bbls of displacement - had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. 01:00 04:30 3.50 CEMENT P PULD SURFAC RD Cmt Head & Nabors Csg Tools, LD Landing Jt and Changed Out Long Elevator Bails to Short Drlg Bails 04:30 05:00 0.50 CEMENT P OTHR SURFAC Flushed out Divertor with Jetting Tool 05:00 09:30 4.50 WELCTL P NUND SURFAC ND 16" Divertor Lines & 21 1/4" divertor, Removed Starting Head 09:30 12:00 2.50 WELCTL P NUND SURFAC Installed FMC Gen 5 11" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead 12:00 17:00 5.00 WELCTL P NUND SURFAC NU BOP's, Change Out Flanges under Drip PAn, Install Riser & Turnbuckles, Changed out Blind Rams to Blind Shear Rams 17:00 18:00 1.00 WELCTL P BOPE SURFAC RU Test Equipment & Filled Stack With Water 18:00 19:30 1.50 WELCTL T EOIP BOPE SURFAC On First Attempt to Test BOP's had Gland Pkg Nut Leak, Sensor Hose Leaked, Replaced Hose and fitting on Manifold Started Leaking, Tightened Same 19:30 00:00 4.50 WELCTL P BOPE SURFAC Tested BOPE, Tested 5" Pipe Rams, Manifold & Valves to 250 Psi Low & 5,000 Psi High, Tested Annular to 250 Psi Then 3,500 Psi, Note: John Crisp with AOGCC Witnessed Test 24 HR SUMMARY: Fin Cmtg 9 5/8" Surface Csg, Had 45 bbls of 10.7 ppg cmt at Surface, Plug Didn't Bump, Ck Floats & Held, CIP at 00:46 hrs. RD Csg Tools, ND Divertor & Lines, Installed Gen5 Wellhead with Tbg Spool & DSA, NU Bops & Tested Same SERVICE , PÊRSÖNNEI..ÐATÄ'·' NO. HOURS COMPANY 3 Nabors COMPANY ConocoPhillips SERVICE NO. HOURS 33 Printed: 11/23/2002 11 :28:37 AM WELL NAME COMPANY Halliburton / Sperry-Sun Doyon Universal . ITEM Fuel Water, Drilling 38-07 UNITS' gals bbls SERVICE ) "CQnocoPhUli.ps,· Ahis·ka· . DaUytJrilling,Report' ¡JOB NUMBER IEVE~DC~DE 124 HRS PROG IT~~776.0 PERSONNEL DATA NO. . HOURS COMPANY 4 APC 6 Baroid . MATERIALS I CONSUMPTION USAGE. ON HAND ITEM -14,184 Water, Potable -1 ,420 ') I TVD IDFS 2,586.0 6.00 SERVice . UNITS bbls . , . P~ge'2 ót?', ,", , I REPT NO. 14 I DATE 11/14/2002 NO.' HOUR~ ~ 2 2 USAGE . ON HAND -638 Printed: 11/23/2002 11 :28:37 AM Well Name: Drilling Supervisor: 3S-07 I Rig: David Burley PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 11/16/2002 I Pump used: i #1 Mud Pump ... Pumping down annulus and DP. Type of Test: . Casing Shoe Test LOT/FIT Hole Size: IS-1/2" i ... RKB-CHF: 26.3 Ft Casina Size and Description: Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight: Estimates for Test: Casing Shoe Depth 2,769 Ft-MD 2,580 Ft-TVD 9-5/S" 40#/Ft L-SO BTC Hole Depth 2,796 Ft-MD 2,605 Ft-TVD ~ Pressure IntearitvTest Mud Weight: 9.5 ppg Mud 10 min Gel: 4.0 Lb/100 Ft2 Rotating Weight: 100,000 Lbs BlockslTop Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1140 psi 9.8 ppg 40.0 Lb/100 Ft2 2,500 psi 94,000 Lbs 26,000 Lbs 1.7 bbls 0.8 bbls I... EMW = Leak-off Pressure + Mud Weight = 1150 + 95 0.052 x TVD 0.052 x 2580 . EMW at 2769 Ft-MD (2580 Ft-TVD) = 18.1 ppg PIT 15 Second Shut-in Pressure, psi 1140 3000 . - Lost 90 psi during test, held = 96.4% of test pressure. ,uu¡..ul 1 I 2500 . .. LLJ 0:::: :J (/) (/) UJ 0:::: a.. o o 2 3 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Barrels ---CASING TEST ~LEAK-OFF TEST Comments: Changed hole over to 9.5 ppg new LSND mud prior to FIT. I Volume Input Volume/Stroke Pump Rate: 8.0! Strkjmin ¡ ... Strokes ... 0.0710 Bbls/Strk! ... ! Casing Test Pressure Integrity Test ... Pumping Shut-in Pumping Shut-in Strks psi Min psi Strks psi Min psi 0 0 0 2500 0 0 0 1150 2 80 1 2490 1 60 0.25 1140 4 170 2 2490 2 125 0.5 1130 6 290 3 2490 3 195 1 1110 8 400 4 2490 4 265 1.5 111r 10 500 5 2490 5 330 2 110~ I 12 650 6 2480 6 400 2.5 1090 14 810 7 2480 7 480 3 1080 16 930 8 2470 8 555 3.5 1070 18 1090 9 2470 9 630 4 1060 20 1240 10 2470 10 700 4.5 1050 22 1425 15 2450 11 775 5 1040 24 1600 20 2440 12 840 5.5 1040 26 1760 25 2420 13 900 6 1030 28 1950 30 2410 14 965 6.5 1020 30 2125 15 1030 7 1020 32 2310 16 1095 7.5 1010 34 2500 17 1150 8 1000 8.5 990 9 990 9.5 980 10 gf '~ Volume Volume Pumped Bled Back 2.4 Bbls ~ Volume Volume Pumped Bled Back 1.2 Bbls _ Bbls ') ). / Casing Detail 7" Intermediate Casina ConocoPhillips Alaska Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 11 H X 7" Hanger Jts 3 to 155 153 Jts 7" 26# L-80 BTCM Csg 7" Davis Lynch Floé\t Collar Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe TD of 8-112" hole @ 6633' MD . 6091' TVD 7" Shoe @ 6623' MD 6081' TVD Total Centralizers 1- 7" Bowspring centralizer over stop rings center of joints # 1 & #2 Bowspring centralizer over collar on joints #3 thru #25 7/1 x 8-3/8/1 Centering guide on every jt. From #92 thru #96 (Total of 5) 7/1 x 8-3/8/1 Centering guide on every third jt. From #143 to #155 (Total of 5) Total of 173 jts.on location Total of 155 jts. Ran In hole Total of 18 jts. Out (13 jts. Inside shed & 5 jts. Outside shed) Use Best-o-Life 2000 pipe dope Remarks: On Wt = 11 Ok Block Wt= 26k Up Wt = 190k Well: 38-07 Date: 11/21/2002 LENGTH 26.20 2.51 6507.96 1.31 83.72 1.48 DEPTH TOPS 26.20 28.71 6536.67 6537.98 6621.70 6623.18 Supervisor: Mike Thornton / Peter Wilson -') ) , , , ConOc'QPhillips··'Alaskå' I," I Cementi:ng R.eport ' Legal Well Name: 38-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING ~:rimary Hole Size: 8.500 (in) TMD Set: 6,623 (ft) Date Set: 11/20/2002 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Gsg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: Time End: Type: Pre-Flush Volume Excess %: Meas. From: Time Girc Prior To Cementing: 4.00 Mud Girc Rate: 210 (gpm) Mud Girc Press: 470 (psi) .1',:: ... .-.''''"., : ", ., ,.1', . I' I, ... I ,",1 ,~ Page, ;it :óf:'~, I'" Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 Cem:e,nt J()b Tvpe:, . Primary . ." .,." Squeeze Open Hole Hole Size: sa TMD: (ft) SO Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Culpepper Cmtd. Csg: Plug. Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Mov~ment Pipe Movement: Stuck prior cmt RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Sta{;ie No:'1 of 1 Start Mix Cmt: 17:00 Start Slurry Displ: 18:00 Start Displ: 18:53 End Pumping: 19:50 End Pump Date: 11/20/2002 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 12.3 (ppg) Vise: 45 (s/qt) Bottom Hole Circulating Temperature:75 (OF) Displacement Fluid Type:Seawater Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 5.00 (bbl/min) Y 1 ,400 (psi) 2,200 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: (lbs) Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch mix Density Meas By: Densometer PV/yP: 20 (cp)/19 (lb/100ft2) Gels 10 see: 6 (lb/100ft2) Gels 10 min: 8 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 8.5 (ppg) Volume: 255.70 (bbl) Mud Data Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 2,931.00 (ft)To: 3,373.00 (ft) Cmt Vol: 10.0 (bbl) Water Source: Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (co) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11:26:36 AM " ') Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING '\ I ConocqPhi lips AI~ska Cel11èntingR~port . . ·1 '" :,1, . 'Pag~ ~. of:.:$ Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 Stage No: 1 Slurry No:·2'of 3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 3,373.00 (ft)To: 5,585.00 (ft) Cmt Vol: 50.0 (bbl) Density: 13.30 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 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) Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 5,585.00 (ft)To: 6,623.00 (ft) Cmt Vol: 45.0 (bbl) Water Source: Slurry Vol218 (sk) Test Data Thickening Time: 3.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name, D65 D600G D47 . Stage No: 1 Slurry NO:,3 of 3 Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1· Slurry No: 3 of 3 - Additives Type Concentration Liquid Cone. Units 0.30 %BWOC Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Units 2.00 G P S 0.20G P S Printed: 11/23/2002 11:26:36 AM ) ') / .' , . ,. . ." . CoOqco Ph illips,' Al(i$ka , , . Cementing Report ' . '."'. . Pagè ~,of'3 ." Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 C$$ingTe$t Shoe Test ' Liner Top Test Test Press: (psi) For: (mln) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/SurVey Evaluation Interpretation 'Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: . Remarks Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 218 sxs (45 bbls) @ 15.8 ppg GasBLOK wI Class G + .300% 065, 2.000 gal/sk D600G, .200 gallsk D47, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls cmt at rate of 5.5 bpm at 500 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1035 psi until cmt around shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug wI total of 257.5 bbls, Bumped plug wi 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CI P @ 1950 hrs 11/20102, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. Printed: 11/23/2002 11 :26:36 AM ') ') i , ., WELL NAME . .' . , ." . . ·conocoPhil.liPS,' ,Alaska ,Daily DrlUingRepC?rt I JOB NUMBER \ EVENTODCRODE ··\24 HRS PROG TMD I TVD I DFS 3S-07 6,633.0 6,091.0 12.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Mike Thornton/Peter Wils N1268@ppco.co Nabors 7ES Kuparuk River 6,611.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD TIH with 31/2" Completion Assembly 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Set Pkr & Complete Well Per Plan, Freeze Protect Well 11/17/2002 202,518 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 18.00 WCD.K3S.0045.01 INC AZIM I LAST CASING I NEXT CASING 8.780 51.110 9.625 (in) @ 2,769.0 (ft) 7.000 (in) @ 6,611.0 (ft) eCP 13.10 MUD DATAI9AI~YCOST I 0.00 I CUM COST I FCrr.SOL OIUWAT %San~BT: Ph/pM PflMf CI 'Ca' H2S 21 I 118.8 7.7/ / p'aget pf2',· ' I REPT NO. I DATE 20 11/20/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 2,466,354 AUTH. LAST SURVEY: DATE 11/18/2002 TMD 6,633.00 2,484,894 LAST BOP PRES TEST 11/15/2002 DENSITY(Ppg) I 12.25 I ppl FV: 'PVNP GELS WUHTHP 48 18/23 8/10 2.5/10.4 0.00 LIME ES \ I' 'OPERATI,ONSSUM'MARY· FROM TO HOURS CODE TROUBLE , SUB PHA~E DESCRIPTION ' 00:00 02:00 2.00 CASE P RURD INTRM1 Fin RU Nabors Csg Equipment & GBR Fill-Up Tool 02:00 12:00 10.00 CASE P RUNC INTRM1 Held Safety Mtg on Running of 7" Csg MU 7" Float Shoe, 2 Jts of 7" 26# L-80 BTC Mod Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 153 Jts 7" Csg, (Total of 155 Jts Ran 6,623.18' ) Note: Nabors Floorhand Robert Miller Twisted Ankle While Running 7" Csg, Stepped on Railing Stop for Iron Roughneck While Tailing in Csg 12:00 18:00 6.00 CASE P CIRC INTRM1 Est Circ & Reciprocating Pipe Up Wt190K, Dn Wt 11 OK -While Reciprocating Pipe after approx 25 Min On Wt down to 80K,Attempted to PU on Csg, PU WnOK Over, Pipe Stuck, Landed Csg in Hanger, RD Fill Up Tool & MU Cmt Head on Landing Jt & Cont to Circ Csg for Cmt Job, Lowered YP from 30 to 23 with 45 vis, Circ at 209 Gpm's at 470 Psi, Landed Csg With FS @ 6,623', FC @ 6,536' 18:00 19:00 1.00 CEMENT P PUMP INTRM1 RU Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 218 sXS (45 bbls) @ 15.8 ppg GasBLOK w/ Class G + .300% D65, 2.000 gal/sk D600G, .200 gal/sk,D47, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls of at 15.8 at rate of 5.5 bpm at 500 psi, Shut down, 19:00 20:00 1.00 CEMENT P DISP INTRM1 Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1035 psi until cmt. around shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug wi total of 257.5 bbls, Bumped plug wi 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CIP @ 1950 hrs 11/20/02, Ck floats & Held, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. 20:00 21:00 1.00 CEMENT P CIRC INTRM1 Flushed Out Mud Pump, Stack & Flowline 21:00 22:30 1.50 CEMENT P RURD INTRM1 LD Landing Jt, RD Csg Tools & Changed Out Elevator Bails 22:30 23:00 0.50 CMPLTN P OTHR INTRM1 RU & RIH and Set 7" Pack-off, Tested Same to 5,000 Psi for 10 Min, LD Setting Tool 23:00 00:00 1.00 CMPL TN P RURD CMPL TN RU Nabors 3 1/2" Tbg Handling Tools 24 HR SUMMARY: RU & Ran 155 Jts of 7" 26# L-80 BTC Mod Csg, Landed Csg at 6,623', Circ & Cond Mud, Cemented 7" Csg, Bumped Plug, Floats Held, CIP at 19:50 Hrs, RD Cmt Head, RU to Run 31/2" Completion Printed: 11/23/2002 11 :29:52 AM WELL NAME COMPANY ConocoPhillips Nabors Halliburton I Sperry-Sun Doyon Universal APC "ITEM, . Fuel Water, Drilling 3S-07 . UNITS: gals bbls SERVICE ) USAGE 2,730 372 . .. . .ConocoÞhiUips, Alaska' . " .. . D,a,UY'DrillingReport IJOB NUMBER IEVE~TDc~DE 124 HRS PROG IT~~633.0 PERSONNEL DATA NO. HOURS ' . COMPANY 3 Baroid 39 Canrig 4 Baker 6 FMC 2 MATERIALS/CONSUMPTION· . ON HAND . I~M -14,262 Water, Potable -1 ,946 ~) TVD I DFS 6,091.0 12.00 : SERVICE 'UNITS' bbls ,., Page 2 ór2,~ I REPT NO. 20 ¡DATE 11/20/2002 No. HOURS' 2 1 1 1 USAGE ,ON,HAND .' -638 Printed: 11/23/2002 11 :29:52 AM Well Name: Drilling Supervisor: 38-07 I Rig: Mike Thorton PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 11/21/2002 Pump used: #1 Mud Pump ... I : 'Y i 'Y Pumping down annulus. Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" ... Casing Shoe Depth RKB-CHF: 26.3 Ft 2,769 Ft-MD 2,580 Ft-TVD Casin~ Size and Description: : 9-5/8" 40#/Ft L-80 BTC Chan~es 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. Hole Depth 5,585 Ft-MD 5,083 Ft-TVD Pressure Inte~ritvTest Mud Weight: 12.3 ppg Inner casing 00: 7.0 In. 18.1 ppg 778 psi Desired PIT EMW: Estimates for Test: 0.4 bbls I... EMW = Leak-off Pressure + Mud Weight = 620 + 123 0.052 x TVD 0.052 x 2580 . EMW at 2769 Ft-MD (2580 Ft- TVD) = 16.9 PIT 15 Second Shut-in Pressure, psi 400 1 000 - UJ c::: ~ U) U) UJ c::: a.. 6 8 0 10 15 20 25 30 Shut-In time, Minutes o PIT Point 4 Barrels ......CASING TEST ~LEAK-OFF TEST Comments: I Volume Input Volume/Stroke Pump Rate: Strokes ... 0.0710 Bbls/Strk ... 7.0\ Strk/min ... I I Casing Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Strks si Min si Strks psi Min psi 0 0 ° 450 7 70 0.25 400 14 80 0.5 380 21 100 1 320 28 180 1.5 31( 35 300 2 300-' 42 480 2.5 300 49 620 3 300 56 500 3.5 300 63 490 4 300 70 490 4.5 295 77 480 5 290 84 480 5.5 290 91 450 6 290 98 450 6.5 285 7 280 7.5 270 8 260 8.5 255 9 250 9.5 250 10 2' ---- ... ... Volume Volume Pumped Bled Back 0.0 Bbls _Bbls Volume Volume Pumped Bled Back 7.0 Bbls _Bbls TUBING (25-8965, 00:3.500, 10:2,992) SURFACE (29-3504, 00:9.625, Wt:40.00) ~OOUCTION (28-9639, 00:7.000, Wt:26,OO) NIP (8878-8879, 00:4.520) PBR (8919-8920, 00:5.870) Anchor Nipple (8932-8933, 00:4.740) PACKER (8933-8937, 00:5.950) NIP (8957-8958, 00 :4.540) WLEG (8964-8965, 00 :4.510) Tn. (8965-8966, 00 :3.500) Perf (9284-9302) Perf (9302-9332) tønø'()P~iill~Ø,. AI_ka, .Inc~ L (] ) ) KRU 35-09 3S-09 API: 501032043200 SSSV Type: Nipple Well Type: PROD Orig Completion: Last W/O: Ref Log Date: TO: 9650 ftKB Max Hole Angle: 59 deç¡ @ 4380 Anç¡le @ TS: 53 deg (â¿ 9284 Angle @ TO: 51 deg @ 9650 Annular Fluid: Reference Log: 24.13' RKB Last Taç¡: 9420 E-Line LastTag Date: 12/23/2002 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 9284 - 9302 5795 - 5806 Rev Reason: Delete PIT note Last Update: 1/20/2003 Top Bottom TVD Wt Grade Thread 28 9639 6013 26.00 L-80 BTCM 29 3504 2596 40.00 L-80 BTC 29 108 108 62.50 H-40 WELD TVD Wt I Grade Thread 5608 9.30 L-80 EUE8RD Status Ft SPF Date Type Comment 18 6 12/25/2002 ¡PERF 2506 pj Chrgs, 60 deg phase 30 6 12/24/2002 I PERF 2506 pj Chrgs, 60 deg phase 20 6 12/25/2002 IPERF 2506 pj Chrgs, 60 deg phase Bottom 8965 Zone C-4 9302 - 9332 5806 - 5824 C-4 9332 - 9352 5824 - 5836 C-4 Gas Lift Mandrels/Valves St MD TVD Man Man Mfr Type 1 8832 5532 CAMCO MMG Other (:>Iugs, equip., etc.' - JEWELRY Depth TVD Type 24 24 HANGER 497 496 NIP 8878 5558 NIP 8919 5581 PBR 8932 5589 Anchor Nipple PACKER BAKER SAB-3 PACKER EXTENSION BAKER MILLOUT EXTENSION NIP CAMCO '0' NIPPLE WINO GO PROFILE WLEG BAKER PUMP OUT SUB - sheared 12/22/2002 TTL V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 12/21/2002 DMY 1.5 RK 0.000 o Description FMC 3.5" GEN 5 TBG HANGER w/3.5" TBG PUP ON BTM CAMCO 'OS' LANDING NIPPLE WITH NO GO PROFILE CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE BAKER PBR 80-40 BAKER KBH-22 ANCHOR TUBING SEAL ID 2.993 2.875 2.812 2.980 2.993 8933 5590 8937 5592 8957 5603 8964 5607 8965 5608 General Notes Date Note 12/18/200~ Tree: FMC I GEN 5 I 5M Tree Cap Connection: Top 5.75" ACME w/3.5" EUE 8rd Thread 3.250 3.720 2.750 2.990 2.992 ) ) Casing Detail 9 5/8" Surface CasinQ .,PHILLIPS Alaska, Inc. œ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts Jts 59 to 81 23 Jts Jts 3 to 58 56 Jts Jts 1 to 2 2 Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Nabors 7ES RKB to Landing Ring 29.55' FMC Gen V Hanger (pup under hanger 2.09) 9-5/8" 40# L-80 BTC Csg TAM Port Collar 40# L-80 BTC SN. PC1-9.6384402 11.27" 00. 9-5/8" 40# L-80 BTC Csg Weathertrd 402 Sure-Seal Float Collar 10.69" 00. 8.665" 10. 9-5/8" 40# L-80 BTC Csg Weathertord 303 Sure-Seal Float Shoe 10.67" 00 TO 12 1/4" Surtace Hole 12-1/4" T.D. @ 35151 MD /26011 TVD 9-5/8" Shoe @ 3504.621 MD /25961 TVD RUN TOTAL 15 BOWSPRING CENTRALIZERS - 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 - #12 1 per Jt over stop rings on #IS 58 & 59 (TAM PC) Total of 110 Jts. On location (Including extra float equip.) Total of 17 Jts. Outside shed (Including extra float equip.) Total of 93 Jts. Inside shed Run Total of 81 Jts. Total of 12 Jts. Left out inside shed Use Jet Lube "RUN-N-Seal pipe dope Remarks: Up Wt - 135 K On Wt - 105 K Block Wt - 30 k Drifted all casing to 8.679" Average MU torque = 8000 fVlbs Well: 35-09 Date: 12/6/2002 LENGTH 28.54 2.40 986.36 3.00 2394.27 1.45 85.90 1.69 Supervisor: Dave Burley / G.Rizek DEPTH TOPS 28.54 30.94 1017.30 1020.30 3414.57 3416.02 3501.92 3503.61 3515.00 ) ) mPHILLlPS Alaska, Inc. ~...... A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-09 9 5/8", 40# L-80 BTC 12/06/02 PAGE: RIG: 1 of 2 Nabors 7ES Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet ¡~~¡¡~::~~I~~ 43.50 26 43.75 51 42.82 76 41.81 101 126 151 176 :~:~:~:!:2t:~ 42.40 27 42.54 52 38.54 77 43.16 102 127 152 177 [¡¡:ä:~: 43.51 28 42.87 53 43.48 78 43.34 103 128 153 178 !*¡[~~n~:: 42.47 29 42.49 54 40.87 79 43.22 104 129 154 179 ~'f:'x'x'x'~ ~~~!f~!!t: 42.63 30 42.48 55 43.51 80 42.67 105 130 155 180 ~~:r:::r::::::~~ :::::;:::ß.::::::: 43.57 31 42.00 56 43.41 81 41.24 106 131 156 181 ~¡~¡Ht:1¡:¡: 43.27 32 42.96 57 42.21 ~ 42A4 107 132 157 182 :}~H~fr 43.10 33 42.88 .................... 42.16 ~ ~ 108 133 158 :}5~r:: 183 !!::~:::::~:~: :~:i!-)!-:*:~ :}~HJ.{:~ 43.11 34 43.11 t$.~t: 42.74 M 42.92- 109 134 159 184 m1~jÞ.:¡~¡ 43.85 35 43.59 60 42.82 8& ~ 110 135 160 185 !:::~::~:~:~: :::::4::1::::: 43.49 36 43.20 61 42.16 ~ 4+:-99 111 136 161 186 :I1wI 43.77 37 40.99 62 42.85 37 ~ 112 137 162 187 13 41.81 38 43.74 63 42.89 gg. 4G-:9ð 113 138 163 188 14 43.50 39 42.77 64 42.71 W 42:.ê& 114 139 164 189 15 43.01 40 41.56 65 43.76 gg. 42,.9& 115 140 165 190 16 43.32 41 41.83 66 43.80 9+ 4+;7.Q. 116 141 166 191 17 41.55 42 42.74 67 42.76 ~ ~ 117 142 167 192 18 43.51 43 43.13 68 43.50 9ð 4&7ê 118 143 168 193 19 42.92 44 42.96 69 42.92 94 119 144 169 194 20 43.13 45 42.39 70 43.21 95 120 145 170 195 21 42.97 46 43.22 71 42.23 96 121 146 171 196 22 43.22 47 43.51 72 43.53 97 122 147 172 197 23 43.78 48 43.77 73 41.99 98 123 148 173 198 24 42.49 49 43.16 74 43.52 99 124 149 174 199 25 40.93 50 40.72 75 43.53 100 125 150 175 200 Tot 1074.81 Tot 1068.36 Tot 1067.92 Tot 766.06 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3977.15 DIRECTIONS: TOTAL JOINTS THIS PAGE = 93 FLOAT SHOE = 1.69 FLOAT COLLAR =1.45 HANGER overall 2.4 includes pup TAM port collar 3.00 HANGER overall 2.4 includes pup RKB =29.55 ) ) :~~~~. PHILLIPS Alaska, Inc. œ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-09 95/8",40# L·80 BTC 12/06/02 PAGE: RIG: 2 of 2 Nabors 7ES Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 3977.15 DIRECTIONS: TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 93.00 AVERAGE JT = 42.77 ') ) Legal Well Name: 3S-09 Common Well Name: 3S-09 Event Name: ROT - DRILLING Hole Size: 12.250 (in) TMD Set: 3,504 (ft) Date Set: 12/7/2002 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: 1 12/4/2002 Spud Date: 12/4/2002 Report Date: 12/9/2002 End: 12/17/2002 Gelt1e.,.tJ()t)TYP~: . SquèezeCaslng Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Cull pepper Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Rotate & Recip Rot Time Start: : Ree Time Start:08: 15 Time End: : Time End: 13:30 RPM: SPM: 'nit Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 135 (Ibs) Start Mix Cmt: 12: 11 Start Slurry Displ: 12:12 Start Displ: 13:10 End Pumping: 13:44 End Pump Date: 12/7/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) Y 468 (psi) 980 (psi) 2 (min) Y Max Torque: (ft-Ibf) Drag Down: 100 (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 60.00 (bbl) Ann Flow After: N Mixing Method: Direct bl Density Meas By: Densometer Type: Spud Mud Density: 9.4 (ppg) Vise: 50 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PV NP: 21 (cp)/14 (lb/100ft2) Gels 10 see: 5 (lb/100ft2) Gels 10 min: 6 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 259.00 (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) Type: Cement Casing Volume Excess %: 225.00 Meas. From: 60 Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 336 (gpm) Mud Circ Press: 440 (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:58:52 PM ) ) ConocoPhillipSAlaska Cementing·· Report Legal Well Name: 38-09 Common Well Name: 38-09 Event Name: ROT - DRILLING Report #: Start: 1 12/4/2002 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) 8pud Date: 12/4/2002 Report Date: 12/9/2002 End: 12/17/2002 $tðge No: 1 Slurry N.o: 2()f4 Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: DesCription: ARCTIC SET Class: G To: 1,804.00 (ft) Cmt Vol: 315.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Slurry Vol398 (sk) Water Vol: 185.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name D79 S001 D46 D65 D124 D53 D44 Stage No: 1 Slurry No: 3 öf 4 .. Additives Type Concentration Units 1.50 %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.10 %BWOC 30.00 %BWOC Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 3,504.00 (ft}To: 1,804.00 (ft) Cmt Vol: 133.0 (bbl) Wa1er Source: Slurry Vol300 (sk) Test Data Thickening Time: 4.41 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temp (OF) (OF) Pressure (psi) (psi) LiquidConc. Units 9.00 %BWOW Class: G Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 44.3 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:58:52 PM ') ) Legal Well Name: 38-09 Common Well Name: 38-09 Event Name: ROT - DRILLING Report #: Start: 1 12/4/2002 Spud Date: 12/4/2002 Report Date: 12/9/2002 End: 12/17/2002 Type Cöncentration 0.50 %BWOC 0.60 %BWOC 29.54 %BWOC 1.00 %BWOC 16.63 %BWOC D79 D46 D124 D65 D164 .. ·.Ca$ingTest . Sh<>eTest Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 18.00 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Interpretation Summary 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: Establish circ @ 1.5 bpm 150 psi - stage pumps up to 8 bpm - circ and cond mud - reduced FV from 122 to 50 - YP from 30 to 14. Final circ press 440 psi- last 100 bbls pumped wI 5 ppb nut plug for marker. PJSM. Line up to cementers - Pumped 5 bbls CW 100 - Test lines to 3000 psi - Pump additional 45 bbl of CW 100. Drop bttm plug, follow wI 50 bb110.5 ppg Mud Push XL with 2 gals die marker. Pumped 316 bbls of 10.7 ppg AS Lite lead, follow by 125 bbls 12.0 ppg LiteCRETE tail. Drop top plug, displaced 20 bbls of FW from cementers. Swiched to rig pumps: displaced wI 9.4 ppg mud @ 8 bpm 390 psi to 682 psi wI 220 bbls pumped - Slowed rate to 4 bpm 1468 psi last 19 bbls pumped. Bumped plugs to 980 psi - floats held. Reciprocated pipe untilllast 90 bbls of displacement - full returns throughout - had 60 bbls of 10.8 ppg cement returns to surface. CIP @ 1344 hrs 12/7/2002. ** Casing collar appeared to be hanging up on Conductor shoe, limited length of reciprocation to 10 '. Printed: 1/31/2003 2:58:52 PM ') ) WELL NAME 3S-09 I JOB NUMBER 1 EVE~DC~DE 124 HRS PROG SUPERVISOR I RIG NAME & NO. 1 FIELD NAME IOCS NO. David Burley I G. Rizek N1268@ppco.co Nabors 7ES Kuparuk River CURRENT STATUS ACCIDENTS LAST 24 HRS.? RU to test BOPE TMD I TVD I DFS 3,515.0 2,601.0 3.40 AUTH MD I DAILY TANG 9,486.0 0.00 DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 12/3/2002 360,780 ILEAKOFF AFE 10027330 I NEXT CASING 9.625 (in) @ 3,589.0 (ft) 0.00 ICUMCOsr Pf/Mf CI Ca H2S I 1 REPT NO. I DATE 5 121712002 I CUM. TANG 0.00 CUM INT ANG WI MUD 0.00 CUM COST WI MUD 711 ,164 24 HR FORECAST NU BOPE, test BOPE, PU DP 7 & BHA, RIH LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 12/6/2002 3,402.04 58.550 39.190 16.000 (in) @ 108.0 (ft) [)EN~IT'f(ppg) I 90.40 I·. pp I ECD I I MUD DATA I DAIL"cc:jstl ·FVPVIYP GELS.· WLlHTHP FCrr~SOL OILfWAT %SandIMBT . Ph/pM. 50 21/14 516 5.51 21 I 120.0 8.51 AUTH. 2,704,388 LAST BOP PRES TEST 0.00 LIME ES OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Continue RIH w/9 5/8" 40#/ft L-80 BTC . Wash f/1520' to 2008' as needed. PUW 115K SOW 70-75 03:00 04:00 1.00 CASE P CIRC SURFAC Condition mud and circ initial rate 5 bpm @ 275 psi final rate 6 bpm w/315 psi - final PUW 1 05K I SOW 75-80K - total volume pumped 250 bbls. 04:00 05:30 1.50 CASE P RUNC SURFAC Continue RIH w/9 5/8" 40#/ft L-80 BTC f/2080' to 3080'. Displacement dropped to 75% of calculated. 05:30 06:30 1.00 CASE P CIRC SURFAC Circ and cond mud - initial 1.2 bpm I 317 psi final 4 bpm I 210 psi PUW 125k SOW 95k. 133 bbls total pumped. 06:30 07:30 1.00 CASE P RUNC SURFAC Continue RIH w/9 5/8" 40#/ft L-80 BTC fl 3080' to 3475'. Total of 81 joints 9 5/8" casing in hole, MU hanger and landing joint - land casing SOW 100k. Tam port collar @ 1018' Float collar @ 3415' Float shoe @ 3504' 07:30 08:00 0.50 CEMENT P RURD SURFAC UD Frank's FC-Hill-up tool. Blow down top drive. MU Dowell cement head. 08:00 12:00 4.00 CEMENT P CIRC SURFAC Establish circ @ 1.5 bpm 150 psi - stage pumps up to 8 bpm - circ and cond mud - reduced FV from 122 to 50 - YP from 30 to 14. Final circ press 440 psi- last 100 bbls pumped wI 5 ppb nut plug for marker. PJSM. 12:00 13:30 1.50 CEMENT P PUMP SURFAC Line up to cementers - Pumped 5 bbls CW 100 - Test lines to 3000 psi - Pump additional 45 bbl of CW 100. Drop bttm plug, follow wI 50 bbl1 0.5 ppg Mud Push XL with 2 gals die marker. Pumped 316 bbls of 10.7 ppg AS Lite lead, follow by 125 bbls 12.0 ppg LiteCRETE tail. Drop top plug, displaced 20 bbls of FW from cementers. 13:30 14:00 0.50 CEMENT P DISP SURFAC Swiched to rig pumps: displaced wI 9.4 ppg mud @ 8 bpm 390 psi to 682 psi wI 220 bbls pumped - Slowed rate to 4 bpm I 468 psi last 19 bbls pumped. Bumped plugs to 980 psi - floats held. Reciprocated pipe untilllast 90 bbls of displacement - full returns throughout - had 60 bbls of 10.8 ppg cement returns to surface. CIP @ 1344 hrs 1217/2002. 14:00 15:00 1.00 CEMENT P OTHR SURFAC Wash out 20" diverter system wI retarder (D110).RID cement equipment. Backout landing joint, UD same. Blowdown all lines. 15:00 16:30 1.50 CASE P RURD SURFAC Remove casing elevators. Change out casing bails to drilling bails. 16:30 19:30 3.00 WELCTL P NUND SURFAC PJSM. N/D 20" diverter system. (Time to remove slip on head 1.5 hrs). 19:30 20:30 1.00 WELCTL P NUND SURFAC Bring FMC csg head and FMC tubing spool into cellar. Set drilling spool in cellar. Printed: 1/31/2003 3:05:58 PM ) ) 38-09 . ... . . ... ConocoPhillips,Alå$i(a . Df);ily. DrillirtgRepprt; JOBNUMBER EVE~DC~DE 24HRSPROG IT~~515.0 ITVD IDFS 2,601.0 3.40 I REPT NO. I DATE 5 12/7/2002 WELL NAME FROM 20:30 OPERATIONS SUMMARY . PHASE . DESCRIPTION SURFAC Attempt to pickup 135/8" BOP stack from stump with Kevlar slings. Removed wire rope slings to avoid having to use safety chain wrapped around Hydril. NO go. Rig back up wI wire rope slings. "Need to be able to safely pick BOPE. NUND SURFAC Attempt to install BOPE. Could not raise stack high enough to clear drilling spool wI present rigup. 22:30 00:00 1.50 WELCTL "p 24 HR SUMMARY: Run 9 5/8" casing, Circ prior to cement, cement csg, RID cement equip, UD landing joint, NID diverter, NU FMC wellhead PERSONNEL DATA . NO. HOURS COMPANY 2 Baroid 31 Can Rig 6 APC 3 COMPANY ConocoPhillips Nabors Doyon Universal Sperry Sun MATERIALS ¡CONSUMPTION ON HAND ITEM·· 7,311 Fuel (camp) 168 Water, Potable . ON HAND 4,186 11 ,160 Fuel Water, Drilling RESERVOIR AND INTERVAL DATA ZONE TOP BASE 325 0 o 0 RESERVOIR NAME 1 R-18 G & I Prudhoe Bay COMMENTS 3S-09 3S-09 Printed: 1/31/2003 3:05:58 PM Well Name: Drilling Supervisor: 38-09 I Rig: D. Burley/ G. Rizek Type of Test: Casing Shoe Test LOT/FIT Hole Size: IS-l/2" RKB-CHF: 28.5 Ft Casina Size and Description: Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight: Estimates for Test: . PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 12/9/2002 ! Pump used: i #1 Mud Pump ... Pumping down annulus and DP. Casing Shoe Depth 3,504 Ft-MD 2,595 Ft-TVD 9-5/S" 40#/Ft L-SO BTC 9.3 ppg 13.0 Lb/100 Ft2 2,550 psi 90,000 Lbs 26,000 Lbs 2.3 bbls Hole Depth 3,535 Ft-MD 2,611 Ft-TVD Pressure IntearitvTest Mud Weight: 9.3 ppg Mud 10 min Gel: 17.0 Lb/100 Ft2 Rotating Weight: 94,000 Lbs BlockslTop Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1174 psi 1.1 bbls I· EMW = Leak-off Pressure + Mud Weight = 1175 + 93 0.052 x TVD 0.052 x 2595 . EMW at 3504 Ft-MD (2595 Ft- TVD) = 18.0 ppg 3000 . uJ ~ :::::> (/) (/) uJ ~ a.. Barrels .....CASING TEST PIT 15 Second Shut-in Pressure, psi 1150 - Lost 5 psi during test, held = 99.8% of test pressure. ~uJ,.ul i 3 4 0 10 15 20 25 30 Shut-In time, Minutes o PIT Point ~LEAK-OFF TEST Changed well over to new 9.3 ppg LSND mud prior to FIT. Comments: r Volume Input Volume/Stroke Strokes ~ 0.0583 Bbls/Strk I ~ l Casin9 Test Pumping Strks psi o 0 2 40 4 120 6 220 8 320 10 460 12 560 14 680 16 750 18 830 20 910 22 1000 24 1100 26 1200 28 1290 30 1400 32 1490 34 1570 36 1700 38 1800 40 1920 42 2010 44 2140 46 2240 48 2350 50 2470 51 2550 - Volume Pumped 3.0 Bbls ... ¡. Pump Rate: i 8.01 Strkjmin ! .. Pressure Integrity Test Shut-in Pumping Shut-in Min psi Strks psi Min psi 0 2550 0 0 0 1175 1 2550 2 50 0.25 1150 2 2550 4 110 0.5 1125 3 2550 6 240 1 1080 4 2550 8 330 1.5 10f 5 2550 10 420 2 10~ 6 2550 12 500 2.5 1010 7 2550 14 580 3 990 8 2550 16 640 3.5 970 9 2550 18 700 4 950 10 2550 20 760 4.5 925 15 2550 22 800 5 920 20 2550 24 850 5.5 915 25 2545 26 900 6 910 30 2545 28 950 6.5 900 30 1000 7 885 32 1050 7.5 870 34 1100 8 860 36 1150 8.5 860 38 1175 9 850 9.5 850 10 8, ~ Volume Bled Back _Bbls Volume Bled Back _Bbls ConocoPhillips Alaska ') )1 Casing Detail 7" Intermediate CasinQ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 11" X 7" Hanger Jts 5 to 231 227 Jts 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Collar Jts 1 to 4 4 Jts 7" 26# L -80 BTCM Csg 7" Davis Lynch Float Shoe Remarks: Up Wt = 275k TD of 8-1/2" hole @ 9650' MD 6020' TVD 7" Shoe @ 9639' MD 6012' TVD Total Centralizers 1- 7" Bowspring cent.! stop rings 10 above FS jt # 1 & 10 below FC 0 Bowspring centralizer over collar on joints #2 , #3 and #5 thru #29 7" x 8-3/8" Centering guide on every jt. From #154 thru #157 (Total of 4) 7" X 8-3/8" Centering guide on Jts #,s 220,223,226,229. (Total of 4) Totals: 29 Bowspring, 8 straight blade, 9 centering guides Total of 237 jts.on location Total of 231 jts. Ran in hole Total out: 6 jts. (last jt on tally # 232 in shed - [5 jts Outside shed not on tally]) Use Best-o-Life 2000 pipe dope On Wt = 88k Block Wt= 26k Well: 35-09 Date: 12/15/2002 LENGTH 26.32 2.48 9439.49 1.34 167.62 1.48 DEPTH TOPS 26.32 28.80 9468.29 9469.63 9637.25 9638.73 Supervisor: Dave Burley / Peter Wilson ) ) ConocoPhillips Alaska CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-09 7",26# L-80 BTCM 12/15/02 PAGE: RIG: 1 of 2 NABORS 7ES Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet '.................1:' X~~{ ::::::::~:::::::: 43.06 42.67 51 43.38 76 43.00 101 41.05 126 41.51 151 39.33 176 40.80 !¡¡jji~¡~i ".................~ 42.30 :titt 43.32 52 41.35 77 43.20 102 40.02 127 42.57 152 40.81 177 38.70 \t¡¡¡ª¡~:i 41.44 r¡ìi¡{ 41 .73 53 41.61 :::::ll::::: 41.17 103 43.35 128 40.65 153 39.70 178 40.76 ~~:::~~~¡f:~:: 40.82 :I'-Ij¡¡: 42.63 54 41.62 79 42.26 104 39.84 129 39.05 d:Sj@ 39.47 179 40.44 .!:!:!:!:!:!:~:!:!:~ 4ïlïlïlïlï tt~J::: 40.75 30 42.81 55 42.63 :tãit 41.65 105 40.44 130 39.10 4:$:~: 43.16 180 40.63 :¡¡j¡¡~¡¡t ~.'.'"'.""""'" ,~.:.I.:.:.:.:.:.:.~ 40.83 ~f~it: 42.71 56 43.02 81 42.56 106 40.35 131 40.93 ti&.ä 40.63 181 38.93 :IjÆi "'..................... rI'::::::::.~.J 43.16 :tiit 41 .78 57 41.45 82 43.20 107 40.45 132 41 .45 ::l5:t:: 40.66 182 40.73 ::f::~:~:~:~~ :~¡!~¡~r J~i¡lr ::::::::~::::::: 40.73 40.09 58 43.31 83 42.76 108 43.11 133 39.97 40.65 183 38.78 ((((I))))): ~t~~:ïH:::: 43.35 "tIll 43.19 59 40.31 84 43.00 109 39.67 134 41.72 159 40.48 184 40.81 '.......-..........¡.. fmiit 42.68 t:ãit 42.95 60 41.51 85 42.64 110 43.11 135 43.10 160 40.66 185 43.42 '.::::.::"f.:f." ¡~~:¡~J¡1~¡:¡~ 42.41 36 42.56 61 42.93 86 42.62 111 41.60 136 42.22 161 43.16 186 42.15 :~:::~:1:af 40.28 37 42.84 62 43.30 87 40.31 112 40.40 137 40.82 162 40.88 187 41.09 "'1.'11"1."11'1 ::;:t1::3::::: 40.06 38 40.95 63 39.59 88 42.66 113 40.48 138 40.02 163 41.75 188 40.52 : : ~ : I : : : : ¡. ma]:it 40.68 39 42.63 64 40.70 89 43.04 114 43.30 139 43.26 164 40.78 189 41.98 i¡¡~~¡ij¡¡[ 38.81 40 43.10 65 43.09 90 43.28 115 40.65 140 40.45 165 41.58 190 43.38 ~:tf:U~:t 43.04 41 43.52 66 43.23 91 39.78 116 40.86 :441:: 34.95 166 38.67 191 40.83 i!¡¡¡¡~¡i!:¡! 43.40 42 40.56 67 43.33 92 36.67 117 43.20 142 41.56 167 40.82 192 42.20 'ff:·:..:·:·:·:':·... iI@@: 42.36 43 40.88 68 42.70 93 42.61 118 40.81 143 40.77 168 40.83 193 43.09 :::il~!i:f 43.37 44 40.58 69 40.45 94 42.10 119 40.77 M¥f 42.66 169 41.06 194 43.27 42.73 45 40.54 70 40.93 95 40.55 120 40.54 145 40.58 170 40.59 195 41.20 :!:!:!:!:!:!:!:!:!:~ :!r~¥t 42.67 46 42.32 71 43.17 96 43.15 121 40.71 146 39.94 171 40.19 196 43.02 ::f2j} 42.46 47 43.20 72 43.29 97 40.72 122 38.91 147 43.31 172 40.06 197 43.45 .........,............. fj~ijt 43.47 48 43.29 73 42.10 98 40.73 123 38.59 148 38.72 173 40.04 198 43.25 '::·:·~·gx."i·~ II: 41.89 49 40.50 74 42.02 99 39.34 124 40.81 149 36.87 174 40.73 199 41.72 43.19 50 43.21 75 41.82 100 36.93 125 42.14 150 41.77 175 40.30 200 43.45 Tot 1 049.94 Tot 1054.56 Tot 1052.84 Tot 1039.93 Tot 1025.16 Tot 1017.95 Tot 1016.99 Tot 1038.60 TOTAL LENGTH THIS PAGE = 8295.97 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE FLOAT COLLAR HANGER RKB ) ) ARCO ALASKA INC CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-09 7", 26# L-80 BTCM 12/15/02 PAGE: RIG: 2 of 2 NABORS 7ES Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 40.84 J~2M: 42.59 251 276 301 326 351 376 202 41.37 227 42.86 252 277 302 327 352 377 203 43.28 228 40.20 253 278 303 328 353 378 204 43.39 ligii( 42.70 254 279 304 329 354 379 205 40.85 230 43.33 255 280 305 330 355 380 206 43.02 231 40.59 256 281 306 331 356 381 207 43.43 ~ 41.80 257 282 307 332 357 382 208 42.92 233 258 283 308 333 358 383 209 43.24 234 259 284 309 334 359 384 210 43.25 235 260 285 310 335 360 385 211 41.73 236 261 286 311 336 361 386 212 42.56 237 262 287 312 337 362 387 213 43.17 238 263 288 313 338 363 388 214 42.26 239 264 289 314 339 364 389 215 41.80 240 265 290 315 340 365 390 216 42.26 241 266 291 316 341 366 391 217 42.63 242 267 292 317 342 367 392 218 43.08 243 268 293 318 343 368 393 219 40.67 244 269 294 319 344 369 394 tii2ð.m 43.21 245 270 295 320 345 370 395 221 42.75 246 271 296 321 346 371 396 222 42.65 247 272 297 322 347 372 397 t~~~t~t 42.70 248 273 298 323 348 373 398 224 41.37 249 274 299 324 349 374 399 225 40.44 250 275 300 325 350 375 400 Tot 1058.87 Tot 294.07 Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 1352.94 TOTAL LENGTH = 9648.91 DIRECTIONS: TOTAL JOINTS THIS PAGE = 32.00 TOTAL JOINTS = 232.00 AVERAGE JT = 41.59 ') I ) Legal Well Name: 3S-09 Common Well Name: 3S-09 Event Name: ROT - DRILLING Hole Size: 8.500 (in) TMD Set: 9,639 (ft) Date Set: 12/15/2002 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: 2 12/4/2002 Spud Date: 12/4/2002 Report Date: 12/15/2002 End: 12/17/2002 . ... ..... ..... ... ... .. CernehtJ()t) Type: . . .. . 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: Cementer: Rick Gallegos Pipe Movement: No movement Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Rot Time Start: Rec Time Start: Time End: Time End: RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Type: Cement Casing Volume Excess %: 75.00 Meas. From: 0 Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 55 (gpm) Mud Circ Press: 775 (psi) Start Mix Cmt: 11 :40 Start Slurry Displ: 11 :41 Start Displ: 12:02 End Pumping: 13:20 End Pump Date: 12/15/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.50 (bbl/min) 6.00 (bbl/min) Y 1,342 (psi) 2,732 (psi) 2 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densometer Type: Non-Disp. LS Density: 12.3 (ppg) Visc: 490 (s/qt) PVIYP: 23 (cp)/19 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 12 (lb/100ft2) Bottom Hole Circulating Temperature: (OF) Bottom Hole Static Temperature: (OF) Displacement Fluid Type:Seawater Density: 8.5 (ppg) Volume: 361.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry No: 1 of 3 To: (ft) Description: CW 100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.40 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:58:42 PM ) 'I ) Legal Well Name: 38-09 Common Well Name: 38-09 Event Name: ROT - DRILLING Report #: Start: 2 12/4/2002 8pud Date: 12/4/2002 Report Date: 12/15/2002 End: 12/17/2002 . . .... .. ~tageN(): 1 ~lurryNO: 2ofª Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 8,232.00 (ft}ro: 7,220.00 (ft) Cmt Vol: (bbl) Density: 13.30 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 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: Stage No:1SllIrryNC):30f3 Slurry Data Fluid Type: TAIL Description: Gasblok Slurry Interval: 9,639.00 (ft}ro: 8,232.00 (ft) Cmt Vol: 63.0 (bbl) Water Source: Slurry Vol:295 (sk) Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Class: G Density: 15.80 (ppg) Yield: 1.20 (ft3/sk) Water Vol: 36.3 (bbl) Other Vol: 0 Purpose: ZONAL ISOL Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: 3.70 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Trade Name Type DISPERSANT Gasblok DEFOAMER . Concentration Units 0.30 %BWOC D-65 D600G D-47 Temp (OF) (OF) Pressure (psi) (psi) LiquidConc. Units 2.00 G P S 0.20 G P S Printed: 1/31/2003 2:58:42 PM ) ) Legal Well Name: 3S-09 Common Well Name: 3S-09 Event Name: ROT - DRILLING Report #: Start: 2 12/4/2002 Spud Date: 12/4/2002 Report Date: 12/15/2002 End: 12/17/2002 Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation Interpretåtiol1SLJl11mary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Circ & Cond Mud for Cementing, Init Circ Rate 1.5 bpm @ 800 psi, staged up to 5.5 bpm, Init Press 1,160 Psi, Final Press 775 Psi, Attempted to Reciprocate after Est Circ, Worked Pipe Up to 375K with No Movement, Relanded Csg In Hanger, 410 Units Gas @ Btms Up, Circ & cond mud Lowered YP from 40 to 19, FV from 154 to 49, maintained 12.3 ppg mud wt in. Full returns throughout. PJSM Line up to cementers - pumped 2 bbls of FW and tested lines to 3500 psi. Pumped 10 bbls of CW 100, dropped btm plug - reload cmt head wI 2nd btm & top plugs. Pumped 40 bbls of 13.3 ppg MudPush XL, dropped 2nd btm plug- pumped 63 bbls of 15.8 ppg G wI adds - flushed cement line to head- drop top plug and displaced cement with 361 bbls of seawater @ 6 bpm 180-1203 psi -reduced rate to 3 bpm 1180 - 1588 psi with tail slurry at shoe bumped plugs to 2650 psi - floats held - full returns throughout - CIP @ 1320 hrs. Bled back 3.5 bbls. Printed: 1/31/2003 2:58:42 PM .) ') '"' ... . . ... ..... .. . . ConôcoPhillips,Alaska· . . . .. .. .. . . . ".". .. . ... ... ...... .. [)ailyD~iUingReport WELL NAME I JOB NUMBER I EVENOTDCRODE 124 HRS PROG TMD I TVD I DFS 9,650.0 6,020.0 11.40 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Nabors 7ES Kuparuk River 9,486.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Dropping ball to set packer 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL NO bope - NU tree-Freeze protect well - LD dp - release rig 12/15/2002 275,818 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 18.02 10027330 2,704,388 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 12/13/2002 9,579.93 51.000 41.160 7.000 (in) @ 9,639.0 (ft) (in) @ (ft) 12/8/2002 DENSITV(ppg) .1 12.30 Ippl IECD I IMUDbATAIDAILycqSTI 0.00 I CUM COST I 0.00 FVPVNP <3.ELSWUHTHP 'FClT.SOL OIWWAT %SandIMBT· Ph/pMPf/Mf ·CI Cà H2SLIME >ES 49 23/19 7/12 3.6/ 2/ / /22.5 8.5/ / I REPT NO. I DATE 13 12/15/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 2,010,765 3S-09 SUPERVISOR I RIG NAME & NO. David Burley I Peter Wils N1268@ppco.co CURRENT STATUS OPERATIONS SUMMARY FROM .TO PHASE DESCRIPTION 00:00 02:00 PROD RIH with 44 Jts of 7",26#, L-80 BTC Mod Csg (176 Jts Total) to 7,300' lost 10k SOW in last 10 jts ran - PU Wt 175K, S/O Wt 75k 02:00 03:00 1.00 CASE P CIRC PROD Circ Btms Up, Initial rate 3.0 bpm @ 687 psi -Final Rate 6 Bpm @ 830 Psi, Had Very Little Cuttings Back, mwt in 12.3 mwt out 12.6 - 12.3 ppg. Ave BGG 110 Units, PU Wt 185K, S/O Wt 90K 03:00 06:30 3.50 CASE P RUNC PROD Fin RIH with 7" Csg, Ran a Total of 231 Jts of 7" 26#, L-80 BTC-Mod, Landed Csg in Hanger with Float Shoe @ 9,638' and Float Collar @ 9,469', Ran Bow Spring Centralizers, Straight Blade's and Centralizing Guides per Well Plan, No Problems RIH and Had Full Returns Final PU Wt, 275K, S/O Wt 88K Ut # 230) 06:30 07:00 0.50 CASE P RURD PROD RD GBR's Fill-up Tool & MU Cement Head, Blew Down Top Drive 07:00 11:00 4.00 CEMENT P CIRC PROD Circ & Cond Mud for Cementing, Init Circ Rate 1.5 bpm @ 800 psi, staged up to 5.5 bpm, Init Press 1,160 Psi, Final Press 775 Psi, Attempted to Reciprocate after Est Circ, Worked Pipe Up to 375K with No Movement, Relanded Csg In Hanger, 410 Units Gas @ Btms Up, Circ & cond mud Lowered YP from 40 to 19, FV from 154 to 49, maintained 12.3 ppg mud wt in. Full returns throughout. PJSM 11:00 13:30 2.50 CEMENT P PUMP PROD Line up to cementers - pumped 2 bbls of FW and tested lines to 3500 psi. Pumped 10 bbls of CW 100, dropped btm plug - reload cmt head w/ btm / top plugs. Pumped 40 bbls of 13.3 ppg MudPush XL, dropped 2nd btm plug- pumped 63 bbls of 15.8 ppg G w/ adds - flushed cement line to head - drop top plug and displaced cement with 361 bbls of seawater @ 6 bpm 180-1203 psi -reduced rate to 3 bpm 1180 - 1588 psi with tail slurry at shoe bumped plugs to 2650 psi - floats held - full returns throughout - CI P @ 1320 hrs. Bled back 3.5 bbls. 13:30 15:30 2.00 CASE P RURD PROD LD cement head - flush stack - RD casing tools - LD landing joint. 15:30 16:45 1.25 CASE P DEQT PROD Install and test packoff 250/5000 psi. 16:45 17:30 0.75 CMPL TN P RURD CMPL TN PJSM. Ru to run 3 1/2" tubing. 17:30 18:30 1.00 CMPL TN P PULD CMPL TN MU 3 1/2" completion equipment: WLEG w/ shear out sub / pup - Camco "d" nipple w/ 2.75" no go - 2 pups - xo 3.5" x 4.5" - Mill out ext - Baker SA B-3 packer - KBH-22 Tubing anchor - Baker 80-40 PBR - Locator sub - pup - 1 jt 3 1/2",9.3#, L-80 tbg - Camco "DS" nipple w/ 2.813 profile - 1 jt tubing - pup- Camco MMG w/ DCR shear valve - pup - 18:30 00:00 5.50 CMPL TN P RUNT CMPL TN RIH with Completion equipment - 4613' (145 jts) run @ midnight. PUW 65K SOW 48K. Printed: 1/31/2003 3:05:30 PM WELL NAME ) ~) ··ConoçøPhilli þs, . Alaska. . .. ..... .......... .·DåUyDrilli ngReport. IJOB NUMBER I EVE~TDC~DE 124 HRS PROG IT~~650.0 38-09 I TVD I DFS I REPT NO. I DATE 6,020.0 11.40 13 12/15/2002 24 HR SUMMARY: Fin RIH with 7" Csg to 9,638', Circ & Cond Mud tor Cmtg, Cemented 7" Csg. Install and test Packott. Mu 3 1/2" Completion string and RIH picking up 31/2" tubing. COMPANY ConocoPhillips Nabors Doyon Universal 8perry 8un Fuel Water, Drilling RESERVOIR NAME 1 R-18 G & I Prudhoe Bay 38-07 UNITS gals bbls PERSQNNELDATA· NO.· . HOURS COMPANY 1 Baroid 36 CanRig 6 APC 4 Baker · MATERIAL.SlCONSUMPTION ON HAND .. ITEM 4,797 Fuel (camp) 164 Water, Potable RESERVPIR:ANDINTERVALDATA ZONE TOP. BASE . o 0 o 0 1674 3.8 750 38-09 38-09 Printed: 1/31/2003 3:05:30 PM Well Name: Drilling Supervisor: PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. 3S-09 I Rig: Nabors 7ES Date: 12/18/2002 Mike Thornton I Jack Kralick Pump used: #1 Mud Pump ... Type of Test: : Annulus Leak Off Test for Disposal Adequacy I Hole Size: IS-1/2" ¡ · Casing Shoe Depth RKB-CHF: 28.5 Ft 3,504 Ft-MD 2,595 Ft-TVD CasinQ Size and Dåscription: 9-5/S" 40#/Ft L-SO BTC ChanQes for Annular AdeQuacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. ... Pumping down annulus. Hole Depth 8,232 Ft-MD 5,204 Ft- TVº- Pressure InteQritvTest Mud Weight: 12.3 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 24.4 ppg 1633 psi 1.2 bbls I· EMW = Leak-off Pressure + Mud Weight = 1150 0.052 x TVD 0.052 x 2595 + 12.3 EMW at 3504 Ft-MD (2595 Ft-TVD) = 20.8 PIT 15 Second Shut-in Pressure, psi 450 1500 - UJ 0::: ::J (J) (J) UJ 0::: c... 500 o o 3 8 . 0 S 10 1 S 20 2S 30 Shut-In time, Minutes o PIT Point 4 6 7 Barrels .....CASING TEST ~LEAK-OFF TEST Comments: Initial test of 9 5/8" shoe = 18.0 ppg FIT. ISIP of 450 psi = 15.6 ppg EMW at 9 5/8" casing shoe (casing shoe not broached) Pumped 6-3/4 bbls at rate of 112 BPM, Bled back 3-3/4 bbls I'" I Volume Input Pump Rate: ¡ Barrels ... Bbls/Strk ... 0.31 Bbl/min ... Pressure Integrity Test Pumping Shut-in Bbls psi Min psi 0.25 350 0 500 0.5 500 0.25 450 0.75 600 0.5 450 1 650 1 400 1.25 700 1.5 4C J 1.5 750 2 40o--¿J 1.75 800 2.5 400 2 900 3 400 2.25 900 3.5 400 2.5 950 4 400 2.75 1000 4.5 400 3 1050 5 400 3.25 1100 5.5 400 3.5 1150 6 400 3.75 1150 6.5 400 4 1150 7 400 4.25 1100 7.5 400 4.5 1000 8 400 4.75 800 8.5 400 5 650 9 400 5.25 600 9.5 380 5.5 600 10 3{ -.-/ 5.75 600 6 600 6.25 600 6.5 600 6.75 600 !. Volume Bled Back 3.8 Bbls . Volume Volume Pumped Bled Back 0.0 Bbls _ Bbls Volume Pumped 6.8 Bbls TUBING (24-6246, 00:3.500, 10:2.992) ~OOUCT ION (26-6879, 00:7.000, Wt:26.00) Gas Lift \i1andrel/ValvE 1 (6113-6114, 00:5.968) NIP (6159-6160, 00:4.520) SEAL (6197-6199, 00:5.870) PBR (6199-6213, J 00:5.870) Anchor Nipple (6213-6214, 00:4.740) PACKER (6214-6219, 00:5.956) NIP (6238-6239, 00 :4.500) SHOE (6878-6879. 00 :7.000) CQiI1<>c¢.PhUliiþ¡ÂI.ka,.lnç~ [) I I I L-J ) ) KRU 3S-14 35-14 API: 501032043900 SSSVType: NIPPLE Angle (â¿ TS: 24 deg (â¿ 6559 Angle @ TO: 23 deg @ 6895 Well Type: SVC Orig Completion: LastW/O: Ref Log Date: TO: 6895 ftKB Max Hole Angle: 34 deg @ 2355 Rev Reason: Depth changes Last Update: 1/1712003 Annular Fluid: Reference Log: 24.33' RKB LastTag: Last Tag Date: Casing String - ALL STRINGS Description Size PRODUCTION 7.000 SURFACE 9.625 CONDUCTOR 16.000 Tubing String - TUBING Size I Top 3.500 24 Gas Lift MandrelslValves St MD TVD Man Man Mfr Type CAMCO MMG Top 26 29 29 Bottom 6879 2808 108 TVD 6161 2556 108 Bottom 6246 TVD 5584 Wt 9.30 I Grade I L-80 V Mfr V Type V OD Latch Port TRO OCR RK 0.000 1.5 6113 5464 1. Sheared Other lJlugs, equip., etc.: - JEWELRY Depth TVD Type 24 24 HANGER 496 495 NIP 6159 5505 NIP 6197 5539 SEAL 6199 5541 PBR 6213 5554 Anchor Nipple PACKER BAKER SAB-3 PACKER EXTENSION BAKER 80-40 MILL OUT EXTENSION NIP CAMCO '0' NIPPLE WINO GO PROFILE WLEG WIRELlNE GUIDE WISHEAR OUT SUB TTL SHOE Descri ption FMC 3.5" GEN 5 TBG HANGER CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE CAMCO 'OS' LANDING NIPPLE WINO GO PROFILE LOCATOR SUB & PBR 12' SEAL ASSEMBLY BAKER PBR 80-40 KBH-22 ANCHOR TUBING SEAL NIPPLE 6214 5555 6219 5559 6238 5576 6245 5583 6246 5584 6878 6160 General Notes Date Note 1/8/2003 TREE: FMC I WKM I GEN 51 5M TREE CONNECTION: TOP 5.75" ACME WITH 3.5" EUE8RD THREAD Wt 26.00 40.00 62.50 Grade L-80 L-80 H-40 Thread BTCM BTC WELD Thread EUE8RD o Date Vlv Run Cmnt 12/26/2002 (1) ID 3.500 2.875 2.812 3.500 2.970 2.993 3.250 3.730 2.750 2.992 2.992 6.151 ) ) Casing Detail 9 5/8" Surface Casinq ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 66 Nabors 7ES RKB to Landing Ring 29.10' FMC Gen V Hanger 9-5/8" 40# L -80 BTC Csg Davis Lynch Float Collar 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Shoe 64 Jts Jts 1 to 2 2Jts TD 12 1/4" Surface Hole 12-1/4" T.D. @ 28201 MD 2566' TVD 9-5/8" Shoe @ 28081 MD 25551 TVD RUN TOTAL 13 BOWSPRING CENTRALlZERS- 2 on jt.#1 (31 to 5' above Shoe on stop ring and over collar) 1 on Jt. #2 (On stop ring 51 below Float Collar) 1 per jt on Jt #3 - #12 (Total of 13 centralizers & 2 Stops) Total of 82 Jts. On location (Including extra float equip.) Total of 7 Jts. Outside shed (Including extra float equip.) Total of 75 Jts. Inside shed Run Total of 66 Jts. Total of 9 Jts. Left out inside shed Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 125k Dn Wt - 93k Block Wt - 30k Drifted all casing to 8.679" Well: 35-14 Date: 12/20/2002 LENGTH 29.10 2.27 2692.23 1.50 81.81 1.70 DEPTH TOPS 29.10 31.37 2723.60 2725.10 2806.91 2808.61 2820.00 Supervisor: Mike Thornton / Peter Wilson ) ) f;~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-14 9 5/8", 40# L-80 BTC 12/20/02 PAGE: RIG: 1 of 2 Nabors 7ES Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet @n1~~t 41.30 26 42.86 51 43.55 76 101 126 151 176 ~¡~iif 40.51 27 40.39 52 43.24 77 102 127 152 177 iI1~1: 41.13 28 42.81 53 41 .45 78 103 128 153 178 I 41.59 29 38.68 54 38.92 79 104 129 154 179 43.52 30 43.20 55 43.73 80 105 130 155 180 43.16 31 41.04 56 42.51 81 106 131 156 181 Î~¡j¡¡i~¡t 40.92 32 42.36 57 40.46 82 107 132 157 182 (I 42.95 33 42.20 58 41.73 83 108 133 158 183 42.65 34 41.93 59 41.87 84 109 134 159 184 I 42.18 35 43.11 60 42.81 85 110 135 160 185 40.32 36 42.88 61 43.49 86 111 136 161 186 ~¡~¡~j~~r 43.25 37 42.28 62 38.66 87 112 137 162 187 13 40.58 38 43.18 63 38.77 88 113 138 163 188 14 43.47 39 41.99 64 38.89 89 114 139 164 189 15 43.74 40 42.48 65 43.76 90 115 140 165 190 16 42.73 41 43.76 66 38.72 91 116 141 166 191 17 42.98 42 43.51 67 ~ 92 117 142 167 192 18 42.76 43 41.87 68 4&+ê 93 118 143 168 193 19 42.38 44 41.38 69 4&-: ..é. 94 119 144 169 194 20 41.86 45 42.54 70 4&W 95 120 145 170 195 21 42.01 46 42.98 71 4&+ê 96 121 146 171 196 22 40.98 47 43.21 72 4+:-99 97 122 147 172 197 23 43.48 48 41.41 73 ~ 98 123 148 173 198 24 41.87 49 42.90 74 ~ 99 124 149 174 199 25 42.40 50 41.81 75 ~ 100 125 150 175 200 Tot 1054.72 Tot 1056.76 Tot 1046.82 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3158.30 DIRECTIONS: TOTAL JOINTS THIS PAGE = 75 FLOAT SHOE FLOAT COLLAR HANGER RKB ) ) :~~~~'.PHILLIPS Alaska, Inc. Œi A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-14 95/8",40# L-80 BTC 12/20/02 PAGE: RIG: 2 of 2 Nabors 7ES Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 3158.30 DIRECTIONS: TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 75.00 AVERAGE JT = 42.11 ) ) . CÒnocoPhiHipsAlaskél· . . . . .. . .. . .... . . . .. "' . .. . Cèrn¡enti 119 ·R~port Legal Well Name: 38-14 Common Well Name: 38-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 1 Report Date: 12/20/2002 12/17/2002 End: Hole Size: 12.250 (in) TMD Set: 2,808 (ft) Date Set: 12/20/2002 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger pr¡ ."ary . . . . . Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Rick Gallegos SqÙeezeOpen Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start: 10: 15 Time End: : Time End: 13:38 RPM: SPM: 'nit Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 125 (Ibs) Type: Cement Casing Volume Excess %: 350.00 Meas. From: 227 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 410 (psi) Start Mix Cmt: 12:35 Start Slurry Displ: 12:35 Start Displ: 13:55 End Pumping: 14:30 End Pump Date: 12/20/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) Y 430 (psi) 1,000 (psi) 5 (min) Y Type: Spud Mud Density: 9.4 (ppg) Vise: 72 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud Max Torque: (ft-Ibf) Drag Down: 103 (Ibs) Returns: FULL Total Mud Lost: (bbl) Cmt Vol to Surf: 227.00 (bbl) Ann Flow After: N Mixing Method: TUB Density Meas By: Densometer PV/yP: 31 (cp)/23 (lb/100ft2) Gels 10 see: 9 (lb/100ft2) Gels 10 min: 14 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.4 (ppg) Volume: 205.60 (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: 50.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:59:12 PM ) ) Legal Well Name: 3S-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 1 Report Date: 12/20/2002 12/17/2002 End: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) . ..... . ",. '. . .. .. ~tagè No: f Sh,irryNO:2 of4 . Description: MUDPUSH XL Class: Cmt Vol: 38.0 (bbl) Density: 10.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Description: ARCTIC SET Class: G To: 1,661.00 (ft) Cmt Vol: 435.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (fP/sk) Slurry Vol570 (sk) Water Vol: 262.4 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 19.34 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name D79 S001 D46 D65 D124 053 D44 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Stage No:t Slurry No: 3 of 4 . Additives Type Concentration Units 1.50 %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.10 %BWOC 30.00 %BWOC %BWOC Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 1,661.00 (ftjro: 2,808.00 (ft) Cmt Vol: 99.7 (bbl) Water Source: Slurry Vol:250 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temp (OF) (OF) Pressure (psi) (psi) Liquid Conc. Units 9.00 %BWOW Class: G Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 44.2 (bbl) Other Vol: 0 Purpose: TAl L Mix Water: 7.44 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/31/2003 2:59:12 PM ) ) Legal Well Name: 38-14 Common Well Name: 38-14 Event Name: ROT - DRILLING Report #: 8tart: Spud Date: 12/18/2002 1 Report Date: 12/20/2002 12/17/2002 End: Type Concentration Units 0.50 %BWOC 0.60 %BWOC 29.54 %BWOC 1.00 %BWOC 16.63 %BWOC ~tage.N():.· iSlurrv No: 4~f4.. Ä~ditives .... .. D79 D46 D124 D65 D164 Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBl Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 72, YP from 48 to 23, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg RU Dowell, Pumped 5 bbls CW 100 Chem Wash, Tested Lines to 3,500 Psi, Pumped 45 bbls CW 100 Chem Wash at 8.3 ppg, 5.5 Bpm @ 155 Psi, Dropped Btm Plug, Pumped 38 bbls of 10.5# Mudpush spacer @ 3.0 bpm @ 125 Psi with Red Dye in Spacer, Mixed & Pumped 435 bbls, 570 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 140 Psi, Reciprocated Pipe until cmt. to surface, then Pipe got Tight-Landed Pipe, Observe Nut Plug and Red Dye Markers at Shakers, Pumped Lead Cmt until Cmt to Surface-31 bbls Late Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield, Pumped @ 6 Bpm @ 275 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 185.6 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 780 Psi, Slowed to 3 bpm @ 430 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eff on Rig Pumps, Had 227 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CI P at 1430 Hrs 12/20/02 Printed: 1/31/2003 2:59:12 PM ') ) 3S-14 SUPERVISOR 1 RIG NAME & NO. Mike Thornton/Peter Wils n1268@conocop CURRENT STATUS I JOB NUMBER I EVE~Dc~DE 124 HRS PROG I FIELD NAME I OCS NO. Nabors 7ES Kuparuk River ACCIDENTS LAST 24 HRS.? 24 HR FORECAST PU 8 1/2" BHA TIH, Test Csg, Drill Out Fit Equip, LOT LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 12/19/2002 2,732.05 30.320 349.980 9.625 (in) @ 2,808.0 (ft) Pi: NSITY(ppg) 9.40 Ippl IECpl IMlJDDATAlpÄn..ycdsT I FV .. PVIYP GELS· WLlHTHP . FCtr~SOL OILfWAT %SandlMBT Ph!pM 72 31/23 9/14 6.4/ 2/ / /20.0 8.51 .. OPERATIONS SUM MARY. PHASE PESCFlIPTION SURFAC Fin Ru Nabors Csg Equipment & GBR Fill up Tool, Held PJSM SURFAC MU 95/8" Float Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, While RIH with Csg, Started taking Wt at 1,580', Attempted to Circ & Fill Up Tool Malfunctioned SURFAC LD Fill Up Tool & MU Circ Swedge, Washed & Worked Csg Thru Base of Permafrost from 1,580' to 1,780', MU Fill Up Tool with Check Valve Removed SURFAC Cant RIH with 9 5/8" Csg, Landed Csg in Head - Ran a Total of 66 Jts to 2,808.61' Landed Csg wI FS @ 2,808', FC @ 2,723'. SURFAC RD Fill Up Tool & MU Cmt Head SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis from 128 to 72, YP from 48 to 23, Final Circ rate 6.7 Bpm at 300 Psi, Last 80 bbls of mud pumped had Nutplug for Marker, Reciprocated Pipe with Full Returns, Held PJSM on Cmtg Csg PUMP SURFAC RU Dowell, Pumped 5 bbls CW 100 Chern Wash, Tested Lines to 3,500 Psi, Pumped 45 bbls CW 100 Chern Wash at 8.3 ppg, 5.5 Bpm @ 155 Psi, Dropped Btm Plug, Pumped 38 bbls of 10.5# Mudpush spacer @ 3.0 bpm @ 125 Psi with Red Dye in Spacer, Mixed & Pumped 435 bbls, 570 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 7.0 bpm @ 140 Psi, Reciprocated Pipe until cmt. to surface, then Pipe got Tight-Landed Pipe, Observe Nut Plug and Red Dye Markers at Shakers, Pumped Lead Cmt until Cmt to Surface-31 bbls Late. Switched to Tail Cmt, Pumped 250 sxs (99.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.4 Yield, Pumped @ 6 Bpm @ 275 Psi, DISP SURFAC Dropped Top Plug & Dowell Pumped 20 bbls Water, Turned over to Rig, Rig Pumped 185.6 bbls of 9.4 ppg mud, Ave Disp Rate 8 bpm @ 780 Psi, Slowed to 3 bpm @ 430 Psi, Bumped Plug to 1,000 Psi, Displ Calc 95% Eft on Rig Pumps, Had 227 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 14:30 Hrs 12/20/02 SURFAC Checked Floats & Held, RD Cmtg & Csg Equipment, LD Landing JT SURFAC Flushed Divertor System with Water SURFAC Cleaned Rig Wind Walls & Mud Pits SURFAC ND 21 1/4" Divertor & 16" Line & Removed Starting Head SURFAC Installed FMC 11" 5M Gen V Wellhead & 11" 5M Tbg Spool & Set on BOP Stack, NU Wellhead & Tbg Spool & Tested Seals to 1,000 Psi, Good Test WELL NAME Testing BOP's 04:00 07:30 3.50 CASE Np RUNC 07:30 09:30 2.00 CASE P RUNC 09:30 10:00 0.50 CASE P RURD 10:00 12:00 2.00 CEMENT P CIRC 12:00 14:00 2.00 CEMENT P 14:00 14:30 0.50 CEMENT P 14:30 17:00 2.50 CEMENT P RURD 17:00 17:30 0.50 CEMENT P OTHR 17:30 19:30 2.00 RIGMNT P RSRV 19:30 22:00 2.50 WELCTL P NUND 22:00 00:00 2.00 WELCTL P NUND TMD 1 TVD I DFS 2,820.0 2,566.0 3.00 AUTH MD I DAILY TANG 6,918.0 0.00 DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 12/18/2002 339,231 ILEAKOFF AFE 10027622 I NEXT CASING 7.000 (in) @ 6,918.0 (ft) 0.00 IClJMCOST I Pf/Mf CI· . Ca H2S / I REPT NO. I DATE 4 12/20/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 603,968 AUTH. LAST BOP PRES TEST 0.00 LIME·· ES Printed: 1/31/2003 3:05:10 PM ) ') 3S-14 I JOB NUMBER I EVE~DC~DE 124 HRS PROG ITVD I DFS 2,566.0 3.00 I REPT NO. I DATE 4 12/20/2002 WELL NAME 24 HR SUMMARY: Ran & Cemented 9 518" Csg to 2,808', Had 227 bbls of Cmt Back, Bumped Plugs & Floats Held, CIP @ 14:30 Hrs, RD Csg Tools, Cleaned Around Rig, ND Divertor & Line, MU Gen V Wellhead & Tbg Spool, RIG CAMP WENT ON HIGHLlNE POWER @ 09:1512/20/02 PERSONNEL.·DATA . . · NO~HOURS COMPANY 2 Sperry Sun 32 Baroid 6 APC Fuel Water, Drilling . MATERIALSl CONSUMPTION ON HAND. ITEM 17,076 Fuel (camp) 92 Water, Potable RESERVOIR NAME 3S-07 1 R-18 G & I Prudhoe Bay 3S-14 3S-14 3S-14 .RESERVOIR,ANDINTERVAL. DATA ,. ZONE . TOp· BASE 2306 2.5 750 psi o 0 o 0 Printed: 1/31/2003 3:05:10 PM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: 3S-14 I Rig: NABORS 7ES Date: 12/21/2002 I Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: MIKE THORNTON/PETER WILSON I Pump used: I #1 Mud Pump , ¡... Strokes ... 0.06981 Bbls/Strk'" 8.0 Strk/min Type of Test: I Casing Shoe Test LOT/FIT i ...1 Pumping down I annulus and DP. !... Casing Test! Pressure Integrity Test Hole Size: USE PICK LIST I · Casing Shoe Depth I Hole Depth Pumping RKB-CHF: 27.0 Ft 2,808 Ft-MD 2,555 Ft-TVD 2,840 Ft-MD 2,583 Ft-TVD Strks psi Casina Size and Description: 9-5/8" 40#/Ft L-80 BTC .1 0 0 Casina Test Pressure IntearitvTest 7 545 Mud Weight: 9.4 ppg Mud Weight: 9.3 ppg 14 950 Mud 10 min Gel: 14.0 Lb/100 Ft2 Mud 10 min Gel: 8.0 Lb/100 Ft2 21 1345 Test Pressure: 2,500 psi Rotating Weight: 98,000 Lbs 28 1815 Rotating Weight: 98,000 Lbs BlocksfTop Drive Weight: 25,000 Lbs 35 2350 BlocksfTop Drive Weight: 25,000 Lbs Desired PIT EMW: 18.0 ppg 37 2550 Estimates for Test: 1.7 bbls Estimates for Test: 1156 psi 0.8 bbls ·1 EMW = Leak-off Pressure + Mud Weight = 935 0.052 x TVD 0.052 x 2555 + 9.3 EMW at 2808 Ft-MD (2555 Ft-TVD) = 16.3 ppg PIT 15 Second Shut-in Pressure, psi 430 3000· - Lost 0 psi during test, held 100% - of test pressure. UJ c::: :::J V) V) UJ c::: a.. o 5 10 15 20 25 Shut-In time, Minutes o PIT Point Volume Volume Pumped Bled Back 2.6 ~bls 2.6 tsbls 4.0 ~bls Minimum acceptable LOT is 14.1 ppg I:.MW for this well. The point at 725 psi could be interpreted as the leak-off point (14.8 ppg EMW). JU+U~ I ¡ ¡ ¡ I : 500 I ¡ i ! I ~~. J.~ ~~j¡~j,. '="'I'~~··· . ,. -?,' I 1 I I I I 4 2 Barrels -"-CASING TEST ~LEAK-OFF TEST Comments: . 30 ... Shut-in Pumping Shut-in Min psi Strks psi Min psi 0 2550 0 0 0 480 1 2550 3 230 0.25 430 2 2550 5 400 0.5 430 3 2550 7 565 1 430 4 2550 9 725 1.5 420 '0..___ 5 2550 12 860 2 420 6 2550 14 935 2.5 420 7 2550 21 464 3 420 8 2550 28 460 3.5 420 9 2550 35 450 4 420 10 2550 42 436 4.5 420 15 2550 49 443 5 420 20 2550 57 440 5.5 420 25 2550 6 420 30 2550 6.5 410 7 410 7.5 410 8 410 8.5 410 9 410 9.5 410 10 410 ~ Vo ume Bled Back 0.5 ~bls ) ) Casing Detail 7" Intermediate CasinQ ConocoPhillips Alaska Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 11" X 1" Hanger Jts 5 to 162 158 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 402 Float Collar Jts 1 to 4 4 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Sure-Seal Model 303 Float Shoe TD of 8-1/2" hole @ 6,895' MD 6175' TVD 7" Shoe @ 68791 MD 6160' TVD Total Centralizers 1- 7" Bowspring cent.! stop rings 10 above FS jt # 1 & 10 below FC 0 Bowspring centralizer over collar on joints #2 , #3 and #5 thru #32 7" x 8-3/8" Centering guide on every jt. From #97 thru #101 (Total of 5) 7" x 8-3/8" Centering guide on every 3rd Jt. # 152, 155, 158, 161. (Total of 4) Totals: 32 Bowspring, 9 centering guides, 2 Stop collars Total of 181 jts.on location Total of 162 jts. Ran in hole Total out: 19 jts. (last jt on tally # 170 in shed - [11 jts Outside shed not on tally) ( Including xtra float equip. Use "Run-N-Seal" pipe dope Drifted to 6.151" Remarks: Up Wt = 205k On Wt = 125k Block Wt= 30k Well: Date: LENGTH 26.40 1.85 6679.21 1.27 169.61 1.46 35-14 12/25/02 DEPTH TOPS 26.40 28.25 6707.46 6708.73 6878.34 6879.80 Supervisor: Mike Thornton / G. Rizek ') ') ConocoPhillips Alaska CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-14 7", 26# L-80 BTCM 12/25/02 PAGE: RIG: 1 of 2 NABORS 7ES Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet ~ .,.................... 1 " 2.65 26 ..1 1 .17 51 41.10 76 43.42 tf:ltW~~: 43.17 126 43.11 151 43.17 176 :mIàt~ fiïf '.................., 40.67 43.09 52 43.45 77 43.44 102 43.11 127 43.15 ~@~\ 43.09 177 '¡¡¡¡¡¡~¡I~ '.::.::.:;'.:~'~ 43.20 JIll 41.28 53 41.12 78 39.65 103 42.34 128 40.98 153 41.03 178 ::::::::;!;I!:::::;: 43.09 :I!~tm 43.17 54 43.34 79 43.01 104 39.28 129 41.39 154 43.18 179 ¡¡¡¡¡¡¡¡i¡¡¡r 43.30 :¡¡¡¡~ær 40.27 55 41.82 80 43.03 105 42.81 130 40.91 ~W$J 41.36 180 :.:.:.:.:.1.:,1.:.1,,11 ':.:.=.:.:.:.:.:.:J }~~~~!št~~~ 43.07 :~~~~~:tr 43.48 56 41.11 81 43.14 106 42.98 131 42.99 156 41.14 181 '....................... ............... :::f~*::I 40.88 :Jß.¿f 41.55 57 42.03 82 40.57 107 43.18 132 41 .45 157 42.86 182 :::::~:::!::~!:~~ ,..... ..... :::::)~t:::: 42.70 33 42.96 58 41.54 83 43.07 108 41.12 133 43.17 :4mt 41.01 183 1.............1...1. ~~r:~9~r:~ 41.81 34 43.19 59 43.15 84 41.67 109 41.47 134 41.41 159 40.13 184 :::.::::::::::::::> ~mðÞm: 41.33 35 43.16 60 41.88 85 42.56 110 42.96 135 42.40 160 42.97 185 .... ...'...~ 10.·_.··.··0··_· i:::::~:lJ 41.60 36 43.17 61 41.27 86 41.27 111 37.98 136 40.05 161 40.30 186 ~t~~:s:~~: 43.16 37 39.77 62 41.52 87 43.27 112 42.30 137 43.18 162 39.10 187 ï.rIY.ï,ï. :::::::1:3::;: 43.09 38 43.16 63 39.50 88 43.26 113 42.48 138 41.65 163 ~ 188 :.:.1.:.1.:.:.:.:.:,,11 ~ri~¡r 43.16 39 43.13 64 42.25 89 43.09 114 43.39 139 40.57 164 ~ 189 ....................... m~~~K 43.17 40 42.96 65 43.30 90 43.45 115 43.09 140 40.70 165 4&QS 190 ~r~f:j~6t 42.18 41 43.27 66 40.69 91 43.30 116 43.14 141 43.19 166 ~ 191 :¡¡¡:¡~¡j:¡:¡ 43.25 42 42.96 67 41.97 92 43.13 117 43.07 142 43.22 167 ~ 192 ':':':":':':':':':"":'<, :tmn: 42.69 43 41.38 68 43.39 93 43.09 118 43.23 143 43.00 168 43:G+ 193 ....·..·..·.oJ !:I:I:II!:I~ 43.19 44 40.87 69 42.21 94 42.65 119 42.46 144 43.16 169 4&+é- 194 43.17 45 41 .49 70 43.09 95 40.59 120 43.41 145 39.97 170 ~ 195 :(((((((((t t~~2ilf 43.00 46 43.15 71 43.43 96 43.32 121 41.83 146 41.10 171 196 ~X::(:X:X:)j :::H¡~ir 43.20 47 43.44 72 42.95 :::::9.7::::: 43.39 122 42.84 147 41.00 172 197 ........-.............. <.:.:.:.:.:.:.:.:J :~Iãir 43.15 48 43.38 73 43.10 :t~~J 42.09 123 43.03 148 43.21 173 198 ':":':':"::x';.,; Íi'.:x"f:'f.::·~' :~¡:!~;¡!:¡? 43.10 49 40.03 74 41.17 ~:~~æJ 43.44 124 40.04 149 41.38 174 199 4.1.1.1.1".1.1.1. ·.·.·.·a·.·.·.·.·.·... 40.72 50 43.17 75 42.24 ::~j«r 43.12 125 43.41 150 43.20 175 200 Tot 1 064.53 Tot 1 058.65 Tot 1 052.62 Tot 1066.02 Tot 1 058.12 Tot 1 049.54 Tot 842.83 Tot TOTAL LENGTH THIS PAGE = 7192.31 DIRECTIONS: TOT AL JOINTS THIS PAGE = 170 ) ) ARCO ALASKA INC CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: 3S-14 7", 26# L-80 BTCM 12/25/02 PAGE: RIG: 2 of 2 NABORS 7ES Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301 326 351 376 202 227 252 277 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 ~ 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 7192.31 DIRECTIONS: TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 170.00 AVERAGE JT = 42.31 ') ) Legal Well Name: 3S-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 2 Report Date: 12/26/2002 12/17/2002 End: Hole Size: 8.500 (in) TMD Set: 6,879 (ft) Date Set: 12/25/2002 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger . . '" .. . SqueezeOpén Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Rick Gallegos Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:20:00 Time End: : Time End: 06:45 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 10.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 205 (Ibs) Max Torque: (ft-Ibf) Drag Down: 125 (Ibs) Type: Cement Casing Volume Excess %: 45.00 Meas. From: Time Circ Prior To Cementing: 9.00 Mud Circ Rate: 167 (gpm) Mud Circ Press: 385 (psi) Start Mix Cmt: 04:15 Start Slurry Displ: 04:47 Start Displ: 05:38 End Pumping: 06:53 End Pump Date: 12/26/2002 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 11.7 (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: 4.50 (bbl/min) 4.50 (bbl/min) Y 1 ,650 (psi) 2,300 (psi) 5 (min) Y Returns: FULL Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch Density Meas By: Densometer Mud.Data·. PVNP: 15 (cp)/16 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 12 (lb/100ft2) Bottom Hole Static Temperature: 145 (OF) Density: 8.4 (ppg) Volume: 265.10 (bbl) Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 3,741.00 (ft)To: 4,183.00 (ft) Cmt Vol: 10.0 (bbl) Water Source: Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (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: 1/31/2003 2:59:03 PM ) ) Conoc.oPhillipsAlaská. :Cernenting ... Report· Page 2 of3 Legal Well Name: 3S-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 2 Report Date: 12/26/2002 12/17/2002 End: . . ... $tag~ No: 1.· Slurry NØ: ·2013 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 4,183.00 (ft}ro: 5,510.00 (ft) Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 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) StageNC):1SlurryNo: 30f 3 Slurry Data Fluid Type: TAIL Description: G wI Gasblock + 1/4 #/sac Class: G Slurry Interval: 5,510.00 (ft}ro: 6,879.00 (ft) Cmt Vol: 51.0 (bbl) Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Source: Slurry Vol:246 (sk) Water Vol: 30.3 (bbl) Other Vol: 0 Purpose: PRI MARY Mix Water: 5.17 (gal) Foam Job: N Test Data Thickening Time: 4.12 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) Stage No: 1· Slurry No: 3 of 3 -Additives Type Concentration Units· Liquid Cone. Units 065 8155 0600 047 0.30 %8WOC 0.02 %8WOC 2.00 G P S 0.20G P S Printed: 1/31/2003 2:59:03 PM ) ') ConocophillipsAlaska CeR1enti.,gReport Legal Well Name: 38-14 Common Well Name: 3S-14 Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/18/2002 2 Report Date: 12/26/2002 12/17/2002 End: Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 30 bbls MudPUSH @ 12.5 ppg, 246 sxs (51 bbls) @ 15.8 ppg Class "G" GasBLOK and 1/4 #/sack celloflakes wI + .300%BWOC D65, .020%BWOC B155, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 5 bbls CW100, Test lines to 3500 psi, Pump 5 bbls CW1 00, Drop #1 btm plug, Reload head, Pump 30 bbls MudPUSH at rate of 4 bpm at 475 psi, Drop #2 btm plug, Pump 51 bbls cmt at rate of 4.5 bpm at 390 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Dowell Displace first 181 bbls seawater at rate of 4.5 bpm at 990 psi until MudPush around shoe, Slowed rate to 3.0 bpm @ 1050 psi until last 30 bbls of displacement then slowed rate to 2 bpm @ 1650 psi & bumped plug wI total of 265.1 bbls, Bumped plug wI 2300 psi, Bled back 2.0 bbls for a total of 263.1 total bbls displaced (Calculated 263.3 bbls), CIP @ 0653 hrs 12/26/02, Had good circ. thru out job- no noticeable mud loss, Displaced entire job with Dowell. Worked casing 10' thru out entire job until last 10 bbls of displacement, then landed in hanger. Check flow- Well static. Printed: 1/31/2003 2:59:03 PM ) ) I JOB NUMBER I EVEONTDCRODE 124 HRS PROG TMD I TVD I DFS 6,895.0 6,175.0 9.00 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Nabors 7ES Kuparuk River 6,918.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Rigging up fl injectivity test 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Finish work on well, freeze protect, secure well, UD DP, RR 12/22/2002 447,446 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 16.34 1 0027622 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 12/23/2002 6,895.00 22.080 346.760 9.625 (in) @ 2,808.0 (ft) 7.000 (in) @ 6,918.0 (ft) DENSITY(ppg) 8.50 Ipp I eCD I MUD IJA1"AIDAILYC()ST I 0.00 IÓUMCOST FV PVNP.· >GELSWLlH1:1iPFÓrr.SOL OIL/WÄT· %Sand/MBTPh/pM Pf/MfCI Ca 28 I I I I I I WELL NAME 3S-14 SUPERVISOR I RIG NAME & NO. Mike Thornton/G. Rizek n1268@conocop CURRENT STATUS CçnbcoPh lIips, Alaska . ... . ... . .. .. .... . DaHy [)rlli ngReport · I REPT NO. I DATE 10 12/26/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,722,075 AUTH. LAST BOP PRES TEST 12/21/2002 0.00 H2S··. LIME ES 01 :00 01 :30 0.50 CEMENT P 01:30 05:00 3.50 CEMENT P 05:00 08:00 3.00 CEMENT P OPERA TI()NSSUIVI MARY PHASE PROD DESCRIPTION Continue to circ and condition hole prior to cement job on 7" 26 # L-80 BTC-Mod casing. Reducing MW f/12 ppg to 11.7 ppg Recip 10' wI PU 205 k & SO 125 k Circ one bottoms up after 11.7 ppg all the way around @ 4.5 bpm 390-420 psi. Gas 17-20 units RURD PROD RID Frank's fillup tool. RU Dowell cement head. Well flowing(Breathing) while changing out head. Flowed back 7.3 bbls in 30 minutes. CIRC PROD Continue to circ wI Dowell cement head. Recip casing. First movement off hanger after changing out head req'd 240 k. Then normal PU wt of 190k-205k. SO 120K- 125K. 155 bbls into circulation, max gas units of 153. (Guage hole would indicate 6194') Decressed to 50 units by 180 bbls pumped and progressive back to 0-20 units. Circ @ 4 bpm 380-390 psi Dowell batch mix 10 bbls CW 100 @ 8.3 ppg, 30 bbls MudPush @ 12.5 ppg, 246 sx (51 bbls) @ 15.8 ppg Class "G" GasBlok WI .3%BWOC D65, .02%BWOC B155, 2.0 gal/sk D600G, .2 gal/sk D47 & 1/4 #/sx celloflakes PUMP PROD PJSM on cemeting 7" casing. Dowell pump 5 bbls CW 100 @ 8.3 ppg, test lines to 3500 psi, pump 5 bbls CW100 @ 8.3 ppg, drop bttm plug, reload head wI another bttm and top pug. Dowell pump 30 bbls MudPush @ 12.5 ppg @ rate of 4 bpm wI 475 psi. Drop another bttm plug, pump 51 bbls Class "G" GasBlok @ 15.8 ppg wI additives at rate of 4.5 bpm with 390 psi, shut down, flush lines to rig floor wI seawater. Drop top plug, Dowell displace first 181 bbls seawater @ 8.4 ppg at rate of 4.5 bpm with 990 psi until MudPush around shoe, then slowed rate to 3 bpm with 1050 psi until last 30 bbls of the displacement. For the last 30 bbls of displacement the rate was 2 bpm with 1650 psi. Bumped plug wI total of 265.1 bbls, bumped wI 2300 psi. Bled back 2 bbls for total of 263.1 bbls displaced (Calculated 263.3 bbls). CIP @ 0653 hrs 12/26/02. Had good circ throughout job. No noticable mud losses. Displaced entire job wI Dowell. Recip casing 10' stroke throughout entire job until last 10 bbls of displacement, then landed hanger. Printed: 1/31/2003 3:04:33 PM WELL NAME 3S-14 FROM· TO 08:00 09:30 09:30 10:30 1.00 WELCTL P 10:30 11:30 1.00 CMPL TN P 11:30 12:00 0.50 CMPL TN P 12:00 19:30 7.50 CMPL TN P 19:30 21:00 1.50 CMPL TN P 21:00 22:00 1.00 CMPL TN P -) ~~) I JOB NUMBER I EVE~DC~DE 124 HRS PROG 22:00 23:00 1.00 CMPL TN P 23:00 00:00 1.00 CMPL TN P TVD I DFS 6,175.0 9.00 I REPT NO. I DATE 10 12/26/2002 OPERÄTIONS.SUIVIMARY . ··PHASE DESCRIPTION··. PROD Flush out BOP stack wI water, mud pump # 2, kill & choke lines to get mud out of system. UD Landing joint. Install FMC packoff on 7" casing hanger. RILDS. Test to 5000 psi f/15 min. PU tubing equip. RU to run 31/2" completion. PJSM on running 3 1/2" completion. Run 3 1/2" 9.3#/ft L-80 EUE 8rd-mod completion equip (197 joints wI jewlery) to 6245.67'. PU wt 80 K SO wt 65 K RU & Pressure test 7" casing to 3500 psi fl 30 min test. Chart test. Plot test. Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 6213.78' Slowly pressure 3 1/2" tubing to 2500 psi. Wait 10 min. Slack off 20k, then continue to pressure tubing string to 3000 psi and hold fl 15 min. Bleed pressure to 1000 psi. PU to 105k to shear PBR. Slack off, tag locator w/1 Ok. Pressure to 3676 psi to shear ball seat. Bleed off all pressure. SOHO PROD Pull joint 197 out of hole (pulling 12' seal assembly out of polished bore recepticle). MU 3 1/2" FMC tubing hanger on joint # 196. Use joint # 197 as landing joint. RIH and land tubing wI locator 2' above fully located in PBR. RILDS. OTHR PROD Pressure 31/2" tubing to 3500 psi fl 15 min. Bleed pressure to 1500 psi. Pressure 7" x 31/2" annulus to 3500 psi fl 15 min (Pressure on tubing increased to 2100 psi). Bleed tbg pressure to zero. RP sheared wI tubing pressure @ 500 psi. Bleed both sides to zero. All tests were charted. OTHR PROD RURD PROD SFTY PROD RUNT PROD OTHR PROD PCKR PROD 24 HR SUMMARY: Recip 7" csg @ 6880' wI circ , MU cmt head, circ, cmt 7" csg-CIP @ 0653 hrs, Flush BOP's, chng bales, RID cmt equip, UD Ind jt, inst packoff , RU/Run 31/2" compl, test 7", set pkr, shear PBR, shear ball seat, PU/MU hanger, Lnd, RILDS, test tbg, test ann COMPANY ConocoPhillips Nabors Doyon Universal PERSONNEL DATA NO. HOURS COMPANY 2 Sperry Sun 33 Baroid 6 APC SERVICE ITEM Fuel Water, Drilling UNITS gals bbls RESERVOIR NAME 3S-07 1 R-18 G & I Prudhoe Bay 3S-14 3S-14 3S-14 SERVICE NO. HOURS 3 2 2 USAGE 2,267 409 MATERIALS/CONSUMPTION ON HAND ITEM 9,355 Fuel (camp) 642 Water, Potable ON HAND 1,932 14,310 UNITS gals gals USAGE 4,680 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 795 1.5 950 o 0 o 0 COMMENTS Printed: 1/31/2003 3:04:33 PM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. I Rig: Nabors 7ES I Date: 12/27/2002 I Mike Thorton/ Granville Rizek Pump used: ! #1 Mud Pump I Volume Input Well Name: Drilling Supervisor: 38-14 VolumelStroke i ... 0.0698 Bbls/Strk! ... Pump Rate: I 8.01 Strk/min i Pressure Integrity Test ... Strokes ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" ... Casing Shoe Depth RKB-CHF: 27.0 Ft 2,808 Ft-MD 2,555 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. ... Pumping down annulus. ... Casin9 Test Hole Depth Pumping Shut-in 5,510 Ft-MD 4,941 Ft-TVD Strks psi Min psi i . 0 50 0 860 2 90 1 810 4 100 2 800 6 125 3 800 8 200 4 780 10 250 5 760 11 300 6 750 12 310 7 730 13 350 8 725 14 375 9 710 15 400 10 710 16 410 151 17 425 20 18 450 25 19 490 30 20 510 21 530 22 575 23 590 24 600 25 630 26 690 27 710 28 725 29 730 30 780 31 800 32 810 33 850 34 860 Volume Volume Pumped Bled Back 2.4 Bbls _Bbls 95/8" @ 2808' TVD of 2555 was 16.3 EMW - TOC in 8-1/2" x 7" annulas calculated at 5510' MD 4941' TVD Casing test Data indicates first attempt at 7" x 9-5/8" injection test and turned into a FIT, Rocked 850 psi (18.0 EMW) several times and pressure broke down at 490 psi for EMW of 15.4 ppg Note; Mud in 7" x 9-5/8" annulas contained 10-20 ppb LCM Pumping Strks psi o 50 2 90 4 200 6 310 8 350 10 450 12 490 14 500 16 500 18 500 20 500 22 500 24 500 26 500 28 500 30 500 32 500 34 500 36 500 38 500 40 500 42 500 44 500 46 500 48 500 50 500 52 500 54 500 56 500 57 500 Volume Pumped 4.0 Bbls Shut-in Min psi o 500 0.25 400 0.5 375 1 350 1.5 3;- 2 31~ 2.5 300 3 300 3.5 300 4 300 4.5 300 5 300 5.5 300 6 290 6.5 290 7 290 7.5 290 8 285 8.5 280 9 275 9.5 27F- 10 2: -,,' Pressure IntearitvTest Mud Weight: 11.7 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 18.0 ppg 837 psi 0.4 bbls I... ... EMW = leak-off Pressure + Mud Weight = 490 0.052 x TVD 0.052 x 2555 + 11.7 EMW at 2808 Ft-MD (2555 Ft- TVD) = 15.4 PIT 15 Second Shut-in Pressure, psi 400 1 000 - - Lost 860 psi during test, held 0% of test pressure. \. \:. I '1 u.J a::: :::J V'J V'J u.J a::: a.. 500 - o o 4 S o S 10 1 S 20 2S Shut-In time, Minutes o PIT Point 30 Barrels Volume Bled Back 0.5 Bbls ~CASING TEST ~LEAK-OFF TEST Comments: 3S-1O Permit to Drill 'Subject: 38-10 Permit to Drill Date: Mon, 23 Dee 200208:55:22 -0900 From: "Scott L Lowry" <Scott.L.Lowry@conocophillips.com> To: winton_aubert@admin.state.ak.us CC: "Randy L. Thomas" <Randy.L.Thomas@conocophillips.com>, " Sharon Allsup-Drake" <Sharon.K.Allsup- Drake@conocophillips.com> Winton, ConocoPhillips requests to expedite the processing of the permit to drill for well 38-10. The approximate spud date given in the permit application was 1/1/2003. It appears Nabors 7E8 will be ready to move on to 38-10 on 12/26/02. The reason for this request is better than expected drilling performance on 38-09 and 38-14. Thank you for your assistance, 8cott L Lowry Drilling Engineer ConocoPhillips Alaska Inc. Voice: 907-265-6869 Cell: 907-240-5322 E-Mail: scott.l.lowry@conocophillips.com ¡) ) ~J~~E ~ f ~~~~~~~ FRANK H. MURKOWSK'. GOVERNOR ~ AlfASIi& OIL AND GAS CONSERVATION COMMISSION 333 W. ]fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK. 99510 Re: Kuparuk River Unit 3S-10 ConocoPhillips Alaska, Inc. Pennit No: 202-232 Surface Location: 2501' FNL, 993' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 1785' FSL, 1059' FWL, Sec. 8, TI2N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above development well. This pennit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~?-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this.2.3~ day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~. .".~i".".:.. ...,) ~~ 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 December 2, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 3S-1 0 Dear Commissioner Taylor: / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 3S-10, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, '~~~ Randy Thomas GKA Drilling Team Leader RECEIVED DEe 0 5 2002 AlasHa 01/·& Gas Qo . AnChor:e CommIsSion ~"¡6A- I 2-l'l'c/ " ~L ) ) 1 a. Type of work: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Exploratory U Stratigraphic TesU Development Gas D Single Zone D 5. Datum elevation (OF or KB) RKB = 28' AMSL 1b. Type of well. Service D Drill l:!.I Redrill U Re-entry D Deepen D 2. Name of Operator ConocoPhillips 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2501' FNL, 993' FEL, Sec. 18, T12N, R8E, UM At top of productive interval 1751' FSL, 1043' FWL, Sec. 8, T12N, R8'E, UM At total depth 1785' FSL, 1059' FWL, Sec. 8, T12N, R8E, UM 12. Distance to nearest property line 13. Distance to neares~ñ 1751' @ Target 3S-09 @ 450' 16. To be completed for deviated wells Kickoff depth: 200 MD 18. Casing program size feet 6. Property Designation ADL 380107/380106 ALK 4624/4623 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well numbey' Number 3S-10 ì#~ #59-52-180 9. APpr,oXima, te spud date /. I Amount JaQyaJ:¥".~~03 ¡ z. :z...'5 O'Z- $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2448 8026' MD /6040' TVD 17. Anticipated pressure (see ~C 25.035 (e)(2)) Maximum surface 2970 psig At total depth (TVD) 3611 psig Setting Depth Development oW Multiple Zona 10. Field and Pool Kuparuk River Field ~ Kuparuk River Oil Pool / Maximum hole angle 510 Hole Casing Weight Specifications Grade Coupling l:j¿I{) V\!eld Length 80' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' 9 cy High Early 28' 28' 3386' 2605' 570 sx AS Lite & 270 sx LiteCrete 28' 28' 8026' 6040' 210 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Length Size Cemented Measured depth True Vertical depth SurfacE! Production RECEIVED Perforation depth: measured DEC 05 2002 true vertical Alaska Oil & Gas Gons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat D BOP SketctQ Diverter SketcO Drilling progr~ Drilling fluid program 0 Time vs depth plot D Refraction analysis D Seabed report D 20 MC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869 Signed '< \ '--~ ,,~ R. Thomas , Title: Kuparuk Drilling Team Leader Date , ê- ( '-( (ó l. Preoared bv Sharon A((slJo-Drake Permit Number ZO';¿ - .2..... 3 ~ Commission Use Only I API number I Approval date .~ 50- /03- .2.0 ýI C70 (...~\ Samples required DYes J8] No Mud log required D Yes ~ No Directional survey required D2M; D 3M; D 5M; D 10r[] I 50(.-:00 f ~ ( . I' I See cover letter ,'7)] QJ\. for other requirements , D Yes ~ No ~ Yes D No Conditions of approval Hydrogen sulfide measures Required working pressure for BOPE Other: Të'7 t- ~ P E t--c D Approved by ORI~~AI .SI~NFn RY M L. Bill Commissioner by order of I t OeRt m1i?\Onr .,"". .! .', [Date (, X ,~\3 Or I I ... ':. I j ¡ \;1 ¡ I \~' l'~ Submit in triplicate Form 10-401 Rev. 12/1/85· ) Appl'~"tion for Permit to Drill, Well 3S-10 J Revision No.O Saved: 27-Nov-02 Permit It - Kuparuk Well 38-10 Application for Permit to Drill Document Ml)ximizE We-II "'OIUE; Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f).... .................................... ..................................... ................. .......... 2 2. Location Sum mary .. ... ... ...................... ......... ..... ... ....... ... ........ ......... .... ......... ............ 2 Requirements of 20 AAC 25.005(c)(2) ....... ............................................................................................ 2 Requirements of 20 AAC 25. 050(b ).................................... ..... ............................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) .................................... ............................................................... 3 4. Dri II i ng Hazards Information .............. ............ ...... ...... ... .......................................... 3 Requirements of 20 AAC 25.005 (c)( 4) ............................... .... ................................... ............................ 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .. .......... ................... ................................................................... 3 6. Casi ng and Cementi ng Prog ram........ ........ .... ...... ...... ... .... .......... .... ... ............... ...... 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. Drill i ng FI u id Program .......... ....... ........... ..... ... ..... ....... ... .... .............. .... ........ ....... ..... 4 Requirements of 20 AAC 25.005(c)(B) ........................................................... ........................................ 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 1 o. Se ism i c An a I ys is...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) .................. ........... ................................................ ................... 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ............................................. ...................... ............................. 6 12. Evidence of Bond i ng .... .... .................. ..... ........... ....... .... ......... .... ........ ...... ......... ...... 6 Requirements of 20 AAC 25.005 (c)(12) ................ ....... ........................................ ..................... ............ 6 13. Proposed Dri Iii ng Program .. ....... .............. ........ .......... .... .... ... .... ..... .................. ...... 6 35-10 PERMIT IT. DOC Page 1 of 7 O J .~ ': ,,!~; ,1/1 Printed: 27-Nov-02 1, .à ¡ i ~ r·~ .. ) APr'·~"\l.tion for Permit to Drill, We1l3S-10 , Revision No.O " Saved: 27-Nov-02 Requirements of 20 AAC 25.005 (c)(13) ......... ...................... .......................... ....................................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ...................................................... .......................................... 6 15. Attachments. ................ ...... ....... ... ....... ... .......... ... ..... ... .......... ........ ..... ... ..... .... ..... ..... 7 Attachment 1 Directional Plan .... ..... ............ ............................................... .......... ................. ......... ....... 7 Attachment 2 Drilling Hazards............................................................................................. 6 Attachment 3 Well Schematic............................................ ............................. ................... ..6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name des¿qnated by the operator and a unique API number assigned by the commis.çion under 20 AAC 25.040(b). For a well with multiple w{~/1 brlmcheS¡, each branch must similady be Identified by a unique name and API number by adding a suffix to the name designated for tl7e well by the operator and to tl7e number assigned to the well by tl7e commis''iion. The well for which this application is submitted will be designated as 35-10. 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 fallowing item!J~ except far an item already 017 me with the commission and Identified in the application: (2) a plat IdentifyÙ7g the property and the propelty's owners and showing (A)the coordinates ot'the proposed location ot'the wé?11 at thi:; sutface/ at the top of each oþjective formation and at total depth referenced to governmental section line."" (8) the coordinates of t/7e proposed location of the well at the surface, referenced to the state plane coordinate ,!::y.':>tem for thl:~ state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the propos-ed depth of the well at the top of eaäJ objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,993,915 12501' FNL, 993' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,266 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "c" Sand) NGS Coordinates Northings: 5,998,160 1751' FSL, 1043' FWL, Sec 8, T12N, R8E, UM Eastings: 478,300 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7807' 5824' 5768' Location at Total Depth 11785' FSL, 1059' FWL, NGS Coordinates Northings: 5,998,194 Eastings: 478,317 Sec 8, T12N, R8E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 8026' 6040' 5984' and (D) other information required by 20 AAC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a PermIt to Dnll (Form 10-401) must (1) I¡¡clude a plat drawn to a sUItable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of tile proposed well,' Please see Attachment 1: Directional Plan ~ : IG.Nh- 38-10 PERMIT IT. DOC Page 2 of 7 Printed: 27-Nov-02 ) Apr" ""1tion for Permit to Drill, We1l3S-10 , Revision No.O ,I Saved: 27-Nov-02 and (2) for all well.'i witt/in 200 feet of the proposed wellbore (A) list the names of the operators of those wel10 to the extent that those? names are known or discoverable in public record.~ and show that eadl named operator has been furnished a copy of the application by certllìed ma/~' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An applkätion lor a Pel7l71t to Drill must be acr;vmpanied by each of the following Item5~ except for an Item already on tile with the commis:.,'ion and identified in the application: (3) a d/~Jglam and desCliption olthe blowout prevention equipment (BOPE) as required by 20 AAC 25.03~ 20 AAC 25.0J6~ or 20 AAC 25.037, as applicable;: Please reference BOP schematics on file for Nabors 7ES. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by eaä7 of the tollowing Item5~ except tor an Item already on file with the (;,(Jfrllnis...<;ion and identitied in the application: (4) intëJl1Tlation on dlilling hazarri!;.~ ineiuding (A) the m¿¡ximum downhole pressure that may be encou/1terecf; cnteda used to determine it and maxlÍTlum potentÙ11 :;,ì.llface pressure based 0/1 a methane gradient; A pressure bUild-up test performed on Palm lA (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 35-10 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5824' tvd: MPSP =(5824 ft)*(0.62 - 0.11 psi/ft) = 2970 psi / (8) data on potential gas zones"-' The well bore is not expected to penetrate any gas zones. and (C) data concerning potent/~JI cau::,-es of hole problems such as abnormally geo-pres::'ì.lred strataf lost circulation zones" and ZO/7e.r; that have a propensity for differential stiâli7g; 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 mllst be accompanied by each of the lollowing items, except for an item already 0/7 file wIth the commission and Identtfied 1i7 the application: (5) a description of the procedure for conducting fo/mation integrity test0 as required under 20 MC 25. OJO(f); A procedure is on file with the commission for performing LOT's. For 35-10 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) o = GINt.- 35-10 PERMIT IT DOC Page 3 of 7 Printed: 27-Nov-02 ') Apr'·"tion for Permit to Drill, Well 3S-1 0 , Revision No.O . Saved: 27-Nov-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by eaä7 of the following /!em5~ except for an ¡[em already on file with the commission and identified in the applic<'1tion: (6) a complete proposed casing and cementing program as required by 20 AAC 25.03~ and a description ofan)l f.,1otted liner;. pre- perforated liner;. or screen to be ¡¡7stallee¿' Casinq and Cementing Program Hole Top Btm CsgfTbg Size Weight Length MOfTVO MOfTVO 00 (in) (in) (/b/ft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated Lead~ 10.7 ppg 9-5/8 12-1/4 40 L-80 BTC 3358' 28'/28' 3386'/2605' / / AS Li ") Tail: ?9~·SX 12.0 ppg 'LiteER:ETE' . (Yield=2.40 cuft/sk) ~d TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 7998' 28'/28' 8026'/6040' (~X 15.8 ppg 'G' w/ add. Planned TOC= 7007' 3-1/2 9.3 L-80 EUE 8rd 7679' 28' / 28' 7707'/5725' SAB-3 packer set at Mod 7707' MD. An open-hole leak-off test will be performed on the 8 112" open hole interval after reaching the contingent casing point. If the leak-off test indicates insufficient formation integrity, 7" casing will be top-set above the Kuparuk C sand. In this case, 6 1/8" hole would be drilled to total depth and a 3 112" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be a<:r:ompanied by each of the fol/owing items, except for an it£:;m already on file with the commis."-¡(){7 and identitìed in the application: (l) a diagram and descnþtion of the diverter system as required by 20AAC 25.035~ unless this requirement is waived by tile (;ommis..c,ion 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)(B) An application for a Perini! to Drill must be accompanied by each of the followli7g Item.~ except for an Item already on file with the commission and identified in the application: (8) a drilling fluid program, ¡¡7e1uding a diagram and desaiption of tl7e drilling flUId system, as required by 20 AAC 25:033,: Drilling will be done using mud systems having the following properties: Ot~ff'~"~fA 11'1 G ¡ f~·i·~L 35-10 PERMIT IT. DOC Page 4 of 7 Printed: 27-Nov-02 ) Apr" '~tion for Permit to Drill, We1l3S-10 I Revision No.O . Saved: 27-Nov-02 Suface Hole mud properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value -" Density (ppg) 8.6 9.0* ./ 9.0* 9.4* /" Funnel Viscosity 120-130 120-130 120-130 120-130 (seconds) Yield Point 35-45 27 -40 25-35 20-30 (cP) Plastic Viscostiy 8-15 11-22 15-30 15-30 (lb1100 sf) 10 second Gel 10-30 10-25 10-25 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 20-40 15-35 Strength (lb1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 12-15 7-8 7-8 7-8 Solids (%) 6-9 6-12 6-12 6-12 * 9.8 if hydrates are encountered Production Hole mud properties initial C40 Top Morraine Top HRZ Kuparuk Density (ppg) 9.5 10.2 10.6 10.8 1 2.3 ",..-- Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (lb1100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (lb1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 15-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pel7TJ/t to Drill must be accompanied by each of the followli7g Items¡ except for an Item already on file with the commission and identified in the applic.ation: (9) for an exploratory or stratigrapl7ic test well, a tabulation setting out the depths of predicted abnom7a/ly geo-pressured strata as required by 20 MC 2S 03J(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 identifìed Iii the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a)/· N/A - Application is not for an exploratory or stratigraphic test well. OJ G,NÞ. 3S-10 PERMIT IT. DOC Page 5 of 7 Printed: 27-Nov-02 ) Apr" ".tion for Permit to Drill, Well 3S-1 0 } Revision No.O l Saved: 27-Nov-02 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit tv Drill must be accompanied by ead7 of the tollowing items~ except tor an item already on file with tfle c;vmmis;,70n and identified in the application: (11) for a well drílled from an off..i:;hore platform, mobile bottom-founded structure, Jack-up lig, or floating drílling ves5ie~ 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 Dnll must be accompanied by eaä7 of the following item~.., except for ('1n item already on file with the commís:c,ion and identitied in the application: (12) evidefJæ showing that the requirements of 20 AAC 25~025 {Bonding}l7ave 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 Dn/I must be accompanied by each of the tOllowing items, (~xcept for an item already on file wit!] the commi!;;:;ion and Identitled in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. /' 2. Install diverter system. / 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. No LWD logs are planned. ("" 4. Run and cement 9-5/8" 40#, L -80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the s~ce. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi./' 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill 8-1/2" hole to contingent top-set casing point according to directional plan. Run LWD logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. POOH and P/U neutron density tool, drill well to total depth according to directional plan, and run 7" 26# L -80 BTCM casing to surface and cement. /' Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. (Run 3-1/2" 9.3#, L-80 8rd EUE 8rd-Mod completion assembly wI SAB-3 permanent packer and PBR. Set packer, shear out of PBR, P/U tubing hanger ~d land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. 8. Set TWC and ND BOPE. Install and pressure test production tree. / 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L-80 BTCM casing will be run and cemented above the Kuparuk C sand. 6 1/8" hole will be drilled to total depth according to the directional plan and a 3 '12" 9.3# L-80 SLHT liner will be ran and cemented across the productive interval. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Perrmt to Dnll mustc be accompanied by each of the following Items, except for an item already on file with the commission and identified in tlìe application: (14) a general description of how the operator plans to dispose of drill1i7g 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 well.; O R ff" G·· '~., 'A· " N t Y j ¡ II V J'.., 3$-10 PERMIT IT. DOC Page 6 of 7 Printed: 27-Nov-02 ') Apr",tion for Permit to Drill, We1l3S-10 , Revision No.O i Saved: 27-Nov-02 Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 35 pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 35-10 for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. O~/G¡~JJI ' 11 i\'r')~ 3$-10 PERMIT IT. DOC Page 7 of 7 Printed: 27-Nov-02 r- Western North 5/glle ConocoPhillips Kup .l!lfc 3S Pad 35-10 '35-10 (wp04) Sperry-Sun Drilling Services ~ C:Þ =:t~J ~:7.__ oposal Report c:;-'~ ') """'" 27 November, 2002 iiIII...i;...:.~~ -.;~"1 ~~~. <7c., J~~ Your Ref: Intersect Original 'Fallback' Target @ 100 inc. Surface Coordinates: 5993914.52 N, 476266.35 E (70023' 40.2172" N, 150011' 35.1779" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 56. 10ft above Mean Sea Level - ~P~~~~}l-=~~ tJ.fjIb;L;.íN::fI:.:."i§'.!!:2:(ç::II~ Á mtì!í>urtm Cüfl~Y Proposal Ref: pro9997 DrillQuest 3.03.02.002 Page 2 of7 27 November, 2002 - 6:06 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-10 Plan - 35-10 (wp04) Your Ref: Intersect Original 'Fallback' Target @ 10° inc. ConocoPhillips Western North 510pe Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section CÔmment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.10 0.00 O.OON 0.00 E 5993914.52 N /( 4762fm.3Sie 0.00 SHL (2501' FNL & 993' FEL, SEC. 18- T12N - R8E) 100.00 0.000 0.000 43.90 100.00 0.00 N 0.00 E 5993914.52 NF, 47~BJâ:35¡¡1? "0.000 0.00 200.00 0.000 0.000 143.90 200.00 0.00 N 0.00 E 5993914.52 N \v\A7626B':35 E 0.000 0.00 Begin Dir @ 2.00/100ft (in 12-1/4" Hole): 200.00ft MD, 200.00ft TVD 300.00 2.000 20.682 243.88 299.98 1.63 N 0.62 E 5993916.15 N 4\f:í??66.97 E 2.000 1.74 400.00 4.000 20.682 343.74 399.84 6.53 N 2.46 E 5993921.04 N 476268.84 E 2.000 6.95 "-' 500.00 6.000 20.682 443.35 499.45 14.68 5993929.18 N 476271 .94 E 2.000 15.64 600.00 8.000 20.682 542.60 598.70 26.08 5993940.57 N 476276.28 E 2.000 27.79 700.00 10.000 20.682 641 .37 697.47 ,A.0.72 N 5993955.19 N 476281.85 E 2.000 43.37 Increase in Dir Rate @ 4.000/100ft : 700.00ft MD, 697.47ft TVD 800.00 13.985 22.344 739.16 795.26 23.03 E 5993974.47 N 476289.58 E 4.000 64.10 900.00 17.977 23.279 835.28 891 .38 33.73 E 5993999.80 N 476300.35 E 4.000 91.60 <:::) v 1000.00 21.972 23.883 929.24 985.34 N 47.41 E 5994031 .05 N 476314.13 E 4.000 125.74 :J:J 1100.00 25.968 24.309 1020.60 1076.70 153.76 N 64.00 E 5994068.07 N 476330.84 E 4.000 166.34 1200.00 29.966 24.627 1108.91 j165;01 196.43 N 83.43 E 5994110.68 N 476350.40 E 4.000 213.23 ---- 1300.00 33.963 24.877 1193:73 12t19183 244.49 N 105.60 E 5994158.67 N 476372.72 E 4.000 266.15 Ç) 1400.00 37.962 25.080 1274:65 ···133Cf75 297.71 N 130.40 E 5994211.81 N 476397.69 E 4.000 324.86 --- <= 1500.00 41 .960 25250 1351 .28 1407.38 355.83 N 157.71 E 5994269.84 N 476425.18 E 4.000 389.07 1600.00 45.959 25.395 1423.25 1479.35 418.56 N 187.39 E 5994332.48 N 476455.07 E 4.000 458.48 ~ 1699.68 49.945 25,521 1490.00 1546.10 485.38 N 219.21 E 5994399.20 N 476487.10 E 4.000 532.48 B. Permafrost r-- 1700.00 49.958 25.522 1490.21 1546.31 485.60 N 219.31 E 5994399.42 N 476487.20 E 4.000 532.73 1728.09 51.081 25.555 1508.07 1564.17 505.16 N 228.66 E 5994418.95 N 476496.61 E 4.000 554.41 End Dir, Start Sail @ 51.08° : 1728.09ft MD, 1564.16ft TVD 1800.00 51.081 25.555 1553.24 1609.34 555.64 N 252.79 E 5994469.35 N 476520.90 E 0.000 610.36 '~' 1900.00 51.081 25.555 1616.06 1672.16 625.83 N 286.35 E 5994539.44 N 476554.69 E 0.000 688.16 2000.00 51.081 25.555 1678.88 1734.98 696.02 N 319.92 E 5994609.52 N 476588.47 E 0.000 765.96 2100.00 51.081 25.555 1741.71 1797.81 766.21 N 353.48 E 5994679.61 N 476622.26 E 0.000 843.77 2200.00 51.081 25.555 1804.53 1860.63 836.41 N 387.04 E 5994749.69 N 476656.04 E 0.000 921.57 2300.00 51.081 25.555 1867.35 1923.45 906.60 N 420.60 E 5994819.78 N 476689.83 E 0.000 999.37 2400.00 51.081 25.555 1930.17 1986.27 976.79 N 454.16 E 5994889.86 N 476723.61 E 0.000 1077.18 2439.52 51.081 25.555 1955.00 2011.10 1 004.53 N 467.43 E 5994917.56 N 476736.97 E 0.000 1107.92 T. West Sak 2500.00 51.081 25.555 1992.99 2049.09 1046.98 N 487.73 E 5994959.95 N 476757.40 E 0.000 1154.98 2600.00 51.081 25.555 2055.82 2111 .92 1117.18N 521.29 E 5995030.03 N 476791.18 E 0.000 1232.78 DrillQuest 3.03.02.002 Page 3 of7 27 November, 2002 - 6:06 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-10 Plan - 35-10 (wp04) Your Ref: Intersect Original 'Fallback' Target @ 10° inc. ConocoPhillips Western North 510pe Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section COmment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/1 OOft) 2700.00 51.081 25.555 2118.64 2174.74 1187.37 N 554.85 E 5995100.12 " 0.000 1310.59 2800.00 51.081 25.555 2181.46 2237.56 1257.56 N 588.41 E 5995170.21 \~'O.OOO 1388.39 2900.00 51.081 25.555 2244.28 2300.38 1327.75 N 621 .98 E 5995240.29 \¡¡;] 0.000 1466.19 3000.00 51.081 25.555 2307.10 2363.20 1397.95 N 655.54 E 5995310.38 N 0.000 1544.00 3100.00 51.081 25.555 2369.93 2426.03 1468.14 N 689.10 E s,~:ç~~i~6 N 0.000 1621.80 3147.87 51.081 25.555 2400.00 2456.10 1501.74N 705.17 E 5995414:ØiltN E 0.000 1659.04 B. West Sak 3200.00 51.081 25.555 2432.75 2488.85 1538.33 N 722.66 E 5995450.55 N 476993.89 E 0.000 1699.60 "-" 3300.00 51.081 25.555 2495.57 2551.67 1608.52 N 756.22 E 5995520.63 N 477027.68 E 0.000 1777.41 3385.50 51.081 25.555 2549.28 2605.38 1668.54 N 784.92 E 5995580.56 N 477056.56 E 0.000 1843.93 9-5/8" Csg Pt ... Drill out 8-1/2" Hole 3385.50ft MD, 2605.38ft TVD 9 5/8" Casing a 3400.00 51.081 25.555 2558.39 2614.49 789.79 E 5995590.72 N 477061.46 E 0.000 1855.21 ......{.- J 3485.33 51.081 25.555 2612.00 2668.10 818.43 E 5995650.53 N 477090.29 E 0.000 1921.60 C-80 (K-10) ---.~ 3500.00 51.081 25.555 2621.21 2677.31 823.35 E 5995660.80 N 477095.25 E 0.000 1933.01 ~ 3600.00 51.081 25.555 2684.04 2740.14 1819.10N 856.91 E 5995730.89 N 477129.03 E 0.000 2010.82 3700.00 51.081 25.555 2746.86 2802,96 1889.29 N 890.47 E 5995800.98 N 477162.82 E 0.000 2088.62 -=- 3800.00 51.081 25.555 2809.68 _..._ 286517'8 1959.49 N 924.03 E 5995871.06 N 477196.60 E 0.000 2166.42 -~~ ~ 3900.00 51.081 25.555 2872.50 ._ 2928.60 2029.68 N 957.60 E 5995941 .15 N 477230.39 E 0.000 2244.23 ):;::.. 4000.00 51.081 25.555 '2935.32 2991 .42 2099.87 N 991.16 E 5996011.23 N 477264.17 E 0.000 2322.03 r-- 4100.00 51.081 25.555 2998.15 3054.25 2170.06 N 1024.72 E 5996081.32 N 477297.96 E 0.000 2399.83 4200.00 51.081 25.555 3060.97 3117.07 2240.26 N 1058.28 E 5996151.40 N 477331.74 E 0.000 2477.64 4300.00 51.081 25;555 3123.79 3179.89 2310.45 N 1091.85 E 5996221 .49 N 477365.53 E 0.000 2555.44 4400.00 51.081 25.555 3186.61 3242.71 2380.64 N 1125.41 E 5996291.57 N 477399.31 E 0.000 2633.24 4500.00 51.081 25.555 3249.43 3305.53 2450.83 N 1158.97 E 5996361.66 N 477433.10 E 0.000 2711 .05 4600.00 51.081 25.555 3312.26 3368.36 2521.02 N 1192.53 E 5996431.75 N 477466.88 E 0.000 2788.85 ---" 4700.00 51.081 25.555 3375.08 3431.18 2591.22 N 1226.09 E 5996501.83 N 477500.67 E 0.000 2866.65 4800.00 51.081 25.555 3437.90 3494.00 2661.41 N 1259.66 E 5996571.92 N 477534.45 E 0.000 2944.46 4900.00 51.081 25.555 3500.72 3556.82 2731.60 N 1293.22 E 5996642.00 N 477568.23 E 0.000 3022.26 5000.00 51.081 25.555 3563.54 3619.64 2801.79 N 1326.78 E 5996712.09 N 477602.02 E 0.000 3100.06 5100.00 51.081 25.555 3626.37 3682.47 2871.99 N 1360.34 E 5996782.17 N 477635.80 E 0.000 3177.87 5200.00 51.081 25.555 3689.19 3745.29 2942.18 N 1393.91 E 5996852.26 N 477669.59 E 0.000 3255.67 5300.00 51.081 25.555 3752.01 3808.11 3012.37 N 1427.47 E 5996922.34 N 477703.37 E 0.000 3333.47 DrillQuest 3.03.02.002 Page 40f7 27 November, 2002 - 6:06 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-10 Plan - 35-10 (wp04) Your Ref: Intersect Original 'Fallback' Target @ 100 inc. ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section COmment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 5400.00 51.081 25.555 3814.83 3870.93 3082.56 N 1461.03 E 5996992.43 0.000 3411 .28 5500.00 51.081 25.555 3877 .65 3933.75 3152.76 N 1494.59 E 5997062.52 i,;.p.ooO 3489.08 5600.00 51.081 25.555 3940.47 3996.57 3222.95 N 1528.15 E 5997132.60 \::"'0.000 3566.88 5700.00 51.081 25.555 4003.30 4059.40 3293.14 N 1561.72 E 5997202.69 N 0.000 3644.69 5752.94 51.081 25.555 4036.56 4092.66 3330.30 N 1579.48 E 59~Æ~~~~79 N 0.000 3685.88 Begin Drop @ 2.00/1 OOft : 5752.94f MD, 4092.65ft TVD 5800.00 50.140 25.555 4066.42 4122.52 3363.11 N 1595.17 E 5997272.55 N 477872.19 E 2.000 3722.24 ~-' 5828.82 49.564 25.555 4085.00 4141.10 3382.99 N 1604.68 E 5997292.40 N 477881.76 E 2.000 3744.27 C-40 (K-3) 5900.00 48.140 25.555 4131.84 4187.94 3431.34 N 1627.80,E'F'V 5997340.68 N 477905.03 E 2.000 3797.87 6000.00 46.140 25.555 4199.85 4255.95 3497.47 N 1659.41;ï: 5997406.70 N 477936.86 E 2.000 3871.17 6100.00 44.140 25.555 4270.39 4326.49 ~~~.;;~2 N 1689.99 E 5997470.55 N 477967.64 E 2.000 3942.05 6200.00 42.140 25.555 4343.35 4399.45 :'I;ª623;;~i·N 1719.48 E 5997532.14 N 477997.33 E 2.000 4010.42 C 6300.00 40.140 25.555 4418.66 4474.76 ¡&,~S,~¡N 1747.86 E 5997591.41 N 478025.90 E 2.000 4076.21 6400.00 38.140 25.555 4496.22 4552.32 .... 37'~Ji40 N 1775.09 E 5997648.26 N 478053.30 E 2.000 4139.33 :J::J 6500.00 36.140 25.555 4575.93 4632.03 ¡ 3793.86 N 1801.13 E 5997702.65 N 478079.52 E 2.000 4199.70 ---.... 6600.00 34.140 25.555 4657.70 4713.80 3845.79 N 1825.96 E 5997754.49 N 478104.51 E 2.000 4257.26 ~'" PJ 6700.00 32.140 25.555 4741.43 4797.53 3895.11 N 1849.54 E 5997803.73 N 478128.25 E 2.000 4311.92 --- 6800.00 30.140 25.555 4827.02 4883.12 3941.76 N 1871.85 E 5997850.31 N 478150.71 E 2.000 4363.63 ~~ .c:::, 6900.00 28.140 25.555 4914.35 4970.45 3985.69 N 1892.86 E 5997894.18 N 478171 .85 E 2.000 4412.32 :t:::a 7000.00 26.140 25.555 5003.34 5059.44 4026.84 N 1912.53 E 5997935.27 N 478191.66 E 2.000 4457.94 .--- 7100.00 24.140 25.556 5093.86 5149.96 4065.16 N 1930.86 E 5997973.53 N 478210.11 E 2.000 4500.42 7150.36 23.133 25.556 5140.00 5196.10 4083.38 N 1939.57 E 5997991.72 N 478218.87 E 2.000 4520.61 Top Morraine 7200.00 22.140 25.556 5185.81 5241 .91 4100.61 N 1947.81 E 5998008.93 N 478227.17 E 2.000 4539.71 7300.00 20.140 25.556 5279.08 5335.18 4133.15 N 1963.37 E 5998041.41 N 478242.83 E 2.000 4575.78 7400.00 18.140 25.556 5373.54 5429.64 4162.73 N 1977.51 E 5998070.95 N 478257.07 E 2.000 4608.56 "- 7438.28 17.374 25.556 5410.00 5466.10 4173.26 N 1982.55 E 5998081 .46 N 478262.14 E 2.000 4620.24 Top HRZ 7500.00 16.140 25.556 5469.10 5525.20 4189.31 N 1990.22 E 5998097.49 N 478269.87 E 2.000 4638.03 7600.00 14.140 25.557 5565.62 5621.72 4212.87 N 2001 .49 E 5998121.02 N 478281 .21 E 2.000 4664.15 7623.05 13.679 25.557 5588.00 5644.10 4217.87 N 2003.88 E 5998126.01 N 478283.61 E 2.000 4669.69 Base H RZ 7700.00 12.140 25.557 5663.00 5719.10 4233.38 N 2011.30 E 5998141.50 N 478291.08 E 2.000 4686.88 7735.75 11 .425 25.558 5698.00 5754.10 4239.97 N 2014.45 E 5998148.07 N 478294.25 E 2.000 4694.18 K-1 7800.00 10.140 25.558 5761.11 5817.21 4250.81 N 2019.63 E 5998158.90 N 478299.47 E 2.000 4706.20 DrillQuest 3.03.02.002 -' Total Depth: 8026.30ft MD, 6040.07ft TVD 7" Casing ~' TARGET: Start Sail @ 10.0° : 7807.00ft MD, 5824.10ftTVD (175' FSL & 1043' FWL, See 8- T12N-R8 Kuparuk Target - 3S-1 OF (Gee), 150.00 Radius., Current Target Miluveach C'omment ConocoPhillips 4745.50 4710.77 4723.57 4740.94 Page 50f7 27 November, 2002 - 6:06 SHL (2501' FNL & 993' FEL, SEC. 18- T12N - R8E) Begin Dir @ 2.00/100ft (in 12-1/4" Hole): 200.00ft MD, 200.00ft TVD Increase in Dir Rate @ 4.000/100ft : 700.00ft MD, 697.47ft TVD End Dir, Start Sail @ 51.08° : 1728.09ft MD, 1564.16ft TVD 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 3385.50ft MD, 2605.38ft TVD 0.00 E 0.00 E 15.37 E 228.66 E 784.92 E 0.00 200.00 697.47 1564.16 2605.38 0.00 N 0.00 N 40.72 N 505.16 N 1668.54 N 0.00 200.00 700.00 1728.09 3385.50 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Comments Based upon Minimum Curvature type calculations, at a Measured Depth of 8026.30ft., The Bottom Hole Displacement is 4745.50ft., in the Direction of 25.414° (True). The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2501' FNL, 993' FEL and calculated along an Azimuth of 25.410° (True). All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to Trùe North. Vertical depths are relative to RKB = 56.1' MSL. Northings and Eastings are relative to 2501' FNL, 993' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. 7826.29 10.000 25.558 5787.00 5843.10 4254.94 N 2021.61 E 5998163!Ô2 N 4~8301.45 E 0.000 7900.00 10.000 25.558 5859.59 5915.69 4266.48 N 2027.13 E 5998174.55;N 478307.01 E 0.000 8000.00 10.000 25.558 5958.07 6014.17 4282.15 N 2034.62 E 5998190.19 N 478314.55 E 0.000 8026.30 10.000 25.558 5983.97 6040.07 4286.27 N 2036.59 E 5998194.30 N 478316.54 E 0.000 Western North 510pe Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (oI100ft) 7807.00 10.000 25.558 5768.00 5824.10 4251.92 N 2020.16 E 5998160.00 N 478300.00 E 2.000 4707.42 Sperry-Sun Drilling Services Proposal Report for Kuparuk 35 Pad - 35-10 Plan - 35-10 (wp04) Your Ref: Intersect Original 'Fallback' Target @ 10° inc. ~,,~ --~ >C~ ~ r-- C) =0 --- ç""J Dip Up-Dip Formation Name Angle Dirn. 0.000 359.818 B. Permafrost 0.000 359.818 T. West Sak 0.000 359.818 B. West Sak 0.000 359.818 C-80 (K-10) 0.000 359.818 C-40 (K-3) 1939.57 E 0.000 359.818 Top Morraine 1982.55 E 0.000 359.818 Top HRZ 2003.88 E 0.000 359.818 Base H RZ 2014.45 E 0.000 359.818 K-1 2020.16 E 0.000 359.818 Kuparuk 2021.61 E 0.000 359.818 Miluveach - DrillQuest 3.03.02.002 Page 6 of 7 -' D TVD (1751' FSL & 1043' FWL, See 8-T12N-R8E) Begin Drop @ 2.00/100ft : 575 TARGET: Start Sail @ 10 Total Depth: 804! ConocoPhillips 4254.94 N 4083.38 N 4173.26 N 4217.87 N 4239.97 N 4251.92 N Northings (ft) 1579.48 E 2020.16 E 2036.59 E 3330.30 N 4251.92 N 4286.27 N 27 November, 2002 - 6:06 Formation Tops Measured Vertical Sub-Sea <::) Depth Depth Depth (ft) (ft) (ft) ::t; 1699.68 1546.10 1490.00 ~~. ç':) 2439.52 2011.10 1 955.00 3147.87 2456.10 2400.00 ~".., 3485.33 2668.10 2612.00 ::'::,0-':-,» 5828.82 4141.10 4085.00 .~-~.""-'.......~ :L~ 7150.36 5196.10 5140.00 r-- 7438.28 5466.10 5410.00 7623.05 5644.10 5588.00 7735.75 5754.10 5698.00 7807.00 5824.10 5768.00 7826.29 5843.10 5787.00 4092.65 5824.10 6040.07 5752.94 7807.00 8026.30 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-10 Plan - 3S-10 (wp04) Your Ref: Intersect Original 'Fallback' Target @ 10° inc. Comments (Continued) Western North Slope a ::.1.:;] ~-~..;.~ C~1J ~:.r<'" 1t.i::J....~"";","'-'='t ~~J3 .....- ---.- _I-:~ r-- Sperry-Sun Drilling Services Proposal Report for Kuparuk 3S Pad - 3S-10 Plan - 3S-10 (wp04) Your Ref: Intersect Original 'Fallback' Target @ 10° inc. Western North Slope CasinQ details Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Casing Detail <Surface> <Surface> <Surface> <Surface> 3385.50 8026.30 2605.38 6040.07 9 5/8" Casing 7" Casing TarQets associated with this wel/øath Target Name 3S-1 OF (Gee) Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape 5824.10 4251.92 N 2020.16 E 5768.00 5998160.00 N 478300.00 E 700 24' 22.0355" N 1500 10' 35.9722" W Circle Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Target Radius: 27 November, 2002 - 6:06 150.00ft Page 70f7 ConocoPhillips --r Target Type Current Target ~' DrillQuest 3.03.02.002 MD Delta ..,...~m . MD(ft) · 0.00 200.00 200.00 700.00 500.00 1728~09 1028.09 5752i94· 4024.85·. ..' . .;:' '. .. 61. 7807iOO 2054.06 IT! 8026.301 <219.30: t...,__._..,_,~_.._. .._...__. ._. ..__.,...__,__".._._......__.,.c., [,.....1 ¡ 2. i 3 4 5 27 November, 2002 - 5:25 Sperr,J-Sun Drilling SerJices Proposal Data - 35-10 Plan - 35-10 (wp04) h'clln~. . Azimuth · TVD. .. Northings Eastings ·1.Oogleg Ai Build · ·.j\;Turn. I. To()lface .<~) ...:...<?......... .......,......~~~.......... ..............,.~~~........ .,... ......,...,.....,.~!n...."........, ......~.~~?·~?:!1).... ...5~~~.?.?!:~~..... .:..:~y1.0()ft). .. .........,.'....~~.~...:..:...:...., ........09.'..09..0909.1:. .........9..9.99.............9.: 00 0 .00 ..........9.~g9 ..,. 0.000 2.00.00· 0.00 ... ·P.OO 0.000' ' '·0;000 0.000 .' . '·0.000 -.. .. . ·1 ......-.-......--......-.... 10.000 I 20.682 697.4740.72 N15;3TE 2.000 2.000 0.000· 20.682 51:081 ·25.555 1564.17 .50S.t6N 228.66E 4.000 3i996 OA74 < · 5.767 51.081 .. 25.555 4092.663330;30 N 1579.48 E OiOOO .0.000 0.0000.000 10.000 25.558 5824.10 4251.92 N 2020.16 E 2.000 ~2.000 0.000 179.999 ,.~.8:9.g9._'.._,..cg~.:~~.~.L.~~~2:.071_~_?..~~~gL.~J..._~,9.~~:~~..51___...g_:9..QQj__...._~_~:00~.1 0~~2~1~..~~~9.Q OR" r /~, f'~ , ~ l .....J !).. . '... .' N . r , 0." I .:. ~ .' ,I . I L;1 a i \i:1 l~ , 'J" DrillQuest Sperry-Sun Drilling SerJices Proposal Data - 35-10 Plan - 35-10 (wp04) t .2 t I: 3 4. 5 6T 7 MD Delta· Inëlin~ ·.. Azimuth TVD Northings Eastings Dogleg A. Build A; Turn Toolface (ft) MD (ft) .... .. m 1.· (0)· (ft)· .~!~~....................... .....................~fo~~........................... (0/100ft) (9/100ft) (0/100ft) (0) 0.00 ·...........Ó:·6Ó6f..·...........ëirujo,.......· -56.10 5993914.52 N 476266.35 E ..................................... ...................................... .................,....., 200.00 ... 200.00 ·..··0:6601'· ... o.000'·....·143.9Ó·:59¡:M!H~Ü52·NI·T476¿~å·.3áÊ....... 0.000' ..' 0.000· ........··Ó:06Ót..ŒOOO 700.00 500.00 10.0001 20.864641.37599395$.19 Ni47628t.85 E' ....·....·...·..'2·:006 ·2.0000;ooòI20~864 1728.09 1028.p9 51 :08125.7361 $08;07 5994418~95 N ~76496.61 E 4.000 3.996 0;474 5: 767 ·5752.94 4024.85 · 51.08125.736· 4036.56 ·5997239~79N ...47?'856.40 E 0.000 0.000··· o.()ob . ··0;000 7807.0Û2()S4.0e 10.000 25.740 5768.00 5998160.00 N 478300.00 E 2.000 .;2.000·· 0.000 179;999 ~~_?~~_3._~J.~::~l?2~:~~gL....lg·!?9gL..._g§.:7~g¡.~_~~~_~?..:.~IL....~.~~...~.!~~..,~91J..!_..:.1!.~~~~~~.~_~..:§.L__0 .000 ['. 0:9221...c..c-~_0.OO!?L.~::...ë..R9.Q..<? 27 November, 2002 - 5:25 - () Ci ,~ ,(} ,;'~,} ,il L V I , ¡ \;i ~ 6 :} lØ'1 '" DrillQuest cD L() II a~ ::tJ ¡ --.-- ~ ~~ ---- '€ Q) ~> ::t:::.. r-- 5PE!r'r'Y-!5Ufl Q^~ J~_h.Lt.lJ~.._..^?^ª~_\tJ~,ê.ê A. 'hln.JII(J'; t;(';u#I/Iþ' Eastings Scale: 1 inch = 1000ff ./ Conoc;-Phillips ConocoPhillips Alaska, Inc. North Slope, Alaska Palm (3S Pad) o I I I 1 I I ¡ I ¡ ! --I-- I - - - - - - - - - - - - -- - - - --žOOO"._' - -1-- 9-518" Csg Pt n. Drill out 8-1/2" Hole: I <f> 3385.501t MD, 2605.38ft TVD ,;Jf> -- ------- ------ --- -1-- - ---- --- --.---- ----I-- I I I I'%~ 1000 I Total Depth: 8026.3011 MD, 6040.07f! TVD 2000 I 3000 I 7" Csg Pt. 8026.30' MD 6040.07 TVD ,H . [(:S(;~· Sf.:"G. 1Ö· n~:N . H2E} f~JL. 5. s~.n· FEL. 0- / 4000 - - 4000 Begin Dir @ 2.0°/10011 (in 12-1/4" Hole): _ 200.00ft MD, 200.00ft TVD 3SA](¿f (GU)...p~}iJ:) Circle. Ni:iUUt: J StJ.iUJþ 5K}·i.ft! Ti}), ·f25f.92 N: ]1;2tJ.16 E ::::J en ~ ~tP'<f> Increase in Dir Rate @ 4.00'/100lt: ! _____ 700.00lt MD, 697.47ft TVD ¡ I I ,;,·""",t~;= 2000~ :-~--- f ;·,·f 'r l·tI..·'· """"'!T ,=m - - - - - ·~t;-·~______1 , ...,,~.,., .,(.(,^_.. 9-5/8" Csg Pt. 3385.50' MD I 2605.38' TVD 35-1 0 <wp04~'! Begin Drop @ 2.0'/1001I : 5752.94f! MD, 4092.65ft TVD 1000 - RKB Elevation: North Reference: Units : 3000 - - 3000 - - - - -- - -- ---""""" -- ------ -- ""~- rJ) C> c :.c t:: o Z~·' - 2000 9-518" Csg Pt... Dril 011 8-112' Hole : 3385.5011 MD, 2605.38ft TVD õ o ~ II .s:::. o .S; (¡j rJ (f) 3000 - 1000 - - 1000 õ ê II .r::; o c: ! -9~ I~ 4000- j' Ok ----. - _.- --.- - ~~--- - - - ---- "~I '"'' ,<> ~ ! ~ I ~ ! :!:~,~':,';]: ~ =--~ ~. -- Current Well Properties 3S-10 Plan End Dir, Slart Sail @ 51.080: 1728.000 MD. 1564.16ft TVD 0-- - -;::s:in-;;;;: ; 4~;;-7~; 6~V~ - - ~ 0 egin Dir @ 2.0'/1001I (in 12-114' Hole): 200.OOIt MD. 200.001I TVD Begin Drop @ 2.00/100ff : 5752.94ft MD. 4092.65ft TVD SHL {25Gi: FN . z( 903' FEL. SEC. 18· T12N - R8E) I 3000 .~ I 1000 I 2000 o 5000 - _ __ _n n_....m __._. _...h__......... ..._ .........._........ _m Reference is True North Well: :" I!~:l~":~~~j~,;',~i.; -: ~i':".,::~;,,- .~!:¡""<Í¡;',~¡!1 ~ -- ~ - . ~ ~ - -~. /' 6000 - I .is-IN' // 1 \. Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: ;¡; ~ (f) 5993914.52 N. 476266.35 E 70.92 N. 188.88 W 70' 23' 40.2172" N. 150' 11' 35.1779' W 2501' FNL & 993' FEL, SEC. 18- T12N - R8E 56.1 Oft above Mean Sea Level True North Feet (US) CÙ';{:Ù~i Total Depth: 8026.301t MD. 6040.07ft TVD I I 5000 6000 i};2Ihj TiI). ·1251.9"2 ;V, :"t!J2tJ.lf;. E o I 1000 I 4000 I 2000 I 3000 Scale: 1inch = 100011 ;" t ~ ~ -~ -~-:-; ~ '..[,~ DrillQuest 3.03.02.002 ConocoPhillips Alaska, Inc. 35-10 (wp04) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 0.00 0.00 0.00 -56.10 0.00 0.00 N 0.00 E 5993914.52 N 476266.35 E 0.00 0.00 SHL --' 200.00 0.00 0.00 143.90 200.00 0.00 N 0.00 E 5993914.52 N 476266.35 E 0.00 0.00 Begin Dir in 12-1/4" Hole 700.00 10.00 20.68 641.37 697.47 40.72 N 1 5.37 E 5993955.19 N 476281.85 E 2.00 43.52 Increase in Dír Rate @ 4.000/100tt 1699.68 49.95 25.52 1490.00 1546.10 485.38 N 219.21 E 5994399.20 N 476487.10 E 4.00 531.52 B. Permafrost 1728.09 51.08 25.56 1508.07 1564.17 505.16 N 228.66 E 5994418.95 N 476496.61 E 4.00 553.36 End Dir; Start Sail 2439.52 51.08 25.56 1955.00 2011.10 1004.53 N 467.43 E 5994917.56 N 476736.97 E 0.00 1104.88 T. West Sak 3147.87 51.08 25.56 2400.00 2456.10 1501.74 N 705.17 E 5995414.01 N 476976.28 E 0.00 1654.01 ---- B. West Sak 3385.50 51.08 25.56 2549.28 2605.38 1668.54 N 784.92 E 5995580.56 N 477056.56 E 0.00 1838.23 9-5/8" Csg pt ... Drill out 8-1/2" Hole 3485.33 51.08 25.56 2612.00 2668.10 1738.61 N 818.43 E 5995650.53 N 477090.29 E 0.00 1915.62 C-80 (K-10) a 5752.94 51.08 25.56 4036.56 4092.66 3330.30 N 1579.48 E 5997239.79 N 477856.40 E 0.00 3673.53 Begin Drop @ 2.00/100tt ::t:::J 5828.82 49.56 25.56 4085.00 4141.10 3382.99 N 1604.68 E 5997292.40 N 477881.76 E 2.00 3731.71 C-40 (K-3) ---<:00 7150.36 23.13 25.56 5140.00 5196.10 4083.38 N 1939.57 E 5997991.72 N 478218.87 E 2.00 4505.25 Top Morraíne ~ 7438.28 17.37 25.56 5410.00 5466.10 4173.26 N 1982.55 E 5998081.46 N 478262.14 E 2.00 4604.51 Top HRZ ____ 7623.05 13.68 25.56 5588.00 5644.10 4217.87 N 2003.88 E 5998126.01 N 478283.61 E 2.00 4653.79 Base H RZ -.~~ 7735.75 11 .43 25.56 5698.00 5754.10 4239.97 N 2014.45 E 5998148.07 N 478294.25 E 2.00 4678.19 K-1 :;;::: 7807.00 10.00 2 E) .5 6 57ßH.OO £)824.10 425'1.92 N 2020.16 E 5998160.00 N 478300.00 E 2.00 4691 .38 TARGET: Start Sail @ 10.0° r--- 7826.29 10.00 25.56 5787.00 5843.10 4254.94 N 2021.61 E 5998163.02 N 478301.46 E 0.00 4694.72 Miluveach 8026.30 10.00 25.56 5983.97 6040.07 4286.27 N 2036.59 E 5998194.30 N 478316.54 E 0.00 4729.33 Total Depth r Company: Field: Reference Site: Reference Well: Refel'ence Well path: Phillips Alaska Inc. Kuparuk HiverUnit Kuparuk3S Pad Plan:3S-10 Plan:·3S-10 ') ) Sperry-Sun Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.000 ft Depth Range: 36.100 to 12674.173 ft Maximum Radius: 1445.518 ft Survey Program for Definitive Well path Date: 5/14/2002 Validated: No Planned From To Survey It ft 28.100 500.000 500.000 8026.300 Planned: 3S-10 (wp04) V11 Planned: 3S-10 (wp04) V11 Casing Points MD TVD Diameter Hole Size It ft in in 3385.200 2605.025 9.625 12.250 8026.000 6039.302 7.000 8.500 Name 95/8" 7" Summary <-----------------m--Offset Wellpath ____m_________m___> Site Well Well path Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Kuparuk 3S Pad Plan: 3S-01 Plan: 3S-02 Plan: 3S-02 Plan: 3S-03 Plan: 3S-06 Plan: 3S-06 Plan: 3S-07 Plan: 3S-08 Plan: 3S-08 Plan: 3S-09 Plan: 3S-14 Plan: 3S-15 Plan: 3S-16 Plan: 3S-17 Plan: 3S-17 Plan: 3S-18 Plan: 3S-19 Plan: 3S-19 Plan: 3S-20 Plan: 3S-21 Plan: 3S-21 Plan: 3S-22 Plan 3S-01 V2 Plan: 3S Plan: 3S-02 V2 Plan: 3 Plan: 3S-02F V2 Plan: Plan: 3S-03 V2 Plan: 3 Plan: 3S-06 V2 Plan: 3 Plan: 3S-06F V2 Plan: 3S-07 (Rig Surveys) VO Plan: 3S-08 V2 Plan: 3 Plan: 3S-08F V2 Plan: Plan: 3S-09 V1 Plan: 3 Plan: 3S-14 V1 Plan: 3 Plan: 3S-15 V1 Plan: 3 Plan: 3S-16 V1 Plan: 3 Plan: 3S-17 VO Plan: 3 Plan: 3S-17F V1 Plan: 3S-18 (Rig Surveys) VO Plan 3S-19F V2 Plan: 3 Plan: 3S-19 V1 Plan: 3 Plan: 3S-20 V1 Plan: 3 Plan: 3S-21 V1 Plan: 3 Plan: 3S-21 F V2 Plan: Plan: 3S-22 V2 Plan: 3 Date: 11/29/2002 Time: 11:50:06 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD)Reference: Well: Plan: 3S-10,True North RKB= 55.8' MSL 55.8 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Version: 2 Toolcode Tool Name CB-GYRO-SS MWD Camera based gyro single shot MW D - Standard Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning Y' ft ft ft ft ft 355.301 350.000 181.698 7.088 174.617 Pass: Major Risk 354.597 350.000 161.102 6.885 154.223 Pass: Major Risk 354.597 350.000 161.102 6.885 154.223 Pass: Major Risk 745.576 750.000 102.420 12.955 89.474 Pass: Major Risk 301.559 300.000 80.866 6.181 74.685 Pass: Major Risk 301.559 300.000 80.866 6.181 74.685 Pass: Major Risk 301.066 300.000 60.404 5.441 54.970 Pass: Major Risk 351.183 350.000 41 .579 7.370 34.216 Pass: Major Risk 351.183 350.000 41.579 7.370 34.216 Pass: Major Risk 450.922 450.000 23.021 9.630 13.404 Pass: Major Risk 298.463 300.000 80.819 6.460 74.359 Pass: Major Risk 249.044 250.000 100.337 5.375 94.962 Pass: Major Risk 297.680 300.000 120.974 6.451 114.524 Pass: Major Risk 248.670 250.000 140.483 5.175 135.308 Pass: Major Risk 248.670 250.000 140.483 5.175 135.308 Pass: Major Risk 149.992 150.000 161.160 2.838 158.345 Pass: Major Risk 248.301 250.000 180.605 5.131 175.475 Pass: Major Risk 248.301 250.000 180.605 5.131 175.475 Pass: Major Risk 248.115 250.000 200.363 4.984 195.379 Pass: Major Risk 247.944 250.000 220.105 5.221 214.884 Pass: Major Risk 247.944 250.000 220.105 5.221 214.884 Pass: Major Risk 247.765 250.000 240.173 5.073 235.100 Pass: Major Risk O ~ f ^ , rà II H l Li ¡ rV~,~ WElLPATH DETAILS N7ES RKB = 55.8" MSL 55.800r' Origin Origin Starting +NI-S +FJ-W From TVD 0.000 0.000 0.000 Rig: Ref. Datum: V.SecliJn Angle 20.86' CaMP A.'IY DETAILS PbilJ;ps Alaska Inc. Engineerng Kuparuk Cakubtion MetOOd: Minimum ClU'1!Iure Error System: ISC\\'SA Scan MetOOd: Trow Cylinder North Error Surface: EnqJtkaJ + Casmg Warning MetOOd: Rub Bas"" ""ý'~ '0 M'TI-COLLIS[ON SETTINGS Interval: 50.000 To: [2674. ¡>n.WmYÆ p'n"' l'ì [nterpolation MelhodMD Depth Range From: 36.100 Hn_;~..~ DnV' l11:'âlY 5l'l NlA Longitul 1\'3;.178W 1;0' l.al 2)". ().217N 7 1:','l.'ling 47(12{'l1. North... mJ914. +Fj·\\, X'/J +NI· 70.9 Name ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 1 ??oo 11 000 12000 13000 ~ 3S-09 ~ Colour Plan: From o 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 1 ??oo 11000 12000 o 27~ ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 -36 7000 8000 9000 10000 -30 11000 12000 13000 -20 -10 -10 -20 -30 -0 From Colour 0- 200 - 400 - 600 - 800 - 1000 - 1500 2000 - 2500 3000 - 4000 5000 - 6000 7000 - 8000 - 9000 - 1??oo - 11000 - 12000 - 90 Tool CB-GYRO-SS MWD SURVEY PROGRAM (wp04) VI (wp04) V I Survey/Plan 35-10 35-10 Planned: Planned: Depth Fm Depth To 499.700 8026.300 28.100 499.700 -349 -300 -0 --200 -100 a -=. -l='-; -"'.< -;-100 c¡ ,/ -. '-0 -, ~ ,··......200 r2-~~~ r-- -300 3S-10 (wp04) Approved Plan -36 Target VSee 0.000 0.000 43.522 553.615 3674.594 4693.000 4730.923 TFace 0.00 0.00 20.68 5.77 0.00 80.00 0.00 Dug QOO QOO 2m 4m QOO 2m QOO SECTION DETAILS +N/-S +E/-W 0.000 0.000 15.370 228.726 1579.640 2020.469 2036.886 0.000 0.000 40.718 505.292 3330.424 4252.2K7 4286.614 TVD 2K.IOO 200.000 697.465 1564.2K5 4092.120 5K23.KOO 603'}.597 Az 0.00 0.00 20.6K 25.56 25.56 25.56 25.56 11\: 0.00 0.00 10.00 51.09 51.0,} 10.00 10.00 MD 2K.IOO 200.000 700.000 I 72K.2K I 5752.743 7K07.174 !HJ26.300 See 1 2 3 4 5 6 7 -349 [degJ vs Centre to Centre Separation [20ft/in] Azimuth (TFO+AZI Travelling Cylinder 35 (IOF) [deg] vs Centre to Centre Separation [200ft/in] Azimuth (TFO+AZI TraveIIing Cylinde ) ) 35-10 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" Casina Interval Risk Level I M itiqation Strateqy Low Monitor cellar continuously during interval. Event Broach of Conductor Gas Hyd rates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Moderate ~ncrease mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Moderate Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Low Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low 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 drillinq practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Moderate .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. Moderate Low Moderate Moderate 35-10 Drilling Hazards Summary.doc prepared by Scott Lowry 7/30/02 ..=tIG g 1~ll' I ",4 J·9 r.~:, , . , w, 1# ri..~ Page 1 of 1 KRU - 35-10 ProL. Jeer Proposed Completion Schematic Single Completion wI Jet Pump Contingency 16"x30" insulated I r ~ ~ conductor @ ~ ~ +/- 109' MD I: I: ~ ~ I: ~ TAM 9-5/8" Po~ ~ Collar Stnd ~ Grade BTC f§ Threads (+/- ~ 1000' MOITVD) ~ ~ ~ Surface csg. ~ 9-5/8"40# L-80 ~ BTC (3386' MD I .....LZ. 2605' TVD) Casing point 100' above the C80 sand C Sand Perfs (to be done after rig moves off) Production csg. 7" 26# L-8Q BTCM (+1- 8026' MD) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..J ] -! -: ï:: ,-",~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -.. Gemèn~ l i' ~ ~ ~ I ~ ~ ~ ~ ~ I ~ ~ L..... ~~ ~~ ~r ~ I ~ ,.. ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ F- If" -- !Ï." - f ~ ~ ~ ~ ~ ~ J ~ ~ ~ ~ ') ConocóPhiwlips 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 Space out Pups as Required. Special Drift 2.91" 3-1/2" Camco OS Landing Nipple with 2.S75" 10 No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Valves #1-4: 3-'W' x 1" KBUG Place gas-lift mandrels at the following depths: TVD Approximate MD GLM Placement TBD Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wI OCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve w/2.S13" Camco No-Go profile, EUESRD box x pin. 3-1/2" x 6' L-SO EUE8RD handling pups installed above 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. Baker 'SO-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1-100' MD above top planned perf. Minimum 10 through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'D' nipple w/2.75" No-Go profile. 6' Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. Ba~,er 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. /" TO @ 8026' MD 16040' TVD (200' MD below Miluveach) Scott L Lowry 11/27/02 o h " ~J j - ~ 'I S. K. ALLSUP~DRAKE PHILLIPS PETROLEUM COMPANY 711 G ST. ANCHORAGE AK 99501 1009 DATE ~~~z,.1311 ~~~:~Ò~E '3TI'fT£ OF-1IW'lSUI /Aci5CL ·a ~ ~/Úrs ~j~)Oò J $ lev. CO 'DOLLARS ~ =~=' ~... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars . , 2DOWhne Clay Center Dr.. Newark. DE 1971' :D~~-Líl~~ I: 0 j ~ ~ 0 0 ~ ~ 1.1: 2 ~ 8 0000 a. 2 ? 2 5 ? 1/' ~ 0 0 C1 ( -- -" ) ') TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI 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(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to . perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY~~/íï~c;WELL NAME ;t1!..L.l 3..5-/6 PROGRAM: Exp_ Dev ~ Redrll_ Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL 7'?ò Jd~ INIT CLASS /7~ /....¿.. ï GEOL AREA ~ ð UNIT# ///6ð ON/OFF SHORE.QL:;} ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 0 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . '( 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 8. If déviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 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.. . . . . y) N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ X/ /!/. /11 (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. ~ N . . ~ 30" \//é/' @ JO!! ENGINEERING 15. Conductor stnng provided. . . . . . . . . . . . . . . . . . . N r- . 16. Surface casing protects all known USDWs. . . . . . . . . N /I j . -I- 17. CMT vol adequate to circulate on conductor & surf csg. . . . ~ f"\1l,L.~ l-'....t.l It·f.. Q¡.J CRj¿( .4 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y .ti/ 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N . ¡ _I . 7LSÇ 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .. N IUI~tp.-@'í S 22. If a re-drill, has a 10-403 for abandonment been approved. . . f\Í/A 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . N ., 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . . N Q , APPR DATE 27. BOPE press rating appropriate; test to 5" 000 p sig. .. N Nt ~ P 2-L I 70 pc; ,. \. t/.· J! ? J J 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . , .. N ~q¡,""" ''1 'l.f)tOV 29. Work will occur without operation shutdown. . . . . . . . . . . ~.~. 30. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . yœ (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥--*-I't/k- GEOLOGY Yó)N APPR DATE ~,., .~ MfI, ~¿ 10A>1.. (Exploratory Only) RESERVOIR ENGINEERING APPR DATE I&.- ~:L 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... GEOLOGY: RP~ PETROLEUM ENGINEERING: UIC ENGINEER COMMISSIONER: COT tar 1~3!oÃ. DTS I VlO/O z... TEM JDH JBR Rev: 10/15/02 SFD_ WGA / MLB I Z./,2..D/oz.. MJW G:\geology\permits\checklist.doc ,( ( Comments/Instructions: ) ) Well History File APPENDIX Infornlation of detailed nature that is not particularly germane to the Well Pennitling Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. ') ) ~ '2 -'";2..3:2- \ \~B (0 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Sat May 24 09:45:16 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/05/24 OL'igìn. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Lihrary. Scientoific Technical Services Tape Header Service name............ .LIS'l'PE Date. . . . . . . . . . . . . . . . . . . . . 03/ 0 5/2 4 Origin. . . . . . . . . . . . . . . . . . . S'I'S Tape Name................UNKNOWN Continuation Nurnber......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scienti. fic Technical Services Physical EOF CommetJt Record TAPE I-!EÞ"DER Kuparuk River Unit MWD/MAD LOGS II WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # ,JOB DAT}.\ 38-10 501032044000 Conoco Phillips Alaska, Inc. Sperry Slm lO-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATORí'JITNESS: MWD RUN 2 AK-MW-22206 P. SMITH Ì"l. 'l'HORNTON # SURFACE LOCATION SECTION: 'T'OWNSHI P: RANGE: FNL: E'SL: FEL: FWL: El,EVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROONO LEVEL: 18 l?N 8E 2501 993 .00 56.30 ?7.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING ORILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.510 9.62S 336S.0 # REtv'J\RKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. ~ . ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. M'i'JD RUN 100 ¡'U\S DIRECTIONl\L ONLY l\ND v-JILL NOT EE ) ) DISPLAYED. 4. MWD RUNS 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUh~ER TUBE DETECTORS ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), CO¡V¡PEI'TSATED NEUTRON POROSITY (CNP), AND STABILIZED Ll'I'HO-DENSI'l'Y (SLD), AND PRESSURE WHILE DRILLING (FWD). 5. MWD DATA IS CONSIDERED PDC PER GKPA GEOSCIENCES. 6. M~'I1D RUNS 100 - 200 REPRESENT WELL 3S-10 WITH API II ,50-103-20440-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 8130' MD, 6176' TVD. SROP ~ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SE~SP = SMOO'l'HF',I) PHASE, SHI F"l' !)¡'~RIVED RF~S.IS'I'I.V.r'I'Y (SHAl..,.LO\I'J SPACING) . SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) . SFX¡;; = SMOO'I'HED FORM.ATION EXPOSURE TI.'.ME. SPSF = SMOOTHED NEUTRON POROSITY SANDSTONE MATRIX FIXED HOLE SIZE. SRD? = SMOOTHED mIL,K DENSITY COMPENS,I1,.TED (T'olAI-COUNT BIN) . SC02 SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTI-IED NEAR NEAR DETECTOR ONLY PHO'1'OELECTRTC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = SLD SENSOR DEPTH IN STEERING INTERVALS. ENVIRONMENTAL PARAMETERS USED FOR NUCLEJ\R LOG PI'\OCESSING: BOREHOLE SIZE: ¡VIU D SALT NT 'I'Y : FORMATION WATER SALINITY: MUD WEIGH'l': HUID DENSITY: 1vlATRIX DENSITY: MATRIX LITHOLOGY: FORMATION WATRR RRSTSTTTVJY 8.5" 1.00 - 300 ppm CL- 25,000 ppm CL- 9.4 - 12.3 ppg 1.00 glee 2.65 glee Sl\NDSTONE o . .1 5 OHMM $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Ve r-s ion Numbe r. . . . . . . . . . . 1 .0.0 Date of Generation.......03/05/2~ Maximum Physical Record. .65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED HERGE.D HI^ID Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 ff FILE SUHMARY PBU TOOL CODE FCNT PEF START DEPTH 3348.0 STOP DEPTH 8045.0 8054.5 3348.0 ') ) DRHO GR l=ì.HOB NPHI ROP NCNT RPX RPM RPS RPD FET $ 3318.0 3348.0 3348.0 3348.0 3348.0 3348.0 3357.0 335'1.0 3357.0 3357.0 3365. ,5 8054.5 8098.5 8054.5 8011.5 8129.5 8045.0 8090.5 8090.5 8090.5 8090.5 8090.5 JI BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ------.--- EQUIVALENT UNS.HI FTED DEPTI! --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 3348.0 MERGE BASE 8129..'J II REMARKS: MERGED MATN PASS. $ j Data Format Specification Record Data Record Type.................. 0 Dat.:l Specificati.on Block Type..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Abse!lt value............... ....... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Sj,ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 <1 ¿ GR MWD ll..PI 1 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS ¡VIWD o HIIIJ¡VI 4 1 68 16 5 RPM MWD OHMM 1 1 68 20 6 RPD MWD OHMM 4 1 68 :24 'f FET HWD HR 4 1 68 28 8 NPHI MWD PU 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 ], 68 40 11 RHOS MWD G/CC 4 1 68 44 12 DRI-IO Míl\TD Glee 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Fir::;t La::;t Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3348 8129.5 5738.75 9564 3348 8129.5 ROP MWD FPH 3.96 1922.31 184.831 9564 3348 8129.5 GR MWD API 44.49 411 . 42 120.4/9 %02 ::1348 80~'8.!J RPX M¡,m o HMIIIJ 0.25 675.69 4.51287 9468 3357 8090.5 RPS MWD OHMM 0.19 1668.15 1.13111 9168 3357 8090.5 RPM MWD Ol-ItvIM 0.21 2000 ~. 39594 9468 33.'JÎ 8090.~ RPD tviND OHV1H 0.06 2000 8.95156 9468 3357 8090.5 FCT t'-1WD ¡¡R 0.1469 92.9028 0.696888 9451 3365.5 8090.5 NPHI MWO PU 15.53 81.76 41.7618 9394 3348 8044.,5 FCNT MWD CP30 462 1331 652.238 9395 3348 8045 ~JCNT MÍI'm CP30 2280 3888 2714.75 9395 3318 80,15 RH08 MHO G/ee 1.002 2.937 2.32134 9383 3348 1)54. ') DRHO ¡vrw 0 G/CC -1.101 Û.425 0.0560866 9383 3348 054.5 PCf M';VO D/C 1.97 14.09 4.10296 9414 3348 054..5 ') First Reading For Entire File..........3318 Last Reading For Entire File...........8129.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.ü Date of Generation.......03/05/24 Maximum Physical Record..65535 Fi! e Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/24 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.001 Cornrnenc Recor"d FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # rILE SUMMARY VENDOR TOOL CODE DRHO RHOB NCNT FCNT NPHI PEF ROP GR RPD RPJVI RPS RPX FET 2 ) header data for each bit run in separate files. 2 .5000 è -r' START DEPTH 3348.0 3348.0 3318.0 3348.0 3348.0 3348.0 3348.0 3348.0 3357.0 3357.0 3357.0 3357.0 .3365.5 # LOG HEADER DATA DATE LOGGED: SO FTWP<.RE SUF:.FACE SOFTWARE VERSION: DOt^JNHOLE SOfTWNŒ VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (E'T): BIT ROTATING SPEED (RPM): 1IOLE INCLINATION (DEG MINIMUM .1l,J\!GLE: MAXIMUM ANGLE: " 1r TOOL STRING (TOP TO VENDOR TOOL CODE DGR EIIIJRI\ CNP SLD S STOP DEPTH 80!J4.5 8054.5 8015.0 8045.0 8044.5 8054.5 8129.5 8098.5 8090.5 8090.5 8090.5 8090.5 8090.5 BOTTOM) TOOL TYPE DUAL GAr·U-1A RAY ELECTRO~~G. RESIS. 1\ COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE .l\.ND C.l\.SING D.l\.T.z:1. OPEN HOLE BIT SIZE (IN): 05-JAN-03 Insite 0.43 Memory 10.:2 SL.3 TOOL NUMBER 155789 134758 1201S6 15181:::: 8.b10 '} ) , DRILLER'S CASING DEPTH (FT): 3365.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): R8SISTIVITY (OlIMM) AT TCMF8RATURE (DEGF) MUD AT MEASURED TEMPERATURE (1'11.'): .HUD AT HAX CIRCULATIl\[G TERIV¡PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.40 27.0 9.5 400 2.0 3.000 34.905 2.700 3.600 72.0 130.2 72.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): H TOOL STANDOFF (IN): EWR E'.REQUENCY (HZ): II REMARKS: $ jl Data Format Specification Record Dat.a Record 'l'ype..................O Data Specification Block Type.....O Logging Direction................. Dm-m Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record_._..........Undefined Absent value...................... - 9 9 9 Depth Units....................... Datum Sped. fication Block sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FFH 4 1 68 4 2 GR MWD020 API 1 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS M\l1JD 0 2 0 OHHM <1 1 68 16 5 RPH MWD020 OHMM <1 1 68 20 6 RPD MWD020 OHHM 4 1 68 24 "/ FET MWD020 HR 4 1 68 28 8 NFHI MWD020 PU 4 1. 68 32 9 FCNT MWD020 CP30 4 1 68 36 10 NCNT MWD020 CP30 4 1 68 40 11 RHOB MWD020 Glee 1 1 68 11 12 DRHO MtÑD020 Glec 4 1 68 48 13 PEr MWD020 G/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEFT FT 3348 8129.5 5738.75 9564 3348 8129.5 ROP MvW020 FPH 3.96 1922.31 181.83"- 9561 3318 8129.5 l:;R MWD020 .A.PI 44.49 41/.42 120.4/9 9~O2 jj4B B09B.~ RPX IVrvW020 o ¡-¡¡VUI/[ 0.25 675.69 4.51287 9468 3357 8090.5 RPS MWD020 OHMM 0.19 1668.15 1. '13111 9168 3357 8090.5 RFM HWD020 OHMM 0.21 2000 tJ.39.':J94 946ij 33.':J1 ij090..':J RFD HWD020 OHHH O.OG 2000 8.95156 9468 3357 8090.5 fET Mí"lD020 IIR 0.1469 92.9028 0.696888 9451 3365.5 8090.5 NFHI MWD020 FU 1.').53 81.76 41.7618 9394 3348 8044.5 tCNT IvíWD020 CP30 462 1331 652.238 9395 3348 8045 NCNT M1"tJD020 CP30 2280 3888 2711 75 9395 3318 8045 RHOE M\ÑDC120 G/ee 1.002 2.937 2.32 34 9383 3348 054.5 DRHO ¡vfvJDO 2: 0 G/ee -1.101 0.425 0.0560 66 ~ 383 3348 054.5 PEr ¡'''[¡"10020 ColE 1. 9; 14.09 4.10 96 9414 3348 0"" " .....J"'1.......,J firct Rcading For:- Entirc Filc..........3318 ) Last Reading For Entire File...........8129.5 File Trailer Service name........... ..STSLIB.002 Service Sub Level J\Íame... Version Number.......... .1.0.0 Date of Generation.......03/05/24 1'1ö.ximum Physical Record.. G5535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03/05/24 OÜgin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......Ol Next. Tape Name........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Serviccs Reel Trailer Servicc name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ OS/24 Origin...................STS Reel Name................ UN!\'NOWN Continuation Nurnber..... .01 Next Reel Name...........UNKNOWN Comments. . .... . . . . . . . . . . . STS LIS Writing Library. Scienti f:i.c Technical Services Physical EOF Physical EOF End Of LIS File ) ) ;? 0:1- ;;)3;) 1/0 r~ 3S-10.tapx Sperry-Sun Drilli~g.services LIS Scan Utlllty $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 10 15:02:43 2003 Reel Header service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/10 ori gi n . . . . . . . . . . . . . . . . . . . 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. . . . . . . . . . . . . . . . . . . . .03/04/10 ori gi n . . . . . . . . . . . . . . . . . . . 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-10 501032044000 Conoco phillips Alaska, Inc. sperry Sun 10-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22206 P. SMITH M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION eFT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2501 993 .00 56.30 27.70 # WELL CASING RECORD page 1 ) ') 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 3s-10.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.510 9.625 3365.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 100 WAS DIRECTIONAL ONLY AND WILL NOT BE DISPLAYED. 4. MWD RUNS 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MULLER TUBE DETECTORS ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO-DENSITY (SLD), AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUNS 100 - 200 REPRESENT WELL 3S-10 WITH API # 50-103-20440-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8130' MD, 6176' 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. SPSF = SMOOTHED NEUTRON POROSITY SANDSTONE MATRIX FIXED HOLE SIZE. SBD2 = SMOOTHED BULK DENSITY COMPENSATED (LOW-COUNT BIN). sco2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = SLD SENSOR DEPTH IN STEERING INTERVALS. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: BOREHOLE SIZE: MUD SALINITY: FORMATION WATER MUD WEIGHT: FLUID DENSITY: MATRIX DENSITY: 8.5" 100 - 300 ppm CL- SALINITY: 25,000 ppm CL- 9.4 - 12.3 ppg 1.00 glee 2.65 glee page 2 ') ) 3S-10.tapx MATRIX LITHOLOGY: SANDSTONE FORMATION WATER RESISITIVIY 0.15 OHMM $ File Header service name............ .STSLIB.001 service Sub Level Name... version Number.......... .1.0.0 Date of Generation..... ..03/04/10 Maximum physical Record..65535 F i 1 e Ty p e. . . . . . . . . . . . . . . . LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT PEF DRHO GR RHOB NPHI ROP NCNT RPX RPM RPS RPD FET $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 3348.0 3348.0 3348.0 3348.0 3348.0 3348.0 3348.0 3348.0 3357.0 3357.0 3357.0 3357.0 3365.5 STOP DEPTH 8045.0 8054.5 8054.5 8098.5 8054.5 8044.5 8129.5 8045.0 8090.5 8090.5 8090.5 8090.5 8090.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3348.0 8129.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format specification Record Data Record Type... ...............0 Data specification Block Type.....O Log~ing Direction................ . Down optlcal log depth units.......... .Feet Data Reference Point......... .....undefined Frame spacing..... ...... ......... .60 .1IN Max frames per record............ .undefined Absent value..................... .-999 Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O page 3 ) ) 3S-10.tapx Name Service Order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD pu 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD cp30 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Fi rst Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3348 8129.5 5738.75 9564 3348 8129.5 ROP MWD FPH 3.96 1922.31 184.834 9564 3348 8129.5 GR MWD API 44.49 417.42 120.479 9502 3348 8098.5 RPX MWD OHMM 0.25 675.69 4.51287 9468 3357 8090.5 RPS MWD OHMM 0.19 1668.15 4.43111 9468 3357 8090.5 RPM MWD OHMM 0.21 2000 5.39594 9468 3357 8090.5 RPD MWD OHMM 0.06 2000 8.95156 9468 3357 8090.5 FET MWD HR 0.1469 92.9028 0.696888 9451 3365.5 8090.5 NPHI MWD pu 15.53 81.76 41.7618 9394 3348 8044.5 FCNT MWD CP30 462 1331 652.238 9395 3348 8045 NCNT MWD CP30 2280 3888 2714.75 9395 3348 8045 RHOB MWD G/CC 1.002 2.937 2.32134 9383 3348 8054.5 DRHO MWD G/CC -1.101 0.425 0.0560866 9383 3348 8054.5 PEF MWD B/E 1.97 14.09 4.10296 9414 3348 8054.5 First Reading For Entire File.... ..... .3348 Last Reading For Entire File... ...... ..8129.5 File Trailer service name............ .STSLIB.001 service sub Level Name... version Number.. ........ .1.0.0 Date of Generation...... .03/04/10 Maximum physical Record..65535 F i 1 e Ty p e. . . . . . . . . . . . . . . . L 0 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... ....03/04/10 Maximum physical Record. .65535 Fi 1 e Type.. . . . . . . . . . . . . . . LO Previous File Name... ....STSLIB.001 Comment Record page 4 FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE DRHO RHOB NCNT FCNT NPHI PEF ROP GR RPD RPM RPS RPX FET $ ) 3s-10.tapx 2 START DEPTH 3348.0 3348.0 3348.0 3348.0 3348.0 3348.0 3348.0 3348.0 3357.0 3357.0 3357.0 3357.0 3365.5 STOP DEPTH 8054.5 8054.5 8045.0 8045.0 8044.5 8054.5 8129.5 8098.5 8090.5 8090.5 8090.5 8090.5 8090.5 # 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 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # page 5 ) 05-JAN-03 Insite 0.43 Memory 10.2 52.3 TOOL NUMBER 155789 134758 120156 151842 8.510 3365.0 LSND 9.40 27.0 9.5 400 2.0 3.000 34.905 2.700 3.600 72.0 130.2 72.0 72.0 ) ) 3s-10.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification Record Data Record Type.... ..... ....... ..0 Data specification Block Type.....O Logging Direction... ..... ........ . Down Optlcal log depth units.......... .Feet Data Reference Point............ ..undefined Frame spacing........ ........ .... .60 .1IN Max frames per record..... .... ... .undefined Absent val ue. . . . . . . . . . . . . . . . . . . . . . -999 Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type. ..0 Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 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 HR 4 1 68 28 8 NPHI MWD020 PU 4 1 68 32 9 FCNT MWD020 CP30 4 1 68 36 10 NCNT MWD020 CP30 4 1 68 40 11 RHOB MWD020 G/cc 4 1 68 44 12 DRHO MWD020 G/cc 4 1 68 48 13 PEF MWD020 B/E 4 1 68 52 14 Fi rst Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3348 8129.5 5738.75 9564 3348 8129.5 ROP MWD020 FPH 3.96 1922.31 184.834 9564 3348 8129.5 GR MWD020 API 44.49 417.42 120.479 9502 3348 8098.5 RPX MWD020 OHMM 0.25 675.69 4.51287 9468 3357 8090.5 RPS MWD020 OHMM 0.19 1668.15 4.43111 9468 3357 8090.5 RPM MWD020 OHMM 0.21 2000 5.39594 9468 3357 8090.5 RPD MWD020 OHMM 0.06 2000 8.95156 9468 3357 8090.5 FET MWD020 HR 0.1469 92.9028 0.696888 9451 3365.5 8090.5 NPHI MWD020 PU 15.53 81.76 41.7618 9394 3348 8044.5 FCNT MWD020 cp30 462 1331 652.238 9395 3348 8045 NCNT MWD020 CP30 2280 3888 2714.75 9395 3348 8045 RHOS MWD020 G/cc 1.002 2.937 2.32134 9383 3348 8054.5 DRHO MWD020 G/cc -1.101 0.425 0.0560866 9383 3348 8054.5 PEF MWD020 B/E 1.97 14.09 4.10296 9414 3348 8054.5 First Reading For Entire File. .... ... ..3348 Last Reading For Entire File... ... ... ..8129.5 page 6 J' ) ) 3s-10.tapx File Trailer service name... ......... .STSLIB.002 service sub Level Name... version Number... ....... .1.0.0 Date of Generation. ..... .03/04/10 Maximum physical Record. .65535 F i 1 e Ty p e. . . . . . . . . . . . . . . . L 0 Next File Name....... ... .STSLIB.003 physical EOF Tape Trailer service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/10 origin.................. .STS Tape Name... ........ .... . UNKNOWN Continuation Number... ...01 Next Tape Name........ ...UNKNOWN Comments........ ....... ..STS LIS writing Library. scientific Technical Services Reel Trailer service name.. ........ ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/10 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 page 7
