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Home My WebLink About205-101 · . 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. ~().S - 1 Q L Well History File Identifier Organizing (done) o Two-sided 11111111111 III" III o Rescan Needed 1111111111111111111 REj-CAN ~Color Items: o Greyscale Items: DIGITAL DATA ¿Diskettes, No. ~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date 7/[):3J 07 o Other:: BY: .~ 151 mP /1111111111I11 11111 Project Proofing BY: ~ Date 7/;;;:'/ D 7 ~ x 30 = ~o Date7/~/D7 151 MP Scanning Preparation BY: ~ + ß = TOTAL PAGES fog (Count does not include cover sheet) .J\ A.D 151 , YIT BY: Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does ;nctude CO.?Sheet) Page Count Matches Number in Scanning Preparation: V YES CMaria) Date:7/d3/D7 If NO in stage 1, page(s) discrepancies were found: /11111111111111111I NO 151 Yl1 P Stage 1 YES NO BY: Maria Date: 151 ""11111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 111111111I1111" III BY: Maria Date: 151 Comments about this file: Quality Checked /1111111I1/11111111 10/6/2005 Well History File Cover Page. doc Permit to Drill 2051010 MD 10408 r TVD 6533 r UIC N ). ~ J\A)l DATA SUBMITTAL COMPLAANCE REPORT 7/2/2007 Well Name/No. KUPARUK RIV UNIT 1C·21L2 Operator CONOCOPHILLlPS ALASKA INC 21 ~o'i~2~~3~1-00 REQUIRED INFORMATION DATA INFORMATION Completion Date 6/22/2005 /" Completion Status 1-01L Current Status 1·01L Mud Log No Samples No Types Electric or Other Logs Run: GRlRes Well Log Information: Directional Survey @ - (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ Scale Media No Start Stop CH .- 10079 1 0408 Open 10079 1 0408 Open 5652 1 0340 Open 13290 LIS Verification 13290 Induction/Resistivity Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I~D Asc~--rnrecÜonal Sû;vey_·_~ I ¿ D Asc Directional Survey ~ D Lis ~ ~c U, ~D C Las I i Well Cores/Samples Information: - Received Comments 7/29/2005 IIFR 7/29/2005 MWD 9/26/2005 GR EWR4 ASI CNP SLD ROP PWD GEOPLOT GR EWR4 ASI CNP SLD ROP PWD GEOPLOT ROP DGR EWR SLD CTN plus Graphics LIS Veri, GR, ROP, NCNT, NPHI, RHOS, DRHO w/Graphics 5652 10340 Open 9/26/2005 116 10408 Open 2/22/2006 5652 10408 Open 1/29/2007 ---- Sample Set Sent Received Number Comments 13696 Induction/Resistivity 14436 Induction/Resistivity Name ADDITIONAL INFORMATION Well Cored? ~ Chips Received? 'r"t'f't- Analysis ~ Received? --~"~-~-~.. Interval Start Stop Daily History Received? Q)N ~/N Formation Tops ----- ~."-- Comments: -~.- a Permit to Drill 2051010 MD 10408 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Well Name/No. KUPARUK RIV UNIT 1C-21L2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23253-61-00 6533 p:;;on D,te 612212005 Current Status 1-01L UIC N Oat<" II ~S2 ¡}tJ 7 Completion Status 1-01L e e . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21_L1_L2_L3, 1D-28_L1, 1F-01A, 3F-19A,3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1B-15A: [)o4.f-d5"G:, 1d: ¡L.../¿..I2D Digital Log Images: 50-029-23465-01 - ~ Ç)DS--03Lf} [}OS" -I DO¡ goS -I 0 I I ÐO~ -/0 I'-ILI ?/./ /4/...f'3fJ 14t../3fo J'IL-/3+ 1 CD Rom 1C-21 L1 L2 L3: - - - Digital Log Images: 50-029-23253-00,60,61,62 1 CD Rom 1D-28 L1: Digital Log Images: 50-029-23237-00, 60 ;)6</ -g;S7 1/-/43d golf -d3ir ¡l../t./33 1 CD Rom 1F-01A: ;)OS- -O;;A -d ¡4L/d?J Digital Log Images: 50-029-20889-01 3F-19A: f)()t./ -Otro ? IL¡t.¡ 3/ Digital Log Images: 50-029-22680-01 1 CD Rom 1 CD Rom 3H-14B: 066 -Oéjl :It t4¿./éP! Digital Log Images: 50-103-20092-02 1 CD Rom ¡ ( . . WELL LOG TRANS MITT AL dJ05- 00 905 - ! Ù , "'!î ~ 1 hr'ì/ cJu':) - . \)0' Febmary 16, 2006 /3 ¿I'D¡$'" /3Ú/C¡/.p /3L(;07 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs 1C-21 L1 + L2 + L3, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 lC-21 Ll + L2 + L3: LAS Data & Digital Log Images: 50-029-23253-60,61,62 1 CD Rom ~, P1 t! ~!iX; . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs lC-21 L2, 1 LDWG formatted Disc with verification listing. API#: 50-029-23253-61 . Septernber23,2005 AK-MW-3706651 f \ »)-qÒ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: :< ~ S<¡1-~ ç- ÎW ðRJ Signed: ). ~;; - (Ò/ RE:CEIVED . STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COM~ION AUG 0 2 Z005 WELL COMPLETION OR RECOMPLETION REfiQ liJiI MRo~QAni,>~í(\n Oil 0 Gas U Plugged U Abandoned U Suspended D WAG D 1 b. Well C~~s: hAr 20AAC 25.105 20AAC 25.11 0 Developm~QCEJ age Exploratory D WlNJ 0 WDSPL D No. of Completions _ Other Service D Stratigraphic TestD 12. Permit to Drill Number: 1a. Well Status: GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1291' FSL, 2350' FWL, Sec. 7, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562198 / y- TPI: x- 567291 y- Total Depth: x- 568658 ' y- 18. Directional Survey: Yes 0 NoU 5968638 ,- 5966753 5966306 "" 5. Date Comp., Susp., or Aband.: June 22, 2005 6. Date Spudded: 31 J..'P Mayj4;2005 9,Ç·~ 7. Date TD Reached: June 2, 2005 / 8. KB Elevation (ft): 42' RKB 9. Plug Back Depth (MD + TVD): N/A 10. Total Depth (MD + TVD): / 10408' MD /6533' TVD / P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1601' FNL, 1191' FWL, Sec. 12, T11N, R10E, UM At Top Productive Horizon: Total Depth: 1751' FSL, 987' FWL, Sec. 7, T11N, R11E, UM 21. Logs Run: GRlRes, Dens/Neu 22. CASING SIZE wr. PER FT. 62.58# 45.5# 29.7# 16" 10.75" 7-5/8" GRADE H-40 L-80 L-80 Zone- 4 Zone- 4 11. Depth where SSSV set: none Zone- 4 19. Water Depth, if Offshore: N/A 205-101/ 13. API Number: 50-029-23253-61 14. Well Name and Number: 1C-21L2 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 28242, 25649 17. Land Use Permit: ALK 2292 20. Thickness of feet MSL Permafrost: 1928' MD ~O/ot¡.o ' /I'1Þ/ (ø S"3it ',KÞ ~ ~,S'.oS- !<op CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 42' 116' 42' 116' 42' 5680' 42' 4480' 42' 9154' 42' 6542' HOLE SIZE 24" 13.5" 9-7/8" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 24. SIZE n/a open hole completion from 9986'-10408' MD 6538'- 6533' TVD 26. Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure press. psi 27. CEMENTING RECORD AMOUNT PULLED 9 cu yds High Early 776 sx AS Lite, 389 sx LiteCrete 255 sx Class G TUBING RECORD DEPTH SET (MD) I PACKER SET 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for OIL-BBL GAS-MCF Test Period .-> Calculated OIL-BBL GAS-MCF 24·Hour Rate .> same as 1 C-21 WATER·BBL WATER-BBL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 10-407 Revised 12/2003 RBDMS BFL AUG 0 8 Z005 NONE CONTINUED ON REVERSE ¡\JAL CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) f'''''''-'' --""" ,._... ...·c·.,_ _.~-~.~. -~ ......\ ~ :,., ¡ ¡ - /- ;".: ;:. ' ,..¡., ., !l:LZZ_Ø)Þ. ¡ ¡ _...'~~'~::~:;J 28. . 29. . FORMATION TESTS GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested. and attach detailed supporting data as necessary. If no tests were conducted. state "None". 1C-21L2 Top Kuparuk C C-4 9107' 9107' 6537' 6537' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 Printed Name." /"~homas _. Thomas Signature ó7t/~ Title: Greater Kuparuk Area DrillinQ Team Leader Phone 7Þ¡/o5 Date 4 (2. 1Æ(/~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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate'production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/11/2005 04:00 - 10:00 6.00 MOVE DMOB MOVE Prepare for rig move. RDMO Rock Washer. Slide rig floor to center of drilling module. Disconnect service lines between drilling and service module. 10:00 -12:00 2.00 MOVE MOVE MOVE Move rig off well 1 F-01A. 12:00 - 00:00 12.00 MOVE MOVE MOVE Move Doyon Rig 15 from 1 F Pad to 1 C Pad. 5/12/2005 00:00 - 00:30 0.50 MOVE MOB MOVE Move Doyon Rig 15 to 1 C-Pad. 00:30 - 02:30 2.00 MOVE POSN MOVE Move support module onto matting boards 02:30 - 06:00 3.50 MOVE POSN MOVE Move drilling module onto matting boards, turn tires. 06:00 - 08:30 2.50 MOVE POSN MOVE Move in and spot drilling module over well 1 C-21. 08:30 - 12:00 3.50 MOVE POSN MOVE Skid rig floor over sub, shim up and level. Spot in support module, set in rock washer. 12:00 -13:00 1.00 MOVE POSN RIGUP Hook up service lines. Complete berming around rig and rock washer. Accepted rig for operations on we1l1C-21 at 13:00 hrs. 13:00 -15:00 2.00 MOVE RURD RIGUP Take on fuel and water for rig. CPAI E&I hook up hi-line power to rig. General rig up activities in pipe shed, mud pits, pump room, and cellar. 15:00 -18:00 3.00 MOVE RURD RIGUP N/U 21-1/4" Divertor System and surface equipment. Take on 580 bbls pre-mixed spud mud into pits. 18:00 - 22:30 4.50 DRILL PULD SURFAC Load pipe shed with 5" drill pipe. Remove thread protectors, inspect, number, and strap 5" drill pipe. Drift on skate. 22:30 - 00:00 1.50 DRILL PULD SURFAC Set mouse hole in rotary table. P/U 5" drill pipe and make up in stands. Rack back drill pipe in derrick. 5/13/2005 00:00 - 05:30 5.50 DRILL PULD SURFAC P/U 5" drill pipe and make up in stands. Rack back drill pipe in derrick. Drift on skate. 05:30 - 06:00 0.50 DRILL PULD SURFAC Load 5" HWDP into pipe shed. Remove thread protectors, inspect, number, strap, and drift drill pipe. 06:00 - 09:30 3.50 DRILL RIRD SURFAC C/O Top Drive saver sub to 4-1/2" IF. Lay down all 4" handling tools, Clear rig floor. 09:30 - 11 :30 2.00 DRILL PULD SURFAC P/U 5" HWDP make up/break out new pipe. Rack back HWDP in derrick. 11 :30 - 12:00 0.50 DRILL OTHR SURFAC Attempt to function test Divertor system. Top element in 21-1/4" Hydril failed resulting in a 10 gal hydraulic spill to secondary contaminment. 12:00 - 18:00 6.00 RIGMNT RGRP SURFAC N/D riser, mouse hole and flow line. Remove beaver slide to access cellar. Remove and replace 21-1/4" Hydril divertor. 18:00-20:15 2.25 RIGMNT RGRP SURFAC N/U riser and flow line. Set in mouse hole. RIU flow line. Set in beaver slide. 20:15 - 22:15 2.00 DRILL OTHR SURFAC M/U stand of drill pipe and RIH. Function test divertor system, OK. Fluid test, OK. Jeff Jones, AOGCC PI, waived witnessing Divertor function test. 22:15 - 00:00 1.75 DRILL PULD SURFAC M/U 13-1/2" bit and BHA. Set AKO on Motor at 1.5 deg. 5/14/2005 00:00 - 00:15 0.25 DRILL PULD SURFAC M/U 13-1/2" Bit & BHA #1. Set MM AKO at 1.5 deg. 00:15 - 01 :15 1.00 DRILL PULD SURFAC RIU sheave in derrick for S/L run with gyro survey. 01 :15 - 02:00 0.75 DRILL REAM SURFAC PIT surface mud lines to 2,500 psi. OK. Clean out ice from inside 16" conductor to 116' with FW. 02:00 - 02:15 0.25 DRILL DRLG SURFAC Drill 13-1/2" OH to 130'. 02:15 - 04:45 2.50 DRILL PULD SURFAC POH, rack back HWDP. M/U MWD tools and orient same. 04:45 - 07:00 2.25 DRILL CIRC SURFAC RIH to btm. Break circulation with spud mud. Returns are thick mud will not flow down auger chute. Circulate and condition mud until vis is down to 300. 07:00 - 08:30 1.50 DRILL DRLG SURFAC Drill 13-1/2" OH to 277'. 08:30 - 09:00 0.50 DRILL TRIP SURFAC POH to 100' 09:00 - 09:45 0.75 DRILL PULD SURFAC M/U remaining BHA, Drill collars and Jars. 09:45 - 10:00 0.25 DRILL TRIP SURFAC RIH to btm. 10:00 - 17:30 7.50 DRILL DRLG SURFAC Rotary drill 13-1/2" OH to KOP at 1,110'. Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/14/2005 17:30 - 00:00 6.50 DRILL DRLG SURFAC Directionally drill 13-1/2" OH to 1,886' MD. ART = 9.23 hrs. AST = 4.1 hrs. ADT = 13.33 hrs. 5/15/2005 00:00 - 05:00 5.00 DRILL DRLG SURFAC Directionally Drill 13-1/2" OH to planned inclination and azimuth at 2,499' MD. AST=2.15, ART=1.25, ADT=3.4, P/U=152k, S/O=145k, Rot=145k, gpm= 550 @ 2,225 ps on bottom, 1750 psi off bottom, 80 rpm, Torque= 7-8k on bottom, 3-4k off bottom, 05:00 - 00:00 19.00 DRILL DRLG SURFAC Rotary Drill 13-1/2" OH to 4,609' MD. Maintain inclination and azimuth. AST = 3.03 hrs ART = 12.47 hrs ADT = 15.5 hrs Rot=160K, P/U=200K, S/O=150K, rpm=80, Torque=10kon, 10torque off = 7-8k, gpm=560 @ 2,379 psi on bottom, 2100 psi off bottom. 5/16/2005 00:00 - 01 :30 1.50 DRILL DRLG SURFAC Drill 13-1/2" hole per directional plan. AST=O, ART=1.06. ADT=1.06. Rot=160k, P/U=200k, S/O=140k, rpm=80, Torque=10-14k on 7-8k off, gpm=500 psi @ 2050 on bottom, 1550 psi off bottom. ROP decreased and torque was spiking 01 :30 - 03:00 1.50 DRILL CIRC SURFAC Stand back stand and CBU @ 429 gpm @ 1400 psi. 03:00 - 08:00 5.00 DRILL TRIP SURFAC Monitor well for 10 min.lstatic. POOH 2 stands and pump dry job. Blow down top drive and POOH to BHA w/ no problems. 08:00 - 11 :30 3.50 DRILL DEQT SURFAC C/O Bit and MWD Tool. RIH shallow test MWD. Tool Failure. 11 :30 - 13:30 2.00 DRILL DEQT SURFAC POH. C/O MWD Tool. RIH. Shallow test MWD Tool, OK. 13:30 - 14:30 1.00 DRILL TRIP SURFAC M/U DC's, Jars, & HWDP, RIH 14:30 - 16:00 1.50 RIGMNT RSRV SURFAC Slip & Cut Drilling Line. 16:00 - 16:30 0.50 DRILL TRIP SURFAC RIH to 1,300'. 16:30 - 17:00 0.50 RIGMNT RGRP SURFAC Inspect Drawworks. Drum coolant line parted. 17:00 - 19:00 2.00 DRILL TRIP SURFAC POH to repair Drawworks. 19:00-21:00 2.00 RIGMNT RGRP SURFAC Repair Draworks Drum Coolant Line. 21 :00 - 21 :45 0.75 DRILL TRIP SURFAC RIH to 1,300' 21 :45 - 00:00 2.25 DRILL TRIP SURFAC RIH with Bit #2 to 2,839' 5/17/2005 00:00 - 03:30 3.50 DRILL TRIP SURFAC RIH with Bit #2. M/U top drive, break circulation, wash last 60' to Btm at 4,688'. Hole in good condition. 03:30 - 15:30 12.00 DRILL DRLG SURFAC Drill 13-1/2" OH as per directional plan to 5,690' MD, TVD 4,490'. Up wt = 220K, Dn wt = 150K, ROT wt = 180K, TQ = 1 0-18K, Circ at 650 GPM 2,650 psi. AST = 1.58 hrs, ART = 6.78 hrs, ADT = 8.36 hrs. A VG ROP = 120 fph. 15:30 - 19:00 3.50 DRILL CIRC SURFAC Circulate and condition Mud. Lower funnel viscosity to 100 s/qt. 19:00 -19:15 0.25 DRILL OBSV SURFAC Monitor well for 10 min. Well static. 19:15 - 23:00 3.75 DRILL TRIP SURFAC POH 5 stds, Pump dry job, POH to BHA. Tight spot observed at 1,550'. Work tight spot clean. SLM, no correction to strap. 23:00 - 00:00 1.00 DRILL PULD SURFAC Lay down BHA and clear floor. 5/18/2005 00:00 - 01:15 1.25 DRILL SURV SURFAC Down load data from MWD tool. 01:15 - 02:15 1.00 DRILL PULD SURFAC Finish laying down BHA, Clear Rig Floor. 02:15 - 03:15 1.00 CASE SFTY SURFAC Remove hazardous ice build up from derrick prior to running casing. 03:15 - 05:30 2.25 CASE RURD SURFAC RIU equipment to run 10-3/4" casing. Make drift run with FMC mandrel casing hanger thru 20" riser and hydril divertor.. RIU spider and elevators. M/U Franks circulating tool. RIU casing power tongs. Inspect and function test stabbing board. 05:30 - 06:00 0.50 CASE RURD SURFAC Service Top Drive and Crown. 06:00 - 11 :30 5.50 CASE RUNC SURFAC PJSM, RIH with 10-3/4" Casing to 2,600'. Up wt = 140K, Dn wt = 115K. Observed hole drag from 1,400' to 2,600' at 10-35K. 11 :30 - 12:30 1.00 CASE CIRC SURFAC Circulate and condition mud at 45 spm, 350 psi. 12:30 -13:00 0.50 CASE RUNC SURFAC RIH with 10-3/4" casing to 3,100'. Observed hazardous ice build up in derrick. 13:00 - 13:30 0.50 CASE SFTY SURFAC Remove ice build up from derrick. 13:30 -17:00 3.50 CASE RUNC SURFAC RIH with 10-3/4" casing to 4,050'. Printed: 7/512005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/18/2005 17:00 - 18:00 1.00 CASE CIRC SURFAC Circulate and condition mud at 48 spm, 450 psi. 18:00 - 21 :00 3.00 CASE RUNC SURFAC RIH with 10-3/4" casing to 5,650'. Total jts ran = 139. 21:00 - 21:15 0.25 CASE RUNC SURFAC M/U FMC 10-3/4" Mandrel casing hanger with landing jt. Land casing on landing ring. 21 :15 - 22:00 0.75 CASE RURD SURFAC N/D Franks fill up tool.. M/U Schlumberger Cement head. 22:00 - 00:00 2.00 CASE CIRC SURFAC Circulate and condition mud prior to cement job. Reciprocate casing at 320K up and 180K dn. 5/19/2005 00:00 - 03:30 3.50 CEMENTCIRC SURFAC Circulate and condition mud for cement job. Mud properties are 10.0 ppg, Vis 57, 600 rpm 28,300 rpm 18, 200 rpm 13, 100 rpm 10,6 rpm 5, 3 rpm 4, PV 10, YP 8, Gels 5/6/8. Pump rate 7 bpm at 200 psi. Reciprocate Casing. Up wt 310K, Dn wt 200K. 03:30 - 03:45 0.25 CEMENT SFTY SURFAC PJSM with Rig Crew, Cementers, and Truck Drivers. 03:45 - 06:00 2.25 CEMENT PUMP SURFAC Pump 7.5 bbls water. Test cement lines to 3,500 psi. Pump 50 bbls CW100 followed by 50 bbls 10.5 ppg Mud Push. Shut down pumping and drop bottom plug. Mix and pump 615 bbls lead slurry at 10.7 ppg followed by 155 bbls tail slurry at 12.0 ppg. Pump rate while mixing 6 bpm at 100 psi. Reciprocate casing at Up wt 320K, Dn wt 190K with full returns. 06:00 - 08:30 2.50 CEMENT DISP SURFAC Stop pumping. Drop top plug. Cementers pump 20 bbls FW behing plug. Shut down cementers. Switch to rig mud pump. Displace cement at 3-5 bpm, ICP 420 psi, FCP 1,235 psi. Bump plug with 1,735 psi on calculated strokes. Hold pressure for 10 min. Bleed off pressure. Floats held. CIP at 08:30 hrs. Land casing after 260 bbl displaced. Observed full returns during displacement. 200 bbls cement returned to surface. 08:30 - 10:30 2.00 CEMENT PULD SURFAC Flush riser with FW, Break out and lay down cement head and landing joint. Clear rig floor. 10:30 - 10:45 0.25 WELCTL SFTY SURFAC PJSM on N/D Divertor System. 10:45 - 14:00 3.25 WELCTL NUND SURFAC N/D flow line and riser. Remove from cellar area. Flush Knife valve and Hydril Annular with FW. Observed hydrates breaking out from 10-3/4" X 16" annulus. 14:00 - 16:00 2.00 WELCTL OBSV SURFAC P/U 10-3/4" Landing joint and stab into casing hanger. Monitor and observe hydrates breaking out from 1 0-3/4" x 16" annulus. 16:00 - 16:15 0.25 WELCTL SFTY SURFAC PJSM, Review CPAI shallow gas flow procedure with rig crews. 16:15 - 23:00 6.75 WELCTL OBSV SURFAC Monitor and observe hydrates breaking out from 10-3/4" x 16" annulus. Hydrates steadly diminished. Annulus observed to be static. 23:00 - 00:00 1.00 WELCTL NUND SURFAC Lay down 10-3/4" landing joint. Prepare to N/D hydril annular. 5/20/2005 00:00 - 02:00 2.00 CASE NUND SURFAC N/D 21-1/4" Diverter System. 02:00 - 04:00 2.00 CASE NUND SURFAC N/U FMC Gen 5 Wellhead Equipment. Test seals to 1,000 psi for 10 min. OK. 04:00 - 04:15 0.25 WELCTL SFTY SURFAC PJSM, Review DDI N/U & Test BOPE Procedure. 04:15 -10:30 6.25 WELCTL NUND SURFAC N/U BOPE. 10:30 -11:30 1.00 WELCTL BOPE SURFAC RIU equipment to test BOPE. 11 :30 - 20:00 8.50 WELCTL BOPE SURFAC Test BOPE per AOGCC Regs, Approved Drilling Permit, & CPAI Drilling Policy. Test pressures were 250 psi and 3,500 psi. All test pressures held for 5 min and charted on test recorder. AOGCC PI Chuck Scheve, CPAI Senior Drilling Supervisor Fred Herbert, and DDI Senior Toolpusher Ron Matteson witnessed BOPE test. 20:00 - 21 :00 1.00 DRILL PULD SURFAC Lay down 8" flex collars from derrick. 21:00 - 21:15 0.25 DRILL SFTY SURFAC PJSM on picking up BHA #3. 21:15-23:00 1.75 DRILL PULD SURFAC M/U 9-7/8" bit and BHA # 3 23:00 - 23:45 0.75 DRILL DEQT SURFAC Load MWD/LWD. Dir/Gr/Res/PWD. 23:45 - 00:00 0.25 DRILL TRIP SURFAC RIH with BHA #3 to 1,020'. 5/21/2005 00:00 - 00:45 0.75 DRILL TRIP SURFAC P/U 9 jts 5" drillpipe, RIH to 1,290'. Printed: 7/512005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/21/2005 00:45 - 01 :30 0.75 DRILL DEQT SURFAC Circulate and condition mud. Shallow test MWD tool, OK. 01 :30 - 03:45 2.25 DRILL TRIP SURFAC P/U 90 jts 5" drillpipe, RIH to 4,000'. 03:45 - 04:30 0.75 DRILL TRIP SURFAC RIH with 5" drillpipe from the derrick to 5,511'. 04:30 - 05:45 1.25 DRILL OTHR SURFAC M/U Top Drive, Break circulation. Wash down to TOC at 5,570'. Circulate and condition mud for casing test. 05:45 - 06:00 0.25 CASE MIT SURFAC RIU to test casing. 06:00 - 07:00 1.00 CASE MIT SURFAC Test 10-3/4" casing to 2,500 psi. Pressure bled back to 2,485 psi. Held for 30 min. OK. RID test equipment. 07:00 - 10:30 3.50 DRILL DRLG SURFAC Drill cement, float equipment, and 20' new hole to 5,710'. 10:30 - 13:00 2.50 DRILL CIRC SURFAC Circulate and condition mud. Change mud system over to 9.5 ppg LSND. 13:00 -14:30 1.50 DRILL LOT SURFAC Perform LOT as per CPAI FIT/LOT Procedure. EMW = 14.6 ppg at 9.5 ppg 5,680'MD, 4,505'TVD. Surface pressure of 1,200 psi observed at leak off. 14:30 - 00:00 9.50 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 5,710' to 6,640' MD /5,130' TVD. AST = 1.06 hrs, ART = 5.51 hrs, ADT = 6.57 hrs, Avg. ROP = 145 fph. Up wt = 220K, Dn wt = 160K, Rt Wt = 180K. Pump pressure = 3,300 psi at 650 gpm. Top Drive RPM = 100, MM RPM = 215. RT Torq = 11-18K. 5/22/2005 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 6,642' MD ( 5,130' TVD ) to 8,263' MD ( 6,202' TVD). AST = 4.28 hrs, ART = 10.37 hrs, ADT = 14.65 hrs, Avg. ROP = 115 fph. Up wt = 275K, Dn wt = 175K, Rt Wt = 195K. Pump pressure = 3,450 psi at 650 gpm. Top Drive RPM = 100, MM RPM = 215. RTTorq = 11-18K. 5/23/2005 00:00 . 20:30 20.50 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 8,283' MD (6,202' TVD) to 9,112' MD ( 6,535' TVD ) Up wt = 245K, Dn wt = 165K, RT wt = 200K, AST = 4.58 hrs, ART = 2.74 hrs, ADT = 7.32 hrs. Avg. ROP = 113 fph. Top Drive RPM = 100. MMRPM = 215. RT Tq = 12·20K. Pump Pressure = 3,500 psi at 600 gpm. K-1 marker at 8,712' MD (6,429' TVD ). 20:30 - 21 :30 1.00 DRILL CIRC INTRM1 Circulate Btms up sample for Geologist. 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 9,112' MD (6,535' TVD ) to 9,150' MD ( 6,542' TVD ) Up wt = 240K, Dn wt = 170K, RT wt = 200K, AST = 1.01 hrs, ART = .84 hrs, ADT = 1.85 hrs. Avg. ROP = 21 fph. Top Drive RPM = 100. MMRPM = 215. RT Tq = 12-20K. Pump Pressure = 3,290 psi at 580 gpm. 5/24/2005 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Drill and Survey 9-7/8" OH from 9,150' MD (6,535' TVD )to 9,160' MD Up wt = 240K, Dn wt = 170K, RT wt = 200K, AST = .3 hrs, ART =0 hrs, ADT = .3 hrs. Avg. ROP = 30fph.Pump Pressure = 3,290 psi at 580 gpm. 00:30 - 02:00 1.50 DRILL CIRC INTRM1 Circulate and condition hole F/short Trip. 02:00 - 06:00 4.00 DRILL WIPR INTRM1 Trip out hole T/ Shoe @ 5680' 06:00 - 07:30 1.50 RIGMNT RSRV INTRM1 Rig servo Grease crown - Top Drive - Monitoir well 07:30 - 09:30 2.00 DRILL WIPR INTRM1 Trip in Hole (slowly) Taking wieght @ 8850'. 09:30 - 12:00 2.50 DRILL REAM INTRM1 Wash & Ream F/8,830' - T/9, 160' 12:00 - 15:30 3.50 DRILL CIRC INTRM1 Circ, & Condition Pump 44 bbl Wieghted Sweep, Spot 120bbl pill on Btm. 15:30 - 17:00 1.50 DRILL TRIP INTRM1 Trip Out Hole Work through Tight hole @ 8,830' - 8,735' Pull 1 0 stands. 17:00 - 17:30 0.50 DRILL CIRC INTRM1 Monitior well, Pump Dry Job, Blow down 17:30 - 22:30 5.00 DRILL TRIP INTRM1 Trip Out Hole Monitior well @ Shoe and BHA 22:30 - 23:30 1.00 DRILL TRIP INTRM1 Stand back Heavy Wieght Drill Pipe, UD jars, Collars, 23:30 - 00:00 0.50 DRILL DEQT INTRM1 Down Load Directional Tools (MWD) 5/25/2005 00:00 - 02:00 2.00 DRILL SURV INTRM1 Clean Tools and UD MWD & MTR. 02:00 - 03:30 1.50 CASE OTHR INTRM1 Close blind rams circ through mud cross monitoir well. Change Top Printed: 7/512005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/25/2005 02:00 - 03:30 1.50 CASE OTHR INTRM1 rams T/ 7 5/8. No gain/loss during ram change. 03:30 - 07:00 3.50 CASE OTHR INTRM1 Pull wear ring,Set test plug, Problem setting test plug wash and flush, RIU test top Rams 250psi. low, 3,500high 5 min each chart and witness.UD test joint & test plug, Clean and clear floor area. 07:00 - 07:30 0.50 RIGMNT RSRV INTRM1 Rig Service 07:30 - 09:00 1.50 RIGMNT RGRP INTRM1 Work on Rig, Drawworks Brake Coolant Line 09:00 - 09:30 0.50 CASE SFTY INTRM1 Pre Job Safety Meeting with crews and support on running 7 5/8 csg. 09:30 - 12:00 2.50 CASE RUNC INTRM1 Finish rigging up to run 7 5/8 - 29.7# - L-80 - Mod Csg. P/U Shoe jt. Fill and Check float 1 jt above float jt OK. RIH W/ 7 5/8 csg. 12:00 - 12:30 0.50 CASE OTHR INTRM1 Laydown franks Circ. Tool, Replace O-Ring. 12:30 - 18:00 5.50 CASE RUNC INTRM1 Run 7 5/8-29.7#- L80-Mod Csg. 133jts Csg. T/10 3/4 shoe 18:00 - 20:00 2.00 CASE CIRC INTRM1 Circulate and condition mud. 20:00 - 00:00 4.00 CASE RUNC INTRM1 Run in Hole 7 5/8-29.7#- L-80- Mod Csg. to 9110' Fill every joint and record P/U and S/O every 10 joints. Break circ, above recorded tight spot @ 8,750' precautionary. No problems. 5/26/2005 00:00 - 01 :00 1.00 CASE RUNC INTRM1 P/U landing Jt. and hanger wash down, Land Out @ 9,153'. Up wt.280 - Dn Wt. 160. UD Franks Circ. Tool. M/U Cmt. Head. 01 :00 - 04:00 3.00 CASE CIRC INTRM1 Circulate and condition mud for cement job. Start @ 3 bbls min and stage up to 6 bbls per min. 685psi. Up Wt, 280 Dn Wt. 160. Recipacating pipe. PJSM onn CMT job. 04:00 - 06:00 2.00 CEMENT PUMP INTRM1 Pump 2bbls water - Press test 3500psi. - 30 bbls CW100 wash - 50 bbls 12.5 ppg. Mud Push XL spacer - 51 bbls G cement (255sx) 15.8 ppg. - 10 bbls Water - Displace with 395 bbls 10.1 ppg @ 6.5 bpm slowed T/ 3 bpm 11 bbls total mud pumped 406 bbls. Bumped plug 650 psi. Pressured up to 1,200psi. Check floats CIP @ 0600 hrs 06:00 - 08:30 2.50 CEMENT RURD INTRM1 RID CMT Head, Csg, Elevators, Landing Jt, Clean and break down franks Circ, tool, Change Bails 08:30 - 09:30 1.00 CASE OTHR INTRM1 Drain stack & Flush, Set Pack Off, Test pack off seals T/5,000psi. F/ 10min. 09:30 - 11 :30 2.00 DRILL OTHR INTRM1 Change Rams, Install Variable 31/2" x 6" in Top and 4" Bottom, 11 :30 - 12:00 0.50 RIGMNT RSRV INTRM1 Rig Service 12:00 - 18:00 6.00 DRILL PULD INTRM1 PJSM - UD 5" Drill Pipe from derrick 159 jts. 18:00 - 21 :30 3.50 DRILL PULD INTRM1 PJSM - UD 5" Drill Pipe. 102 jts. 21 :30 - 23:30 2.00 DRILL OTHR INTRM1 Change Out Saver sub & Bell guide on top Drive T/ 4" XT 39. . 23:30 - 00:00 0.50 DRILL OTHR INTRM1 P/U all 4" Test Equipment & Handling Equipment to Rig floor. 5/27/2005 00:00 - 01 :30 1.50 DRILL OTHR INTRM1 RIU test BOP,Run test plug,fiII stack open annulas, 01 :30 - 07:00 5.50 DRILL OTHR INTRM1 TEST BOP Equipment 250 low - 3,500 high, Koomey test, Test all floor valves. 07:00 - 08:30 1.50 DRILL RIRD INTRM1 Rig down test equipment, Pull test plug, Install wear Ring I.D.(7 118"). Blow down Top Drive, Mud Pumps and choke manifold. 08:30 - 15:00 6.50 DRILL SFTY INTRM1 PJSM, P/U 4" Drill Pipe 14.5# S-135 XT-39 15:00 -16:30 1.50 RIGMNT RSRV INTRM1 PJSM, Cut Drill Line (95'), Inspect and adjust Brakes, 16:30 - 19:30 3.00 DRILL PULD INTRM1 Pull Drill Pipe out of hole to Rack back in derrick for drilling. 56 stands. 19:30 - 00:00 4.50 DRILL SURV INTRM1 P/U tools M/U Geo - Pilot and MWD - Program Tool 5/28/2005 00:00 - 00:15 0.25 DRILL SFTY INTRM1 H2S Drill 00:15 - 02:00 1.75 DRILL SURV INTRM1 Pulse test MWD, Load Nukes (PJSM) 02:00 - 03:00 1.00 DRILL PULD INTRM1 M/U BHA (cont.) 03:00 - 04:45 1.75 DRILL TRIP INTRM1 RIH F/Pipe Shed 75 jts. 4" Drill Pipe 14.5# S-135 XT-39 RIH. 04:45 - 06:00 1.25 DRILL SURV INTRM1 Fill pipe, Test MWD, Break in Geo-pilot seals. Rotating 5 RPM. Send Down link 0 deflections and 0 Toolface, Showed 100% deflection, Manually Sent home command still showed 80%.Change jet. P/U WT 110 - DNWt 100 - ROT 105 06:00 - 06:30 0.50 DRILL TRIP INTRM1 P/U 4" Drill Pipe 14.5# S-135 XT-39 Total 91jts. Printed: 7/512005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/28/2005 06:30 - 07:00 0.50 DRILL SURV INTRM1 Test Gee-Pilot 300 gpm, Blow down Top Drive. 07:00 - 08:30 1.50 DRILL TRIP INTRM1 P/U 4" Drill Pipe 14.5# S-135 XT-39,Tota1151 jts. 08:30 - 09:00 0.50 DRILL SURV INTRM1 Test Geo-Pilot 280 gpm, Blow down Top Drive. 09:00 - 12:00 3.00 DRILL TRIP INTRM1 P/U 4" Drill Pipe 14.5# S-135 XT-39,TotaI250 jts. 12:00 - 12:15 0.25 DRILL SFTY INTRM1 H2S Drill 12:15 -13:30 1.25 DRILL TRIP INTRM1 P/U 4" Drill Pipe 14.5# S-135 XT-39,Tota1276 jts. 13:30 - 14:30 1.00 CEMENT DSHO INTRM1 Wash and Ream cement Stringers F/ 9,004' - T /9,045' 14:30 -15:30 1.00 DRILL CIRC INTRM1 Circulate and Condition Mud for Casing Test. 15:30 - 16:30 1.00 CASE MIT INTRM1 RIU test Csg. T/ 3,500psi. F/30 min. Chart and plot. RID test equipment, Test Geo-Pilot skid manifold 16:30 - 22:30 6.00 CEMENTDSHO INTRM1 Drill CMT F/9,045' T/9,060', Drill on float, Drill T/9,153' Drill Shoe @ 9,153. T/9,160' 22:30 - 23:00 0.50 DRILL DRLG I NTRM 1 Drill 20' of new hole F/9,160' - T/ 9,180' 50 RPM 275gpm 2500psi. WOB 6-8 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Circulate and Condition mud for FIT- LOT, 5/29/2005 00:00 - 01 :00 1.00 DRILL FIT INTRM1 Perform FIT as per CPAI FIT/LOT Procedure. EMW = 12.6ppg at 10 ppg 9180'MD, 6,543' TVD. Surface pressure of 900 psi. 01 :00 - 03:00 2.00 DRILL CIRC PROD Change Mud out F/1 0 ppg LSND @ 250 GPM Up WT. 215, DN WT. 135, ROT WT. 156. T/ Flow Pro 9.2 ppg. Flush all lines, Displace well 35 bbllow vis-35 bbl high vis-Flow pro, New SPR. #2 MP 20spm-780psi., 30spm - 980 psi. New Wt With 9.2 flow pro., @ 250 GPM UP WT. 155, DN WT. 150, ROT. 150. 03:00 - 03:30 0.50 DRILL OTHR PROD Shut down Monitior and clean Shakers install screens and clean surface equipment. 03:30 - 13:30 10.00 DRILL DRLG PROD Drill 6 3/4" OH from 9,180' MD ( 6,543' TVD ) to 9,700' MD, Up wt = 180, Dn wt = 140, RTwt =150, Bit Hrs = 6.77 hrs, Avg. ROP = ??fph.Pump Pressure = 2200 psi at 285 gpm. APIG = 52' per hr. 13:30 - 16:00 2.50 DRILL CIRC PROD Work on GEO-PILOT and Replace Manifold, Decision made GEO - PILOT failed TOOH. 16:00 - 16:30 0.50 DRILL TRIP PROD Monitior Well, T.O.O.H. T /9,050' 16:30 - 17:30 1.00 DRILL CIRC PROD Monitoir Well, Pump Dry Job, Blow down Top Drive. 17:30 - 22:00 4.50 DRILL TRIP PROD T.O.O.H. - Recording up and down wts Every 5 stands. 22:00 - 22:15 0.25 DRILL OBSV PROD Monitior Well @ Heavy Wieght, 22: 15 - 00:00 1.75 DRILL TRIP PROD PJSM - Work BHA,Remove Radioactive source, Download MWD. 5/30/2005 00:00 - 01 :00 1.00 DRILL SURV PROD Down Load MWD- UD GEe. Pilot 01 :00 - 03:30 2.50 DRILL SURV PROD PJSM; P/U 5" Motor W/1.22 deg. Bend Flow Rates 250-300 gpm, .77 brev. M/U Bit. Orientate and upload MWD and Load Sources.P/U BHA T/406', Shallow test 03:30 - 08:00 4.50 DRILL TRIP PROD T.I.H. Fill Pipe every 25 stands. 08:00 - 00:00 16.00 DRILL DRLG PROD Drill 6 3/4" OH F/9,700' MD T / 10,220' MD, Up wt =190, Dn wt = 145, RT wt =155, Bit Hrs = 13.69 hrs, ADT 9.75 hrs. AST = 5.00, ART = 4.75 hrs. Jar hrs.13.57 Pump Pressure = 2700 psi at 290 gpm. APIG =38' per hr. ROP = 62' per. 5/31/2005 00:00 - 03:30 3.50 DRILL DRLH PROD Drill 6 3/4" OH F/10,310' MD T / 10,336' MD, Up wt =180, Dn wt = 140, RT wt =155, Bit Hrs = 13.69 hrs, ADT 21.96 hrs. AST = 7.95, ART = 5.01 hrs. Jar hrs.19.74 Pump Pressure = 2700 psi at 290 gpm. APIG = 32.6 per Hr. Sliding straight down to get back in C sands. 03:30 - 04:30 1.00 DRILL TRIP PROD Pump out hole to 10,060' 04:30 - 14:30 10.00 DRILL OTHR PROD Open Hole Side track @ 10,060' Orient toolface down and start sidetrack. 68 spm = 289 gpm, 2,350 psi. UP WT. 170, DN WT. 135. 14:30 - 23:00 8.50 DRILL TRIP PROD Monitor Well, TOOH T/Shoe. Monitor @ shoe 9,153'. Pump Pill, TOOH T/ 5,050' crew change monitor well, TOOH to BHA. Monitior Well, Work BHA PJSM remove Radioactive source, Down load MWD, and Upload Printed: 7/5/2005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 5/31/2005 14:30 - 23:00 8.50 DRILL TRIP PROD for TIH. 23:00 - 00:00 1.00 DRILL PULD PROD UD 1.22 Motor, P/U New Motor Change T/1.5 deg. R.R. Bit HYC DS 111 6/1/2005 00:00 - 00:30 0.50 DRILL TRIP PROD Shallow test MWD and Load Nuclear source 00:30 - 01 :00 0.50 DRILL TRIP PROD TIH W / BHA. 01 :00 - 05:30 4.50 DRILL TRIP PROD TIH fill every 25 stands T/9,1 04' 05:30 - 07:00 1.50 RIGMNT RSRV PROD PJSM - Cut and slip 85' Drlg line. 07:00 - 08:00 1.00 RIGMNT RSRV PROD Service Rig, Top Drive, Grease Crown 08:00 - 13:30 5.50 RIGMNT RGRP PROD Repair Brake cooling lines and brake pad 13:30 - 14:45 1.25 DRILL TRIP PROD Trip In Hole to 10,040' 14:45 - 23:30 8.75 DRILL OTHR PROD Orient tool to 160 R begin sliding and troughing 10,040' - 10,090'. Start time drilling @ 147R T /10,107' 23:30 - 00:00 0.50 DRilL DRLG PROD Drlg Ahead F /10,107' - T /10,120' Pump press=2,366 psi. off btm. 2,500 psi. on btm. Up Wt. 180, DN Wt. 135. Slide hrs .5 ADT. New survey @ 10,131' 88.21. Old Survey @ 10,173' 92.55 6/2/2005 00:00 - 02:15 2.25 DRILL DRLH PROD Drill horizontal section from 10120' to 10223'. AST=.81 hr. ART=.85 hr. TST=1.31, TRT=.85, P/U=180k, S/O=140k, 69 spm 298 gpm @ 2400 psi on bottom/2300 psi off bottom. 02:15 - 02:45 0.50 DRILL WIPR PROD Pump out of hole from 10223 to 9944'. Rot 60 rpm. Pump 68 spm 02:45 - 03:15 0.50 DRILL WIPR PROD Orient toolface to highside and wash from 9944' to 10133'. Took weight @ 10107'. Back ream up past 10107'. Reorient to highside and wash w/o rotating past 10107' without taking weight. Wash to 10223' and tag up. Pumping @ 69 spm @ 2440 psi. Max gas=3923 units. 03:15 - 06:00 2.75 DRILL DRLH PROD Drill from 10223' to 10302'. ART=.33, AST=2.47, TRT=1.18, Pumping 70 spm (300 gpm), 2600 psi on bottom, 2400 psi off bottom, P/U =180k, S/O=140K, Rot=150k. 06:00 - 12:00 6.00 DRILL DRLG PROD Drill from 10302' to 10,393' ,6,535 tvd AST= 4, Pumping 70 spm (300 gpm), 2600 psi on bottom, 2400 psi off. bottom, P/U =180k, S/O=140K, Rot=150k. 12:00 - 13:30 1.50 DRILL DRLH PROD Drill from 10,393' to 10,410', 6,535 tvd AST= .94, Pumping 70 spm (298 gpm), 2300 psi on bottom, 2100 psi off. bottom, P/U =180k, S/O=135K, Could not drop angle. 13:30 - 14:30 1.00 DRILL TRIP PROD POOH to new side track depth, 9,630' UP WT. 180k - DN WT. 135k 14:30 - 22:30 8.00 DRILL OTHR PROD Orientate 180 deg. Trough F/9,600' - T/9,630', Start time Drilling for kick off. 9,630'. - 9,642' Slide 160deg. slide 9,661 in old no side track. 22:30 - 23:15 0.75 DRILL OTHR PROD Re-Check surveys look at first hole log. Suggest alternate K.O.P. up hole @ 9,600'. 23:15 - 00:00 0.75 DRILL OTHR PROD Start troughing @ 9,568' to 9,600' 180 deg. Start Kick Off. @ 9,600' 6/3/2005 00:00 - 05:45 5.75 DRILL OTHR PROD Side track - Time Drilling to sidetrack well F /9,600-9,630' @ 161r Orientation. No side track obtained 05:45 - 06:30 0.75 DRILL TRIP PROD Pump Out of hole, 06:30 - 07:15 0.75 DRILL CIRC PROD Monitoir well, drop ball to open CCV. opened circ. sub 2,800 psi. Pump Dry Job. 07:15 -11:30 4.25 DRILL TRIP PROD Trip out of Hole. tI HWDP, Monitior well 11 :30 - 14:00 2.50 DRILL TRIP PROD Trip out HWDP. PJSM on handling Nuclear source, Work BHA 14:00 - 16:45 2.75 DRILL SURV PROD Change Motor bend T/1.83 deg. M/U new Bit FM 2643. Orient, Upload MWD, Shallow test, load Nuclear sources. P/U BHA. 16:45 - 20:30 3.75 DRILL TRIP PROD T.I.H. Fill every 25 stands 20:30 - 21 :00 0.50 RIGMNT RSRV PROD Rig service-Grease Crown, Lubricate and check. 21 :00 - 21 : 15 0.25 DRILL TRIP PROD Cont. Trip in hole 21:15 -21:45 0.50 DRILL OTHR PROD Orientate tool face to 150r Trough 70 spm = 2300psi. 21 :45 - 00:00 2.25 DRILL OTHR PROD Start kick off - Time slide 70 spm = 2300psi off btm - 2350 psi. on btm. High gas units 4179 from btms up. Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/4/2005 00:00 - 03:30 3.50 DRILL DRLH PROD 03:30 - 03:45 0.25 DRILL SURV PROD 03:45 - 05:45 2.00 DRILL DRLH PROD 05:45 - 06:15 0.50 DRILL REAM PROD 06:15 - 06:30 0.25 DRILL OTHR PROD 06:30 - 18:00 11.50 DRILL DRLH PROD 18:00 - 00:00 6.00 DRILL DRLH PROD DRILL PROD 6/5/2005 00:00 - 05:30 05:30 - 07:15 07:15 - 07:30 07:30 - 08:30 08:30 - 18:00 18:00 - 00:00 6/6/2005 00:00 - 18:00 5.50 DRILL DRLH PROD 1.75 DRILL WIPR PROD 0.25 RIGMNT RSRV PROD 1.00 DRILL WIPR PROD 9.50 DRILL DRLH PROD 6.00 DRILL DRLH PROD 18.00 DRILL DRLH PROD 18:00 - 20:00 2.00 DRILL CIRC PROD 20:00 - 00:00 4.00 DRILL OTHR PROD 6/7/2005 00:00 - 18:00 18.00 DRILL DRLG PROD Time slide Kick Off F/9,605' - T/9,630', TVD 6,547 70 spm = 2300psi off btm - 2350 psi. on btm. Survey - Confirm new hole @ 9,630' Old hole 90.85 incl. 106.55 azm. interpolated. Side Track hole 87.16 incl. 108.32 azm. Drill 6 3/4" OH F/9,630" MD T /9,755' MD, Up wt =180, Dn wt = 135, RT wt =150, Pump Pressure = 2300 psi. off Btm, 2,350 psi. on Btm @ 300 gpm. Jar hrs 49.59, ADT=6.66(lncluding time drill). ART= .94 AST= 5.72. Max Gas 2,903' Back Ream out of hole F/9,755 - T /9,572'. Orient high side, Challenge side trac, No Problems, Drill 6 3/4" OH F/9,755 MD T /10,693' MD, Up wt =180, Dn wt = 135, RTwt =150, Pump Pressure = 2,750 psi. off Btm, 3,100 psi. on Btm @ 335 gpm. Jar hrs 56.74, ADT=7.05 ART= 6.05 AST= 1. Drill 6 3/4" OH F/10,693 MD T /11063' MD, Up wt =180, Dn wt = 135, RTwt =150, Pump Pressure = 2,750 psi. off Btm, 3,100 psi. on Btm @ 335 gpm. Jar hrs 60.55, ADT= 3.81 ART= 3.12 AST= .69 Total Hours on Bit #7 TST=7.51 TRT=10.11TBT=17.62. SPR @ 10,880' MD - 6,535' TVD.-MW - 9.2 ppg. #1pump 20 spm-550psi.30spm-740 psi.#2 pump 20 spm-550psi.30 spm-720psi. GEO-Very fine Sand and traces of Siderite. Drill 6 3/4" OH F/11 063 MD T /11439' MD, TVD 6,586' Up wt =180, Dn wt = 135, RT wt =160, Tq on btm 7k, Torq off btm 5k, WOB 5~ 15k, Rpm 55, Pump Pressure = 2,750 psi. off Btm, 3,100 psi. on Btm @ 335 gpm. Jar hrs 60.76, ADT= 3.81 ART=2.61 AST= .60 APIG= 72.36' per hr. - 1,809' - 25 hrs. Pump Out Of Hole F/11 ,439' - T /9,575', Monitior well, Service Blocks, Wash Pipe Trip in hole T/11 ,441 and record SPR. Wash to btm. Drill 6 3/4" OH F/11 ,439' MD T /12,125' MD, TVD 6,550' Up wt =190, Dn wt = 130, RT wt =155, Tq on btm 9k, Torq off btm 5-6k, WOB 5-15k, Rpm 55, Pump Pressure = 2,980 psi. off Btm, 3,240 psi. on Btm @ 335 gpm. JAR HRS 69.58, ADT= 3.81 ART= 3.12 AST= 1.35 APIG= 72.32' per hr. - New hole 2495' -34.5 hrs. Drill 6 3/4" OH F/11 ,439' MD T /12,336' MD, TVD 6,550'Up wt =190, Dn wt = 125, RT wt =155, Tq on btm 9k, Torq off btm 5-6k, WOB 5-15k, Rpm 55, Pump Pressure = 3000 psi. off Btm, 3,200 psi. on Btm @ 338 gpm.JAR HRS. 72.58, ADT= 3.01 ART= 1.58 AST= 1.43 APIG= 66.81' per hr. - New hole 2,706' -40.5 hrs. Drill 6 3/4" OH F/11 ,439' MD T /12,933' MD, TVD 6,542'Up wt =205, Dn wt =120, RTwt =155, Tq on btm 9k, Torq offbtm 7·6k, WOB 5-15k, Rpm 60, Pump Pressure = 3160 psi. off Btm, 3,450 psi. on Btm @ 338 gpm.JAR HRS. 80.05 ADT= --- ART= --AST= -- APIG= 56.46' per hr. - New hole 3,303' -58.5 hrs. Work Pipe and Circ,F /12,933' - T/12,469', Out of C sands seeing low resistivity and shale in samples Look at the Geology and discuss Team Leaders, Decision made to side track. Side Track - Start troughing F/12,560' - T/12,595' Start Time Drilling at 12,595' - T/12,604' 156r Drill and survey 6-3/4" OH from 12,605' MD (6,558' TVD) to 13,508' MD ( 6,499' TVD ). AST = 3.94 hrs, ART = 5.62 hrs, ADT = 9.56 hrs. Printed: 7/512005 4:13:27 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-21 1C-21 ROT - DRILLING D15CM@conocóphillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/7/2005 00:00 - 18:00 18.00 DRILL DRLG PROD Avg. ROP = 95 fph. Up wt. 205K, SOW 125K, ROT Wt 160K. Tq on Btm 10K, Tq off Btm 8K, at 60 rpm. Pump at 80 spm, 335 gpm 3,200 psi. SPR = Pump #1 20 spm 710 psi, 30 spm 950 psi, Pump #2 20 spm 730 psi, 30 spm 1,030 psi. 18:00 - 19:00 1.00 DRILL CIRC PROD HP hose on mud pump failed. Jumper hose on Mud Pump #1 leaked spilling approximately 1 bbl of mud in pump room. Hose was replaced and spill cleaned up. KRU security was notified. No fluid escaped out of containment. PIR completed. 19:00 - 19:15 0.25 DRILL OBSV PROD Monitor well, slight flow observed. 19:15 - 21 :45 2.50 DRILL CIRC PROD Circulate and condition mud. Weight up mud to 9.4 ppg for trip. 21 :45 - 22:00 0.25 DRILL OBSV PROD Monitor well, static. 22:00 - 00:00 2.00 DRILL WIPR PROD Pump out of hole from 13,508' MD to 11,722' MD. Good hole conditions. 6/8/2005 00:00 - 03:15 3.25 DRILL WIPR PROD Pump out of hole from 11,722' MD to 9,104' MD. 7-5/8" casing shoe. 03:15 - 03:30 0.25 DRILL OBSV PROD Monitor well, static 03:30 - 05:00 1.50 DRILL CIRC PROD Drop opening ball, pump down at 2 bpm 500 psi. Open CCV with 2,600 psi. Circulate and condition mud until clean returns observed at shakers. 05:00 - 07:00 2.00 RIGMNT RSRV PROD Cut and slip drlg line. Service rig. Monitor well, static. 07:00 - 08:00 1.00 DRILL CIRC PROD Drop closing ball. Pump at 3 bpm 710 psi. Close CCV at 2,800 psi. Pulse test MWD, OK. 08:00 - 09:30 1.50 DRILL TRIP PROD RIH with drill pipe from derrick to 12,096'. 09:30 - 09:45 0.25 DRILL CIRC PROD Fill pipe 80 spm 2,700 psi. Blow down top drive. 09:45 - 11 :30 1.75 DRILL PULD PROD P/U 6 jts drill pipe and 39 jts HWDP from pipe shed. RIH to 13,463. 11 :30 - 12:00 0.50 DRILL CIRC PROD M/U top drive, fill pipe. Record SPR's. Orient Bit. 12:00 - 14:00 2.00 DRILL DRLG PROD Drill and Survey 6-3/4" OH from 13,508' MD ( 6,499' TVD ) to 13,650' MD ( 6,601' TVD ). AST = .57 hrs, ART = 1.1 hrs, ADT = 1.67 hrs. Pump at 340 gpm, 3,010 psi on btm, 2,800 psi off btm. Up wt 21 OK, SOW 130K, Rt wt 160K. 14:00 - 15:00 1.00 DRILL TRIP PROD Lost 250 psi pump pressure. Trouble shoot pressure loss. Suspect CCV not fully closed. POH, pump out to 13,545' MD. 15:00 - 15:45 0.75 DRILL CIRC PROD Drop opening ball. Pump at 2 bpm. Open CCV at 2,730 psi. 15:45 - 16:45 1.00 DRILL CIRC PROD Drop closing ball. Pump at 2 bpm. Close CCV at 2,650 psi. 16:45 - 17:00 0.25 DRILL TRIP PROD RIH to 13,650'. M/U top drive. Break circulation. Pulse test MWD. OK. 17:00 - 00:00 7.00 DRILL DRLG PROD Drill and Survey 6-3/4" OH from 13,650' MD (6,601' TVD) to 14,149' MD ( 6,567' TVD ). AST = .25 hrs, ART = 3.62 hrs, ADT = 3.87 hrs. Pump at 340 gpm, 3,240 psi on btm, 2,900 psi off btm. Up wt 210K, SOW 130K, Rtwt 160K. 60 rpm. Tq on btm = 10K, Tq offbtm = 8K. 6/9/2005 00:00 - 00:30 0.50 DRILL DRLH PROD Drill horizontal section. Make connection and pump lube pill 00:30 - 01 :00 0.50 DRILL OTHR PROD Investigate pressure loss. Pressure test surface lines to 4000 psi-Ok Monitor well-static 01 :00 - 06:00 5.00 DRILL TRIP PROD Pump out of hole from 14149' to 9572' 06:00 - 07:15 1.25 DRILL TRIP PROD Pump out of hole from 9572' to 9100' 07:15 - 08:15 1.00 DRILL CIRC PROD Circulate bottoms up 08:15 - 10:15 2.00 DRILL CIRC PROD Monitor well-slight flow. Circulate and raise mud weight to 9.5 ppg. 10:15 - 12:00 1.75 DRILL TRIP PROD Monitor well-flow reduce but still flowing. RIH to 11515' 12:00 -13:00 1.00 DRILL TRIP PROD Continue tripping in hole. Tag up @ 12848'. Took check shot survey and confirmed in old hole. 13:00 - 13:30 0.50 DRILL TRIP PROD Pump out of hole to 12545' 13:30 -15:15 1.75 DRILL CIRC PROD Circulate and condition mud. Insure entire system is weighted up to 9.5 ppg 15:15 -16:30 1.25 DRILL TRIP PROD Monitor well-static. Pump out of hole to 11722'. P/U=190k, S/0=125k Printed: 7/5/2005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/9/2005 16:30 - 20:00 3.50 DRILL TRIP PROD Monitor well-static. Pump out of hole to shoe @ 9153' 20:00 - 20:30 0.50 DRILL CIRC PROD Monitor well, static. Pump dry job. Blow down top drive. 20:30 - 00:00 3.50 DRILL TRIP PROD POH on elevators to HWDP. Proper hole fill observed. Break out and lay down CCV. Inspect circ sub. Internal valve washed out. 6/10/2005 00:00 - 00: 15 0.25 DRILL OBSV PROD Monitor well, Static 00:15 - 01:30 1.25 DRILL TRIP PROD POH, stand back HWDP, Jars, and flex drill collars. 01 :30 - 01 :45 0.25 DRILL SFTY PROD PJSM on removing source from LWD tool. 01 :45 - 02:00 0.25 DRILL PULD PROD HES crew removed source from LWD tool. 02:00 - 03:00 1.00 DRILL SURV PROD Download MWD tool. 03:00 - 03:45 0.75 DRILL PULD PROD Stand back MWD tool, break out and lay down bit and motor. 03:45 - 04:45 1.00 DRILL PULD PROD Latch up MWD tool. Make service breaks and lay down tool in pipe shed for battery change out. 04:45 - 05:30 0.75 DRILL PULD PROD Drain BOP stack, P/U test jt. M/U wear ring retrieving tool. Pull wear ring. M/U test plug and set in wellhead. 05:30 - 06:30 1.00 DRILL RIRD PROD RIU BOPE test equipment. Fill stack and choke manifold with water. 06:30 - 10:00 3.50 WELCTL BOPE PROD Test BOPE per CPAI & AOGCC procedures. Test pressures 250 low and 3,500 hi as per Drilling Permit. Test charted and witnessed by CPAI Drilling Rep and DDI Tool Pusher. Chuck Scheve, AOGCC PI, waived witnessing test. 10:00 - 11 :00 1.00 DRILL RIRD PROD Pull test plug, set wear ring. Monitor well, static. 11 :00 - 13:00 2.00 WELCTL BOPE PROD Pressure test all valves on choke manifold to 250/3,500 psi. Blow down choke maniflod. Line up valves for drilling. 13:00 - 14:00 1.00 RIGMNT RSRV PROD Service rig. Change oil in top drive unit. 14:00 - 15:00 1.00 RIGMNT RSRV PROD Change out top drive saver sub. 15:00 - 15:15 0.25 DRILL SFTY PROD PJSM on picking up BHA # 8. 15:15 - 20:00 4.75 DRILL PULD PROD M/U BHA # 8. 20:00 - 22:00 2.00 DRILL PULD PROD M/U MWD tool. Failed surface test. Change out MWD tool. Retest at surface .OK. 22:00 - 22:30 0.50 DRILL PULD PROD Load sources in LWD Tool, RIH flex collars, HWDP, and jars. 22:30 - 00:00 1.50 DRILL TRIP PROD RIH with dp to 3,203' MD. M/U top drive. Fill drill pipe. Shallow test MWD tool, OK. 6/11/2005 00:00 - 01 :00 1.00 DRILL TRIP PROD RIH with BHA # 8 to 6,008'. Stop to take check shot with MWD tool. 01:00-01:15 0.25 DRILL SURV PROD Unable to take check shot with MWD. Cycle pumps. Surface computer I problem. MWD operator reestablished communication with MWD tool. Check shot OK. 01:15 - 02:45 1.50 DRILL TRIP PROD RIH with BHA # 8 to 9,279' 02:45 - 04:00 1.25 DRILL CIRC PROD Circulate and condition mud at 7-5/8" casing shoe. Observed 35% increase in cuttings at btms up. Continue to circulate until clean returns observed at surface. 04:00 - 04:15 0.25 DRILL OBSV PROD Flow check, well static. Take SPR's for both pumps. 04:15 - 05:15 1.00 DRILL TRIP PROD RIH to 9,780'. Stop and take check shot with MWD. Inadvertently entered old wellbore. POH. Reorient BHA. Enter correct wellbore. Continue to RIH 05:15 - 07:00 1.75 DRILL TRIP PROD RIH with BHA # 8 to 12,545'. Hole in good condition. 07:00 - 07:45 0.75 DRILL CIRC PROD Circulate and condition mud at 12,545'. Rotate and reciprocate pipe. Observed clean returns at btms up. 07:45 - 08:00 0.25 DRILL OBSV PROD Flow check well, static. 08:00 - 08:30 0.50 DRILL TRIP PROD RIH with BHA # 8 to 13,732'. Hole in good condition. 08:30 - 09: 15 0.75 DRILL REAM PROD Precautionary wash and ream to btm at 14,149'. Hole in good condition. 09:15-10:15 1.00 DRILL CIRC PROD Circulate and condition mud at 14,149'. Rotate and reciprocate pipe. Observed clean returns at btms up. 10:15 - 18:00 7.75 DRILL DRLG PROD Drill and survey 6-3/4" OH from 14,149' MD (6,567' TVD) to 14,288' MD ( 6,558' TVD ). Raise lubrication concentration in mud to 4% to help Printed: 7/5/2005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1 C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/11/2005 10:15 - 18:00 7.75 DRILL DRLG PROD with sliding difficulties. Unable to get proper weight transfer through drill string to bit due to hole geometry. AST = 2.29 hrs, ART = .53 hrs, ADT = 2.82 hrs. Up wt. 210K, SOW 120K, Rot wt. 162K. Pump 80 spm, 340 gpm, 3,240 psi on btm, 3,010 psi off btm. ROT 60 rpm, 1 OK tq on btm, 8K tq on btm. Discuss options with Drilling Team Lead, Drilling Engineer, and Geologists. Decision made to trip for Lo-tads. 18:00 - 19:00 1.00 DRILL CIRC PROD Circulate and conditon mud. 19:00 -19:15 0.25 DRILL OBSV PROD Flow check well, slight flow observed. 19:15 - 20:30 1.25 DRILL CIRC PROD Circulate and condition mud. Raise mud weight to 9.5 ppg for trip. 20:30 - 20:45 0.25 DRILL OBSV PROD Flow check well, static. Take SPR's for both pumps. 20:45 - 00:00 3.25 DRILL TRIP PROD POH on elevators from 14,288' to 10,705'. 6/12/2005 00:00 - 01 :45 1.75 DRILL TRIP PROD Pump out of hole to 9,285'. 01 :45 - 02:45 1.00 DRILL CIRC PROD Circulate and condition mud at 7-5/8" casing shoe. 02:45 - 03:00 0.25 DRILL OBSV PROD Flow check well. Static. Pump dry job. 03:00 - 04:45 1.75 DRILL TRIP PROD POH on elevators to 6,101' 04:45 - 08:45 4.00 DRILL TRIP PROD RIH to 9,099', installlo-tads on each stand. 08:45 - 09:00 0.25 DRILL CIRC PROD Fill pipe, Blow down top drive. 09:00 - 10:30 1.50 RIGMNT RSRV PROD Cut and slip 86' drilling line. Inspect break bands on drawwork drum. 10:30 - 11 :30 1.00 RIGMNT RSRV PROD Service rig and top drive. 11 :30 - 16:00 4.50 DRILL TRIP PROD RIH to 14,288'. Install total of 60 lo-tads. Hole in good condition. 16:00 - 18:00 2.00 DRILL CIRC PROD Circulate and condition mud. Observed 5,000 units gas at btms up. Circulate until clean returns observed at surface. 18:00 - 00:00 6.00 DRILL DRLH PROD Drill and survey 6-3/4" OH from 14,288' MD (6,558' TVD) to 14,392' MD ( 6,561' TVD). AST = .81 hrs, ART = 1.44 hrs, ADT = 2.25 hrs. Up wt. 210K, SOW 120K, Rot wt. 162K. Pump 80 spm, 340 gpm, 3,240 psi on btm, 3,010 psi off btm. ROT 60 rpm, 10K tq on btm, 8K tq on btm. 6/13/2005 00:00 - 00:00 24.00 DRILL DRLH PROD Drill and survey 6-3/4" Horizontal OH section from 14,392' MD ( 6,561' TVD) to 14,857' MD (6,546' TVD). AST = 6.71 hrs, ART = 3.21 hrs, ADT = 9.92 hrs. Up wt. 215K, SOW 115K, Rot wt. 168K. Pump 80 spm, 340 gpm, 3,560 psi on btm, 3,250 psi off btm. ROT 60 rpm, 12K tq on btm, 1 OK tq on btm. 6/14/2005 00:00 - 01 :00 1.00 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 14,857' MD to 14,950'MD (6,545' TVD ). ART = .87 hrs 01 :00 - 01 :30 0.50 DRILL CIRC PROD Gas units at 5,000. Circulate and work pipe until gas units below 500. Make connection. Take survey. 01 :30 - 02:00 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 14,950' MD to 14,971' MD ( 6,546' TVD ). ART = .18 hrs 02:00 - 03:30 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. 03:30 - 03:45 0.25 DRILL DRLH PROD Slide at 150 R from 14,971' MD to 14,979' MD. AST = .10 hrs Rotary Drill 6-3/4" hole f/14,979' to 15,011' MD (6546' TVD) ART=.17 hrs. 03:45 - 05: 15 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tool face and slide to bottom. 05:15 - 05:30 0.25 DRILL OBSV PROD Flow check well. Static. Take SPR's. 05:30 - 09:30 4.00 DRILL TRIP PROD POH, circulate and back ream out to 12,855' MD to reposition push pipe in drill string. 09:30 - 11 :00 1.50 DRILL TRIP PROD RIH on elevators to 14,320' MD. 11 :00 - 13:30 2.50 DRILL REAM PROD M/U top drive. Wash and ream from 14,320' MD to 15,011' MD. Pump at 80 spm, 3,560 psi, Up wt. 220K, Dn wt. 11 0-115K, Rt wt. 165K. 13:30 - 15:00 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tool face and slide to bottom. 15:00 - 17:00 2.00 DRILL CIRC PROD Mix up 50 bbl Lube pill. Add in 5 ppb Alpine fine glass beads. Printed: 7/512005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C..,21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/14/2005 17:00 -17:30 0.50 DRILL DRLH PROD Pump lube pill with beads. Work pipe, orient string in attempt to slide. Observed large volume of cuttings at btms up. Shakers blinded off for several minutes. 17:30 - 18:00 0.50 DRILL DRLH PROD Slide at 160 R from 15,011' MD to 15,034' MD. AST = .30 hrs 18:00 - 19:00 1.00 DRILL DRLH PROD Slide at 180 from 15,034' MD to 15,047' MD. AST = 1.00 hrs 19:00 - 20:00 1.00 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 20:00 - 21 :30 1.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,047' MD to 15,139' MD ( 6,544' TVD ). ART = 1.43 hrs 21 :30 - 22:00 0.50 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 22:00 - 22:30 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,139' MD to 15,160' MD ( 6,544' TVD ). ART = .40 hrs 22:30 - 23:15 0.75 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tool face and slide to bòttom. Pump lube pill with beads. Work pipe, orient string in attempt to slide. 23:15 - 00:00 0.75 DRILL DRLH PROD Slide at 180 from 15,160' MD to 15,183' MD (6,545' TVD). AST = .75 hrs 6/15/2005 00:00 - 00:30 0.50 DRILL DRLH PROD Slide at 180 from 15,183' MD to 15,190' MD ( 6,545' TVD ). AST = .50 hrs 00:30 - 01 :15 0.75 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,190' MD to 15,233' MD ( 6,546' TVD ). ART = .65 hrs 01:15-01:30 0.25 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 01 :30 - 02:00 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,233' MD to 15,326' MD ( 6,545' TVD ). ART = .45 hrs 02:00 - 02:20 0.33 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 02:20 - 03:00 0.67 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,326' MD to 15,419' MD ( 6,545' TVD ). ART = .55 hrs 03:00 - 03:30 0.50 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 03:30 - 03:45 0.25 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,419' MD to 15,439' MD ( 6,545' TVD ). ART = .15 hrs 03:45 - 04:00 0.25 DRILL DRLH PROD Slide at 180 from 15,439' MD to 15,450' MD ( 6,537' TVD ). AST = .35 hrs 04:00 - 05:30 1.50 DRILL DRLH PROD Attempt to slide for inclination correction. Work pipe, orient string in attempt to slide. Unable to hold tooí face and slide to bottom. 05:30 - 06:00 0.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,514' MD to 15,450' MD ( 6,537' TVD ). ART = .45 hrs 06:00 - 06:30 0.50 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 06:30 - 10:30 4.00 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,514' MD to 15,603' MD ( 6,535' TVD ). ART = 3.50 hrs 10:30 - 11 :30 1.00 RIGMNT RGRP PROD HP hose on mud pump failed. Jumper hose on Mud Pump #2 leaked spilling approximately 25 gals of mud in pump room. Hose was replaced and spill cleaned up. KRU security was notified. No fluid escaped out of containment. PIR completed. 11 :30 - 12:30 1.00 DRILL DRLH PROD Wash and ream full stand. Make connection. Take survey. 12:30 - 15:00 2.50 DRILL DRLH PROD Rotate drilling 6-3/4" horizontal OH section from 15,603' MD to 15,634' MD ( 6,528' TVD ). ART = 2.50 hrs. TD horizontal section as per onsite geologist. Up wt. 215K, Dn wt. 120K. 15:00 - 15:30 0.50 DRILL CIRC PROD Wash and ream full stand. Make connection. Take survey. 15:30 - 00:00 8.50 DRILL REAM PROD BROOH from 15,634' to 12,186'. Hole taking fluid. Lost a total of 110 bbls. Reduced pump rate from 80 spm to 50 spm to reduce loss rate. Hole in good condition. Pulling pipe at 8-10 min per stand. 6/16/2005 00:00 - 02:45 2.75 DRILL REAM PROD BROOH from 12,186' to 11,415'. Observed torque fluctuation from 11,500' to 11,440', 6K to 12K torque while back reaming. Work pipe, torque at 6K. Rack back stand. Up wt. 190K, Dn wt 130K. Lost 45 bbls Printed: 7/5/2005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1 C-21 ROT - DRILLING D 15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/16/2005 00:00 - 02:45 2.75 DRILL REAM PROD of mud to hole. 02:45 - 06:00 3.25 DRILL REAM PROD M/U top drive. Break circulation. Unable to move drill string up or down. Work pipe at 11,415'. No jar action. Mix and pump 65 bbllube/bead pill. Pump at 215 gpm 1,700 psi. 06:00 - 08:00 2.00 DRILL REAM PROD Regain jar action. Work pipe at 11,415'. Mix and pump 35 bbl 15% concentration lube pill. Spot pill around BHA. 08:00 - 08:45 0.75 DRILL REAM PROD Shut down pumps, allow pill to soak. S/O to 65k w/ no torque in string. 08:45 - 09:30 0.75 DRILL REAM PROD P/U on drill string to 250K allow jars to fire upward. Regain pipe movement. Rotate and reciprocate pipe. 09:30 - 17:30 8.00 DRILL REAM PROD BROOH from 11,390' to 9,153'. Mix and pump 45 bbl sweep. Record up and down weights every 5 stands. Up wt 180K Dn wt 140K. Pump 315 gpm 75 spm at 2,525 psi. Lost 43 bbls of mud to hole. 17:30 - 19:45 2.25 DRILL CIRC PROD Circulate and condition mud. Mix and pump 45 bbl sweep. Observed 15% increase in cuttings at btms up. Continue to circulate until clean returns are observed at shakers. 19:45 - 20:00 0.25 DRILL OBSV PROD Flow check well, Static. 20:00 - 20:15 0.25 DRILL CIRC PROD Pump dry job. Blow down top drive. 20: 15 - 00:00 3.75 DRILL TRIP PROD POH drill pipe on elevators to 680'. Hole taking correct displacement. 6/17/2005 00:00 - 01 :00 1.00 DRILL PULD PROD Stand back HWDP. Lay down jars. Stand back flex DC's. 01:00 - 01:15 0.25 DRILL SFTY PROD PJSM on removing source from LWD. 01 :15 - 02:00 0.75 DRILL PULD PROD Remove source from LWD. 02:00 - 03:00 1.00 DRILL SURV PROD Down load MWD tool. 03:00 - 04:00 1.00 DRILL PULD PROD Lay down MWD/LWD tools. 04:00 - 05:45 1.75 DRILL PULD PROD Inspect Bit. Rerun. Set motor at 1.22 deg. M/U MWD tool. Orient BHA. 05:45 - 07:00 1.25 DRILL TRIP PROD M/U BHA # 9, RIH to 400'. Shallow test MWD, OK. 07:00 - 07:30 0.50 RIGMNT OTHR PROD Inspect Derrick. OK 07:30 - 11 :00 3.50 DRILL TRIP PROD RIH with BHA # 9 for clean out. Take up and down weight readings every 5 stands. 11 :00 - 11 :30 0.50 DRILL SURV PROD M/U Top drive. Pulse test MWD at 7,025. Blow down top drive. 11 :30 - 12:30 1.00 DRILL TRIP PROD RIH to 7-5/8" casing shoe at 9,153' with BHA # 9 for clean out. Take up and down weight readings every 5 stands. 12:30 - 13:00 0.50 DRILL CIRC PROD Circulate and condition mud. Pump at 300 gpm, 70 spm 1,950 psi. Up wt 183K, Dn wt 145K. ROT wt 152K. Torque off btm 4K. 13:00 - 18:45 5.75 DRILL TRIP PROD RIH to 15,579' with BHA # 9 for clean out. Take up and down weight readings every 5 stands. Hole in good condition. 18:45 - 19:00 0.25 DRILL REAM PROD M/U top drive. Wash and ream to btm at 15,634' 19:00 - 20:45 1.75 DRILL CIRC PROD Circulate and condition mud. Observed 2,500 units of gas at btms up. Circulate until gas below 200 units. 20:45 - 23:00 2.25 DRILL CIRC PROD Mix and pump 60 bbl hi-vis sweep at 9.7 ppg, 85 seclot. Observed 10% increase in cuttings at shakers when sweep returns to surface. Circulate until clean returns are observed at surface. 23:00 - 23:15 0.25 DRILL SFTY PROD PJSM on switching over to solids free mud system. 23:15 - 00:00 0.75 DRILL CIRC PROD Displace old mud out of hole. Replace with 9.7 ppg solids free mud system. 6/18/2005 00:00 - 03:30 3.50 DRILL CIRC PROD Displace well to 9.7 ppg solids free flo-pro mud system. 03:30 - 03:45 0.25 DRILL OBSV PROD Flow check well, static. Take SPR's. 03:45 - 11 :30 7.75 DRILL WIPR PROD Pump out of hole from 15,634' to 7-5/8" casing shoe. Hole in good condition. 11 :30 - 12:45 1.25 DRILL CIRC PROD Circulate and condition mud. Pump at 70 spm 1,650 psi. Up wt 175K, Dn wt 145K. 12:45 - 13:00 0.25 DRILL OBSV PROD Flow check well, static. Mix and pump dry job. 13:00 - 18:00 5.00 DRILL TRIP PROD POH with drill pipe on elevators. Hole took proper displacement. Printed: 7/512005 4:13:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/18/2005 18:00 - 19:00 1.00 DRILL PULD PROD Lay down BHA # 9. 19:00 - 19:45 0.75 DRILL PULD PROD Flush out mud motor. Break out and lay down float sub, mud motor, and 6-3/4" PDC bit. 19:45 - 20:15 0.50 DRILL PULD CMPL TN Clear rig floor. 20:15 - 21 :45 1.50 CASE RURD CMPL TN RIU GBR casing tools. Layout running order in pipe shed for 4-1/2" liner. 21 :45 - 22:00 0.25 CASE SFTY CMPL TN PJSM with rig crew and service personnel on running 4-1/2" casing liner. 22:00 - 00:00 2.00 CASE PULR CMPL TN RIH with 4-1/2" 12.6 ppf L-80 IBT slotted and blank casing liner. Space out swell packers. 6/19/2005 00:00 - 04:30 4.50 CASE PULR CMPL TN RIH 4-1/2" 12.6 ppf L-80 IBT liner. Ran 169 jts slotted. 39 jts. blank and 4 swell packers. RIH from 3,774' to 6,600. 04:30 - 05:45 1.25 CASE PULR CMPL TN M/U Baker SBR, Flex Hanger, and Tie-Back Sleeve. RIH to 6,660' Change out to drill pipe elevators. Lay Down GBR casing handling equipment. 05:45 - 13:00 7.25 CASE RUNL CMPL TN RIH with 4-1/2" liner on drillpipe. Running speed 90 sec per stand. 13:00 - 16:30 3.50 CASE RUNL CMPL TN. Hole condition deteriorating. Hole sticky. Work pipe. Up wt 200K, Dn wt 115K. Work 4-1/2" liner to btm at 15,634' 16:30 - 18:00 1.50 CASE DEQT CMPL TN Drop setting ball down drillpipe. Pressure up to 4,600 psi set hanger and packer. Release running tool from hanger. P/U Wt 180K. 18:00 - 19:00 1.00 CASE DEQT CMPL TN Close annular. Pressure up and test liner top packer to 1,500 psi. Hold test pressure for 15 min. OK. Bleed off pressure. RID test chart recorder. 19:00 - 19:30 0.50 DRILL PULD CMPL TN Pull one stand of drillpipe. Blow down top drive. 19:30 - 20:30 1.00 RIGMNT RSRV CMPL TN Cut and slip 129' drilling line. 20:30 - 21 :30 1.00 RIGMNT RSRV CMPL TN Service top drive and crown. 21 :30 - 21:45 0.25 DRILL OBSV CMPL TN Flow check well. Static 21:45 - 22:15 0.50 DRILL TRIP CMPL TN Mix and pump dry job. Blow down top drive. Reset crown-o-matic. 22:15 - 00:00 1.75 DRILL TRIP CMPL TN POH, lay down 4" drillpipe at 6,738'. 6/20/2005 00:00 - 09:00 9.00 DRILL PULD CMPL TN POH, lay down 4" drill pipe and lo-tads from 6,738' to surface. 09:00 - 09:30 0.50 DRILL PULD CMPL TN Break out and lay down Baker liner hanger running tool. 09:30 - 12:00 2.50 DRILL TRIP CMPL TN RIH with 13 stands of HWDP and 57 stands 4" drill pipe to 6,500'. 12:00 -12:30 0.50 DRILL PULD CMPL TN POH, lay down 4" drill pipe to 6,400'. 12:30 - 13:30 1.00 DRILL CIRC CMPL TN M/U top drive. Circulate and condition mud. Mix and pump dry job. Blow down top drive. 13:30 - 18:00 4.50 DRILL PULD CMPL TN POH, lay down 4" drill pipe from 6,400' to 1,200'. 18:00 -19:00 1.00 DRILL PULD CMPL TN POH, lay down 4" HWDP from 1,200' to surface. 19:00 - 19:30 0.50 DRILL RIRD CMPL TN Clear rig floor of all drill pipe handling equipment. 19:30 - 19:45 0.25 DRILL RIRD CMPL TN Pull wear ring from wellhead. 19:45 - 20:30 0.75 CMPL TN RURD CMPL TN RlU GBR tubing handling equipment. Layout running order in pipe shed for 4-112" completion. 20:30 - 20:45 0.25 CMPL TN SFTY CMPL TN PJSM with rig crew and service company personnel on running 4-1/2" completion. 20:45 - 00:00 3.25 CMPL TN PULD CMPL TN P/U Baker seal assembly, RIH with 4-1/2" 12.6 ppf L-80 IBT tubing and completion equipment to 4,290' 6/21/2005 00:00 - 03:30 3.50 CMPL TN RUNT CMPL TN Run 41/2 TBG. 03:30 - 04:30 1.00 CMPL TN SOHO CMPL TN Space Out test seals 500psi. confirm seal set. 04:30 - 07:30 3.00 CMPL TN CIRC CMPL TN RlU and Displace well W/9.5 ppg. Brine.@ 45spm 250 psi. 07:30 - 09:30 2.00 CMPL TN SOHO CMPL TN M/U hanger & Land Tbg. Press test annulus T/1500 psi. 15 min. Press up To 2,900psi shear RP valve. 09:30 - 10:00 0.50 CMPL TN OTHR CMPL TN UD landing Jt. Set BPV. 10:00 - 17:00 7.00 CMPL TN NUND CMPL TN Change Rams to 4-1/2" X 7" & 5". Nipple down BOPE 17:00 - 19:30 2.50 CMPL TN SEQT CMPL TN Nipple up adapter flange and Production Tree. Test pack off to Printed: 7/5/2005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D15CM@conocophillips.com Doyon 15 Start: 5/11/2005 Rig Release: Rig Number: 15 Spud Date: 5/14/2005 End: Group: 6/21/2005 17:00 - 19:30 2.50 CMPL TN SEQT CMPL TN 19:30 - 22:00 2.50 CMPL TN SEQT CMPL TN 22:00 - 00:00 2.00 CMPL TN CIRC CMPL TN 6/22/2005 00:00 - 03:00 3.00 CMPL TN FRZP CMPL TN 03:00 - MOVE DMOB CMPL TN 5,000psi. Test Good. Pull BPV and install two way check, Trouble Pulling BPV through Actuator Valve, Function valve and work past. Test Tree to 25010w , 5,000psi. high, Good Test. RIU and pump Brine with Inhibitor, total 260 bbls, @ 3bpm 1,050 psi. Freeze Protect, Tbg,x7 5/8" 2,000' Set BPV. 280psi. on tbg. and annulus, Injectivity test and freeze Protect 7 5/8"x10 3/4" 2,000' After injecting 82 bbls 875psi. on Annulus. Secure Well and Release Rig @ 03:30. Printed: 7/5/2005 4:13:27 PM HAL.L.IBURTClN .......,. Drilling hrYfce. -750- 750- 1500- 2250 - "2 ~ o o II> <;:. 3000- % OJ o ] :¡:: 3750- ~ - OJ ~ 4500- 5250- -750 0 I I II r I 0- 6000- 6750- 7500- WELL DETAILS: Plan: 1C-21 +N/-S +EJ-W 0.00 0.00 Ground Level: 60.30 Easting Laüttude 562198.12 70019'29A34N Longitude 149°29'44.342W 9000 I I I 1C-21L2 (9986-10408) I 1C-21L3 (9618-12933) I I I I I I I I I I 1 I I 1 I I I I 1 1 J I I I I I I I I 1 I I I 1 I 1 I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 109.74' (1500 Mn) Northing 5968637.75 I I I 750 I I I Vertical Section at 109.74' (1500 ftlin) 4500 5250 6000 6750 7500 r 1 I I I I I I I I r r 1 I 1 I I I I I I I I I I I I 8250 I I I 1 I 1500 I I 1.1 I I r 2250 I I I 3000 I I I I 1 1 I 3750 I 1 I REFERENCE INFORMATION ~ Co-ordinate (NlE) Reference: Well Plan: 1C·21, True North Vertical (1VD) Reference: 1C·21 Actuel @ 101.80ft (Doyon 14 (41.5+ß0.3)) Section (VS) Reference: Slot - (O.OON, O.ODE) Measured Depth Reference: 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) Calculation Method: Minimum Curvature LEGEND -b.- Plan: 1C-21,1C-21L1, 1C-21L1 VO ~ Plan: 1C-21, ~C-21L3,1C-21L3 VO "'*- Plan: 1C-21 , 1C-21L2,1C-21L2VO -b.- 1C-21 \1C-21L1 (0-10336) I ~ 7518" -A~ --... \,I:lllllllII_I,\. Cöno.ill~ . Arm: Slot 1C-21 9750 10500 11250 12000 12750 I I I I r I I I I I I I I I I I I I I 1 r r I I I --750 -0 . -750 -1500 -2250 g (II ¡¡; ;:¡. ::-3000 [ a (þ "§: -3750 ~ 0 0 ~ 2: -4500 . 1'<:-21 (12511 ~ -5250 -6000 -6750 -7500 I I 1 1 I 1 I I I I 1 I 1 I I I I I I I I I ,- 9750 10500 11250 12000 12750 HALLIBURTON Ip..-.y DrIll.... lerv"'.. 5625- 'ê" ~ - ~ 6000-: t c _ 13 6375- b ]I - co 7 5/8" ::> -A./ Q) -'""I ~ - 6750- +N/-S +EI-W 0.00 0.00 \ 1C-21L 1 (Q.10336) ! WELL DETAILS: Plan: 1C-21 (wp11) extensIon Ground Level; 60.30 NorthIng Eastlng Latlttude Longitude 5968637.75 562198.12 70"19'29.434N 149"29'44.342W ."to!"". . COnocoPhimps· .AJe.ska ; Slot 1 C.21 REFeRENCE INFORMATION Co-ordinate (NIE! Referenca: Willi Plan: 1C·21, True North Vertical (TVO Referenca: 1().21 Actuel @ 101.8Oft (Doyon 14 (41.5+60.3» Sèctlon (VS Reference: Slot· (o.oON. O.OOE) Measured Dapth Reference: 1C·21 Actuel @ 101.àOft (Doyon 14 (41.5+60.3» Celcula~on Method: Minimum Curvature LEGEND . -4- Plan: 10.21, 1C-21L 1, 1o.21L 1 VO "*' Plan: 1C-21 , 1C-21L3, 1o.21L3 va * Plan: 10.21, 1C-21L2, 1C-21L2 va -e- 10-21 1C-21L3 (9618-12933) I I1C-21 (12511-15634) I . , I ' I , , I ' I , , I ' I I , I I , , , I ' I , , I I , , 'I ' , , , I ' I I , I' , , , I ' I I I I I , , , I I I I , I ' , , , I ' , , , I ' , , , , ' , I I I I I I , I I I I 1 I ' 5625 6000 6375 6750 7125 7500 7875 8250 8625 9000 9375 9760 10125 10500 10875 11250 11625 12000 1~375 Vertical Section at 109.74° (750 fIIln) +N/-8 +EI·W 0.00 . 0.00 WELL DETAILS:. Plan: 1C.21 (wp11) extension Ground Level: 60.30 Northing Eøtlng Latlttude Longitude 5968637.75 562198.12 70019'29.434N 149°29'44.342W ~ . COnocoPhiUips : AJas'ka HALLIBURTON .p.rt)' Drill'", ..""Ie.. Slot 1 c.21 REFERèNCE INFORMATION .., Co-Qldlnate (N/E¡ Reference: Well Plan: 10'21, True North Vertical (lYD Reference: 10..21 Actual @ 101.800 (Doyon 14 (41.5+60.3» Section (VS) Ref8rei1ce: Slot. (0.00"1. Q.OOE) Measured Dapth Reference: 10..21 Aciùal @ 101.8OIt (Doyon 14 (41.5+80.3» Calculation Method: Minimum Cutvature LEGEND . -+- Plan: 1C-21, 1C-21t.1,1c.21L1 va ""*" Plan: 1c.21 , 1C-21L3, 1C.21L3 va + Plén: 1c.21, 1C-21L2, 1c.21L2 va -e- 1C.21 6400- \1C.21L2 (9986-10408) \ 6450 - 1c.21L1 (Q.10336) I . 'ê' - :Jã 6500- 8 ::. t - ~ 6550- B - :e <U > - ~ 6600- t-' - ~ 11C.21L3(9618-12933) I 6650 - 1C.21 (12511.15634) I 6700 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ' I I I I I I I I I' I I I I \ I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I I 6000 6050 6100 6150 6200 6250 6300 6350 6400 6450 6500 6550 6600 6650 6700 6750 6800 6850 6900 6950 Vertical Section at 109.74° (100 fIIln) ,', .' ...~.,:. ..' . CønøcøPh' ·I·IIIPS . . . ,; ~ . :..' I' ,.' ': . '. . ·,'i.' . ::, " .' .' :" ':'. . .AI.......,..'.U.....·...'....· f"IIa$r,ö 1750- 875- 0- -875- '2 -1750- ~ - o LO I'- ::::. -2625- +' ?:: t o _ ~ -3500- , - ?:: "5 o CI) -4375- -5250- -8125- -7000- -7875- ~ Project: Kuparuk River Unit Site: KupaRlk 1CPad Well: Plan: 1C-21 Wellbore: 1C-21 Design: 1C-21 HALLIBURTDN Sperry Drilling Services '1 . 1618" . LEGEND -b- Plan: 1C-21 , 1C-21L1,1C-21L1 VO ....¡... Plan: 1C-21 , 1C-21L3, 1C-21L3VO -a- Plan: 1C-21, 1C-21L2, 1C-21L2 VO -b- 1C-21 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -875 0 875 1750 2625 3500 4375 5250 6125 7000 7875 8750 9625 10500 11375 12250, 13125 14000 14875 West( - )Æast( +) (1750 ftlin) T ^ M Azimuths to True North ¿MagnetlC North: 24,34' Magnetic Field Strength: 57604,3nT Dip Angle: 80,11' Dete: 61712005 Model: BGGM2004 Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 C 1 C-21 L2 . Job No. AK-ZZ-0003706651, SUlVeyed: 2 June, 2005 Survey Report 6 July, 2005 Your Ref: API 500292325361 Suñace Coordinates: 5968637.75 N, \ 562198.12 E (700 19' 29.4336" N, 149029' 44.3424" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Suñace Coordinates relative to Project H Reference: 968637.75 N, 62198.12 E (Grid) Suñace Coordinates relative to Stucture Referance: 116.73 N, 172.97 W (True) Kelly Bushing Elevation: 101.80ft above Mean Sea Level Kelly Bushing Elevation: 101.8Oft above Project V Reference Kelly Bushing Elevation: 101.80ft above Structure Referance &P&!l'""'ïf~-&U" DRILL.ING SERVIces A Hanlburtol'l Company SUlVey Ref: svy2169 Halliburton Sperry-Sun SUlVey Report for Kuparuk 1C -1C-21L2 Your Ref: API 500292325361 Job No. AK-ZZ-0003706651, SUlVeyed: 2 June, 2005 ConocoPhillips Western North Slope Measured True 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) 10079.89 89.930 106.780 6436.00 6537.80 2255.00 S 6141.87E 5966433.73 N 568358.47 E 6542.58 Tie-On Point 10107.00 90.680 106.490 6435.85 6537.65 2262.76 S 6167.85 E 5966426.19 N 568384.51 E 2.966 6569.65 Window Point 10176.48 88.740 104.180 6436.20 6538.00 2281.13 S 6234.84 E 5966408.37 N 568451.66 E 4.341 6638.91 10267.04 90.980 113.930 6436.42 6538.22 2310.66 S 6320.33 E 5966379.55 N 568537.39 E 11.046 6729.35 10359.60 92.880 125.170 6433.30 6535.10 2356.20 S 6400.68 E 5966334.68 N 568618.11 E 12.308 6820.36 10408.00 92.880 125.170 6430.87 6532.67 #. 2384.05 S 6440.19 E - 5966307.16 N 568657.85 E - 0.000 6866.95 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. ~ Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 109.740· (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10408.00ft., The Bottom Hole Displacement is 6867.30ft., in the Direction of 110.314· (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10079.89 10107.00 10408.00 6537.80 6537.65 6532.67 2255.00 S 2262.76 S 2384.05 S 6141.87E 6167.85 E 6440.19 E Tie-On Point Window Point Projected Survey . 6 July, 2005 - 16:59 Page 20f3 DrillQuest 3.03.06.008 Western North Slope Halliburton Sperry-Sun Survey Report for Kuparuk 1C - 1C-21 L2 Your Ref: API 500292325361 Job No. AK-ZZ-0003706651, Surveyed: 2 June, 2005 ConocoPhillips Survey tool IJroaram for 1 C-21 L2 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 6 July, 2005 - 16:59 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10408.00 6532.67 MWD+IIFR+MS+SAG (1C-21L 1) . . Page 3 of3 DrillQuest 3.03.06.008 . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 C-21 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,079.89' MD 10,107.00' MD 10,408.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun grilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 -1 ) /1 Date , ( ~~ \- Signed '~ d JJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 14-Jul-05 ;2 Or - J c , rr:1t. . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-21 L2 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,079.89' MD 10,107.00' MD 10,408.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ¡;J I A Date. )i ~ ;u, ( Signed "~ð/JvJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 14-Jul-05 ) ()S- - { (j \ ~/(~ . . Note to File KRU 1C-21 (205-034), KRU 1C-21L1 (205-100), KRU 1C-21L2 (205-101), and KRU 1C-21L3 (205-102) ACTION For the sake of clear record keeping, the following names, API numbers and Permit to Drill numbers will be assigned to portions ofKRU lC-21: 1. KRU 1C-21, API Number 50-029-23253-00, Permit to Drill number 205-034: assigned to the well bore segments completed with casing and slotted liner between the surface and the total depth of the well at about 15,573' measured depth ("MD"). 2. KRU 1C-21L1, API number 50-029-23253-60, Permit to Drill number 205-100: assigned to the first vacated well bore segment between 9,605' and 1O,336'MD. 3. KRU lC-21L2, API number 50-029-23253-61, Permit to Drill number 205-101: assigned to the second vacated well bore segment between 1O,107'and 10,408' MD. 4. KRU 1C-21L3, API number 50-029-23253-62, Permit to Drill number 205-102: assigned to the third vacated well bore segment between 12,511' and 12,933' MD. BACKGROUND The following is a recap of events that occurred during drilling ofthe KRU 1 C-21 well. 1. The Commission issued Permit to Drill 205-034 for the KRU lC-21 well on March 15,2005. The permitted total depth of the well was 14,147' MD. 2. While drilling, ConocoPhillips Alaska, Inc. ("CP AI") determined that the well bore had exited the top of the reservoir sand into the overlying shale. After reaching a total measured depth of 10,336', CPAI pulled back to 10,107' MD (229') and performed an open-hole course correction. This section of vacated well bore opened about 70' of reservoir sand, and it was not plugged back. 3. Due to steering difficulties, the well bore again approached the top ofthe reservoir sand. At 10,408' MD, CPAI pulled back to 9,605'MD (803') and performed a second open-hole course correction without plugging the vacated well bore. This section of vacated well bore lies within the reservoir sand. 4. As drilling continued, CP AI apparently again approached the top of the reservoir sand. At 12,933' MD, they pulled back to 12,511' MD (422') and performed a third open-hole course correction without plugging the vacated well bore. This section of vacated well bore apparently lies within the reservoir sand. 5. Based on encouraging drilling results, CPAI sought and obtained verbal approval from the Commission to lengthen the well to a new bottom-hole location that was more than 500' from the permitted bottom-hole location. 6. CP AI submitted a permit to drill application for the revised 1 C-21 bottom-hole location. The requested total depth was changed to 15,573' MD (an additional 1,426'). 7. Commission senior staff instructed CP AI via email to submit permit to a drill application for each vacated well bore segment on June 9, 2005. 8. The Commission issued a revised permit to drill for the KRU 1C-21 well on June 10,2005. . . RATIONALE The vacated well bore segments open between 70' and 800' of reservoir sand, and they were not plugged. They were not completed, and they are expected to remain open. They will act as open-hole branches of the KRU lC-21 well, and will contribute to production. Commission regulations require that each well branch be given a unique name and an API number. Our databases require that each API number have a corresponding pennit to drill number. Commission regulation 25.005(e) requires a separate pennit to drill for each well branch, and paragraph (e) specifies that the application for the pennit to drill for a well branch need only include infonnation that is unique to that branch. Having unique names, API numbers and pennit to drill numbers will ensure proper management ofthe directional data and any MWD data acquired in the vacated well branches. Including vacated well branches in our databases is important, especially when conducting Area-of-Review investigations associated with enhanced recovery operations. ~-4'¿;~~ Steve Davies June 28, 2005 . . (fù.l? ill ? rr ,'~ i[ I~' [; iÞ r'lH.U "u,\'ì" 'J \;:;:.,; w ;. U W t-=:3 ~n ~ ¡ , , 1 :i ~ q ,,¡, !:d HJ.Î n ~u :ï1 II ~ ~ ,; , i ft 1 ~ FRANK H. MURKOWSKI, GOVERNOR ~1,A.SIiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: KRU 1C-21L2 ConocoPhillips Alaska, Inc. Permit No: 205-101 Surface Location: 1600' FNL, 4089' FEL, SEC 12, T11N, R10E, UM Bottomhole Location: 3987' FNL, 2573' FEL, SEC 7, T11N, RIlE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced developmen t well. The purpose of this permit to drill is clear record keeping. It is needed for proper tracking of KRU 1C-21L2, an unplanned lateral well branch that was drilled and then subsequently vacated when the ConocoPhillips Alaska, Inc. 's drilling team pulled back up-hole and made an open hole course correction. This well branch is expected to remain open and will contribute to production from the KRU 1C-21 well. AOGCC's regulations require a unique name and API number for each well branch. Our business practices and databases require an associated permit to drill number for each API number. If you have any questions, please contact Mr. St DATED thi~ day of June, 2005 . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill 0 Re-entry 0 11 b. Current Well Class: Stratigraphic Test 0 Redrill U 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1600' FNL, 4089' FEL, Sec. 12, T11N, R10E, UM Top of Productive Horizon: 1751' FSL, 987' FWL, Sec. 7, T11N, R11E, UM Total Depth: 3987' FNL, 2573' FEL, Sec.7, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562198 16. Deviated wells: y- 5968638 Zone- 4 Kickoff depth: 10107 ft. Maximum Hole Angle: 92° deg Specifications 18. Casing Program Size Hole Casing Coupling Weight Grade Length A~ Exploratory U bevøtop~¡'tOil W Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: W Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1C-21L2 6. Proposed Depth: 12. Field/Pool(s): MD: 10408' TVD: 6533' Kuparuk River Field 7. Property Designation: A ziyþÇ" ADL 28242, 256~ 8. Land Use Permit: ALK 2292 9. Acres in Property: 2469 10. KB Elevation Kuparuk Oil Pool 13. Approximate Spud Date: 5/14/2005 14. Distance to Nearest Property: 2324' f/KRU Bndry 15. Distance to Nearest (Height above GL): 42' RKB feet Well within Pool: 1 C·26 - 2300' , 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3189 psig Setting Depth Top Bottom Surface: 2473 psig Quantity of Cement c. 1. or sacks (including stage data) 19 Total Depth MD (ft): 10408' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) 6533' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD Length Size 76' 5639' 9111' MD MD TVD TVD 16" 9 cu yds High Early 776 sx AS Lite, 389 sx LiteCrete 255 sx Class G 116' 5681' 9153' 10.75" 7-5/8" 116' 4480' 6542' none 20. Attachments: Filing Fee 0 Property Plat 0 perfOration Depth TVD (ft): none Drilling Program U Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 BOP Sketch U Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas Signature ~ \ ~ Contact Tim Billings/ey @ 265-6531 Title Greater Kuparuk Area Drilling Team Leader Phone l.bS-6ô'1ð Date (, ('l.:2./~ PreDared bv Sharon AI/suo-Drake Permit to Drill 2öS /0 I Commission Use Only API Number: . _ Permit Approval 50- Ó z.C¡ - 2325 3 .-, I Date: Number: Other: Yes 0 Yes ~ Conditions of approval: Approv Form 10-401 Revise~ No g¡ No 0 Mud log required Directional survey required APPROVED BY THE COMMISSION --- JR\G\NAL see cover letter for other requirements Yes 0 Yesg No g No 0 C,re ~!::e · Halliburton Compane Global Report Survey: Start Date: Company: Tool: Engineer: Tied-to: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) ~ys Datum: Mean Sea Level r Site: Kuparuk 1 C Pad I I I I ; Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, ZOl1~ 4 Well Centre bggm2004 Site Position: From: Map Position Uncertainty: Ground Level: Northing: Easting: 5968522.46 ft 562372.05 ft Latitude: 70 19 Longitude: 149 29 North Reference: Grid Convergence: 28.285 N 39.293 W True 0.48 deg 0.00 ft 0.00 ft Well: Plan: 1 C-21 Slot Name: Well Position: +N/-S 116.74 ft Northing: 5968637.75 ft Latitude: +E/-W -172.98 ft Easting: 562198.12 ft Longitude: Position Uncertainty: 0.00 ft 70 19 29.434 N 149 29 44.342 W WelIpath: Rig: 1C-21 PB2 Current Datum: i Magnetic Data: Field Strength: Vertical Section: +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Rig: 1C-21 PB1 10079.89 ft Mean Sea Level 24.35 deg 80.78 deg Direction deg 109.74 .- 1C-21 (40 D15 + 60.3GL) 6/2/2005 57605 nT Depth From (TVD) ft 40.00 Height 100.30 ft Survey Program for Definitive Wellpath Date: 6/2/2005 Validated: No Actual From To Survey ft ft 150.45 700.98 791.69 10079.89 10107.00 10359.60 Version: 3 Toolcode Tool Name Rig:1 C-21 (150.45-700.98) (1) Rig: 1C-21 MWD (791.69-10267.9 1C-21 MWD (10107.00-10359.60) INC Inclinometer (TotcolTeledrift) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey 40.00 0.00 0.00 40.00 -60.30 0.00 0.00 5968637.75 562198.12 TIE LINE 150.45 0.48 122.03 150.45 50.15 -0.25 0.39 5968637.51 562198.51 INC 238.15 0.71 123.10 238.14 137.84 -0.74 1.16 5968637.02 562199.28 INC 329.53 0.67 105.38 329.52 229.22 -1.19 2.15 5968636.58 562200.28 INC 423.34 0.88 117.37 423.32 323.02 -1.66 3.32 5968636.11 562201.45 INC 515.72 0.98 115.05 515.69 415.39 -2.33 4.66 5968635.46 562202.80 INC 607.93 0.44 69.53 607.89 507.59 -2.54 5.71 5968635.26 562203.85 INC 700.98 0.14 2.56 700.94 600.64 -2.30 6.05 5968635.50 562204.19 INC 791.69 0.09 44.52 791.65 691.35 -2.14 6.10 5968635.67 562204.24 MWD+IFR-AK-CAZ-SC 884.15 0.26 30.73 884.11 783.81 -1.90 6.26 5968635.90 562204.40 MWD+IFR-AK-CAZ-SC 976.65 0.00 195.75 976.61 876.31 -1.72 6.37 5968636.08 562204.50 MWD+IFR-AK-CAZ-SC 1072. 50 2.80 117.77 1072.42 972.12 -2.81 8.44 5968635.01 562206.58 MWD+IFR-AK-CAZ-SC 1167.70 4.08 117.75 1167.45 1067.15 -5.47 13.50 5968632.39 562211.66 MWD+IFR-AK-CAZ-SC 1260.00 5.74 118.20 1259.40 1159.10 -9.18 20.47 5968628.74 562218.66 MWD+IFR-AK-CAZ-SC 1356.76 9.07 117.17 1355.34 1255.04 -14.96 31.52 5968623.06 562229.76 MWD+IFR-AK-CAZ-SC 1452.21 12.47 123.17 1449.10 1348.80 -24.03 46.85 5968614.11 562245.16 MWD+IFR-AK-CAZ-SC 1547.33 13.41 117.90 1541.81 1441.51 -34.81 65.19 5968603.48 562263.59 MWD+IFR-AK-CAZ-SC ORIGINAL · Halliburton Compane Global Report Survey 1642.93 14.32 115.22 1634.62 1534.32 -45.04 85.69 5968593.43 562284.17 MWD+IFR-AK-CAZ-SC 1738.04 15.47 112.66 1726.54 1626.24 -54.94 108.03 5968583.72 562306.59 MWD+IFR-AK-CAZ-SC 1833.26 17.54 109.74 1817.83 1717.53 -64.68 133.26 5968574.19 562331.90 MWD+IFR-AK-CAZ-SC 1928.28 21.90 108.23 1907.26 1806.96 -75.06 163.58 5968564.05 562362.30 MWD+IFR-AK-CAZ-SC 2024.64 26.47 109.40 1995.14 1894.84 -87.82 200.93 5968551.60 562399.75 MWD+IFR-AK-CAZ-SC 2119.04 30.78 113.98 2077.99 1977.69 -104.64 242.87 5968535.14 562441.82 MWD+IFR-AK-CAZ-SC 2214.89 36.44 114.91 2157.78 2057.48 -126.61 291.13 5968513.57 562490.26 MWD+IFR-AK-CAZ-SC 2310.10 42.32 113.36 2231.34 2131.04 -151.25 346.25 5968489.39 562545.58 MWD+IFR-AK-CAZ-SC 2404.35 46.91 11 0.17 2298.43 2198.13 -175.72 407.72 5968465.44 562607.25 MWD+IFR-AK-CAZ-SC 2499.20 48.04 109.15 2362.54 2262.24 -199.23 473.55 5968442.47 562673.26 MWD+IFR-AK-CAZ-SC 2595.36 47.42 109.34 2427.22 2326.92 -222.68 540.73 5968419.58 562740.63 MWD+IFR-AK-CAZ-SC 2690.64 46.96 109.40 2491.96 2391.66 -245.86 606.67 5968396.95 562806.75 MWD+IFR-AK-CAZ-SC 2785.90 47.77 109.30 2556.49 2456.19 -269.08 672.79 5968374.28 562873.06 MWD+IFR-AK-CAZ-SC 2880.70 49.09 110.36 2619.39 2519.09 -293.15 739.51 5968350.77 562939.96 MWD+IFR-AK-CAZ-SC 2975.47 49.10 110.79 2681.45 2581.15 -318.32 806.56 5968326.15 563007.22 MWD+IFR-AK-CAZ-SC 3070.81 48.70 110.76 2744.12 2643.82 -343.80 873.74 5968301.23 563074.59 MWD+IFR-AK-CAZ-SC 3166.02 48.35 110.21 2807.18 2706.88 -368.77 940.56 5968276.82 563141.62 MWD+I FR-AK-CAZ-SC 3260.89 48.02 110.75 2870.43 2770.13 -393.51 1006.80 5968252.64 563208.05 MWD+IFR-AK-CAZ-SC 3356.68 47.78 110.31 2934.65 2834.35 -418.43 1073.36 5968228.27 563274.81 MWD+IFR-AK-CAZ-SC 3452.18 47.65 110.25 2998.90 2898.60 -442.92 1139.63 5968204.33 563341.27 MWD+IFR-AK-CAZ-SC 3547.06 47.39 110.45 3062.98 2962.68 -467.26 1205.24 5968180.54 563407.07 MWD+IFR-AK-CAZ-SC 3642.08 47.02 110.38 3127.53 3027.23 -491.58 1270.58 5968156.77 563472.61 MWD+IFR-AK-CAZ-SC 3736.31 46.47 109.98 3192.10 3091.80 -515.25 1335.00 5968133.63 563537.22 MWD+IFR-AK-CAZ-SC 3831.84 46.50 110.35 3257.88 3157.58 -539.13 1400.03 5968110.29 563602.44 MWD+IFR-AK-CAZ-SC 3926.93 46.24 109.79 3323.49 3223.19 -562.75 1464.68 5968087.21 563667.27 MWD+IFR-AK-CAZ-SC 4022.16 45.98 109.33 3389.51 3289.21 -585.73 1529.34 5968064.77 563732.12 MWD+IFR-AK-CAZ-SC 4117.07 47.47 109.64 3454.57 3354.27 -608.78 1594.49 5968042.26 563797.44 MWD+IFR-AK-CAZ-SC 4211.90 47.32 109.68 3518.77 3418.47 -632.27 1660.22 5968019.33 563863.36 MWD+IFR-AK-CAZ-SC 4306.29 46.85 109.86 3583.04 3482.74 -655.65 1725.27 5967996.49 563928.60 MWD+IFR-AK-CAZ-SC 4401.30 47.90 109.80 3647.38 3547.08 -679.36 1791.03 5967973.32 563994.55 MWD+IFR-AK-CAZ-SC 4494.75 47.52 109.87 3710.26 3609.96 -702.82 1856.06 5967950.41 564059.76 MWD+IFR-AK-CAZ-SC 4591.17 47.50 109.71 3775.39 3675.09 -726.89 1922.96 5967926.89 564126.85 MWD+IFR-AK-CAZ-SC 4683.91 47.57 109.44 3838.00 3737.70 -749.81 1987.42 5967904.51 564191.49 MWD+IFR-AK-CAZ-SC 4779.32 46.25 108.87 3903.18 3802.88 -772.68 2053.23 5967882.19 564257.49 MWD+IFR-AK-CAZ-SC 4874.02 45.75 109.20 3968.96 3868.66 -794.89 2117.63 5967860.51 564322.06 MWD+IFR-AK-CAZ-SC I 4969.39 47.42 109.77 4034.50 3934.20 -818.00 2182.93 5967837.94 564387.55 MWD+IFR-AK-CAZ-SC 5064.30 49.07 110.20 4097.71 3997.41 -842.21 2249.47 5967814.30 564454.28 MWD+IFR-AK-CAZ-SC 5158.80 49.05 109.94 4159.63 4059.33 -866.70 2316.52 5967790.36 564521.52 MWD+IFR-AK-CAZ-SC 5253.60 49.07 111.79 4221.75 4121.45 -892.21 2383.43 5967765.41 564588.63 MWD+IFR-AK-CAZ-SC 5349.50 49.13 111.84 4284.54 4184.24 -919.14 2450.73 5967739.04 564656.14 MWD+IFR-AK-CAZ-SC 5444.32 49.65 111.84 4346.26 4245.96 -945.92 2517.54 5967712.82 564723.17 MWD+IFR-AK-CAZ-SC 5539.80 47.58 112.85 4409.38 4309.08 -973.15 2583.80 5967686.15 564789.65 MWD+IFR-AK-CAZ-SC 5633.56 47.10 113.05 4472.92 4372.62 -1000.03 2647.29 5967659.79 564853.36 MWD+IFR-AK-CAZ-SC 5723.14 48.12 113.72 4533.31 4433.01 -1026.29 2708.02 5967634.03 564914.29 MWD+IFR-AK-CAZ-SC 5818.01 50.22 112.27 4595.34 4495.04 -1054.32 2774.09 5967606.56 564980.59 MWD+IFR-AK-CAZ-SC 5912.16 50.97 111.92 4655.10 4554.80 -1081.68 2841.50 5967579.76 565048.21 MWD+IFR-AK-CAZ-SC 6006.81 49.86 110.18 4715.42 4615.12 -1107.89 2909.57 5967554.12 565116.49 MWD+IFR-AK-CAZ-SC 6102.57 48.63 109.91 4777.93 4677.63 -1132.75 2977.71 5967529.82 565184.83 MWD+IFR-AK-CAZ-SC 6197.23 48.22 109.52 4840.75 4740.45 -1156.64 3044.37 5967506.49 565251.68 MWD+IFR-AK-CAZ-SC 6292.41 48.98 109.91 4903.69 4803.39 -1180.73 3111.58 5967482.97 565319.08 MWD+IFR-AK-CAZ-SC 6388.33 49.93 109.64 4966.04 4865.74 -1205.39 3180.17 5967458.88 565387.87 MWD+IFR-AK-CAZ-SC 6483.93 49.16 111 .27 5028.07 4927.77 -1230.80 3248.33 5967434.03 565456.22 MWD+IFR-AK-CAZ-SC 6579.84 48.62 111.02 5091.14 4990.84 -1256.87 3315.72 5967408.53 565523.83 MWQ+tFR...AK,CAZ-SC RIGINAL . Halliburton Compane Global Report Survey 6674.85 6769.27 6864.01 6960.16 7055.34 7150.92 7245.64 7340.59 7434.25 7530.42 7625.72 7721.85 7814.93 7908.83 8004.57 8099.93 8194.85 8289.80 8384.96 8480.28 8575.26 8669.60 8763.73 8857.57 8953.63 9050.65 9088.29 I 9154.39 9246.59 I 9339.28 9432.80 I 9526.04 '--9618.98 9707.68 I 9801.09 9894.10 9986.63 - ~ 10079.89 I 10107.00 I 10176.48 I 10267.04 . 10359.60 ¡ -10408.00 '----- 48.87 48.74 49.88 49.46 47.94 46.74 46.90 46.20 46.24 47.62 48.58 48.45 50.01 51.84 50.96 49.86 49.29 51.12 56.62 61.01 62.64 63.86 68.14 73.04 75.09 79.77 81.21 84.87 92.72 90.26 89.88 85.99 90.46 93.65 93.09 88.77 90.56 89.93 90.68 88.74 90.98 92.88 92.88 111.06 110.32 110.06 111.88 111 .29 110.73 110.31 110.15 109.97 110.17 111 .52 111.74 113.07 112.83 114.88 113.75 111.83 110.06 109.41 108.44 108.37 109.36 109.75 110.80 109.60 106.36 105.12 108.90 108.11 107.52 101.71 100.31 106.08 109.92 111.19 109.36 109.26 106.78 106.49 104.18 113.93 125.17 125.17 5153.79 5215.97 5277.74 5339.97 5402.79 5467.56 5532.37 5597.67 5662.47 5728.15 5791.79 5855.47 5916.25 5975.44 6035.17 6095.95 6157.50 6218.27 6274.36 6323.70 6368.55 6411.01 6449.29 6480.47 6506.84 6527.95 6534.17 6542.18 6544.12 6541.71 6541.60 6544.96 6547.84 6544.65 6539.16 6537.65 6538.19 6537.80 6537.65 6538.00 6538.22 6535.10 6532.67 5053.49 5115.67 5177.44 5239.67 5302.49 5367.26 5432.07 5497.37 5562.17 5627.85 5691.49 5755.17 5815.95 5875.14 5934.87 5995.65 6057.20 6117.97 6174.06 6223.40 6268.25 6310.71 6348.99 6380.17 6406.54 6427.65 6433.87 6441.88 6443.82 6441.41 6441.30 6444.66 6447.54 6444.35 6438.86 6437.35 6437.89 6437.50 6437.35 6437.70 6437.92 6434.80 6432.37 -1282.51 -1307.61 -1332.41 -1358.63 -1384.94 -1410.14 -1434.35 -1458.19 -1481.39 -1505.50 -1530.74 -1557.29 -1584.16 -1612.58 -1642.83 -1673.09 -1701.09 -1727.15 -1753.08 -1779.50 -1805.94 -1833.18 -1861.96 -1892.63 -1924.52 -1953.71 -1963.78 -1982.98 -2012.21 -2040.56 -2064.14 -2081.94 -2103.13 -2130.51 -2163.25 -2195.47 -2226.06 -2254.91 -2262.67 -2281.04 -2310.57 -2356.12 -2383.96 3382.39 3448.85 3516.27 3584.71 3651.20 3716.81 3781.50 3846.18 3909.70 3975.68 4041.97 4108.91 4174.08 4241.20 4309.63 4376.59 4443.20 4511.33 4583.65 4660.77 4740.21 4819.93 4900.94 4983.93 5070.61 5160.65 5196.38 5259.10 5346.45 5434.65 5525.11 5616.55 5706.93 5791.21 5878.52 5965.73 6053.05 6141.73 6167.71 6234.70 6320.19 6400.54 6440.05 5967383.44 5967358.89 5967334.66 5967309.00 5967283.25 5967258.59 5967234.92 5967211.63 5967188.96 5967165.40 5967140.71 5967114.72 5967088.39 5967060.53 5967030.85 5967001.15 5966973.71 5966948.22 5966922.89 5966897.11 5966871.34 5966844.76 5966816.65 5966786.67 5966755.51 5966727.06 5966717.29 5966698.62 5966670.11 5966642.50 5966619.67 5966602.63 5966582.19 5966555.51 5966523.50 5966492.01 5966462.14 5966434.03 5966426.49 5966408.67 5966379.86 5966334.99 5966307.48 )- L1 \L..O \> ~"C'L. ;}o«:> - \00 t t\.)b.~~\\ ~\E..~~ç\-(),", qCo\~ - \Q'40i ORIGINAL 565590.70 MWD+IFR-AK-CAZ-SC 565657.36 MWD+IFR-AK-CAZ-SC 565724.98 MWD+IFR-AK-CAZ-SC 565793.63 MWD+IFR-AK-CAZ-SC 565860.32 MWD+IFR-AK-CAZ-SC 565926.14 MWD+IFR-AK-CAZ-SC 565991.02 MWD+IFR-AK-CAZ-SC 566055.88 MWD+IFR-AK-CAZ-SC 566119.59 MWD+IFR-AK-CAZ-SC 566185.77 MWD+IFR-AK-CAZ-SC 566252.25 MWD+IFR-AK-CAZ-SC 566319.40 MWD+IFR-AK-CAZ-SC 566384.78 MWD+IFR-AK-CAZ-SC 566452.13 MWD+IFR-AK-CAZ-SC 566520.80 MWD+IFR-AK-CAZ-SC 566588.01 MWD+IFR-AK-CAZ-SC 566654.84 MWD+IFR-AK-CAZ-SC 566723.18 MWD+IFR-AK-CAZ-SC 566795.70 MWD+IFR-AK-CAZ-SC 566873.04 MWD+IFR-AK-CAZ-SC 566952.69 MWD+IFR-AK-CAZ-SC 567032.62 MWD+IFR-AK-CAZ-SC 567113.85 MWD+IFR-AK-CAZ-SC 567197.09 MWD+IFR-AK-CAZ-SC 567284.03 MWD+IFR-AK-CAZ-SC 567374.30 MWD+IFR-AK-CAZ-SC 567410.10 MWD+IFR-AK-CAZ-SC 567472.97 MWD+IFR-AK-CAZ-SC 567560.55 MWD+IFR-AK-CAZ-SC 567648.98 MWD+IFR-AK-CAZ-SC 567739.62 MWD+IFR-AK-CAZ-SC 567831.20 MWD+IFR-AK-CAZ-SC 567921.74 MWD+IFR-AK-CAZ-SC 568006.24 MWD+IFR-AK-CAZ-SC 568093.81 MWD+IFR-AK-CAZ-SC 568181.27 MWD+IFR-AK-CAZ-SC 568268.84 MWD+IFR-AK-CAZ-SC 568357.74 MWD+IFR-AK-CAZ-SC 568383.78 MWD+IFR-AK-CAZ-SC 568450.92 MWD+IFR-AK-CAZ-SC 568536.64 MWD+IFR-AK-CAZ-SC 568617.35 MWD+IFR-AK-CAZ-SC 568657.09 MWD ""'~ . :: '1<;'0 HALLIBURTON _m________.__.__._···__ Sperry Drilling Services -750- 0- 750- 1500- "_-0) .'"1' r;:- ,--.I 2250- G) - z ).> r- ê ~ o o II) S 3000- ~ Õ. '" Q ~ 'äi 3750- > - '" " f::. 4500- 5250- 6000- 6750- 7500- -750 I I I I I ~ I -750 t I I o I I I I I I I I o WELL DETAILS: Plan: 1C-21 +N/-S +E1-W 0.00 0.00 Ground Level: 60.30 Easting Latittude 562198.12 70019'29.434N Longitude 149°29'44.342W Northing 5968637.75 750 I I I I I Vertical Section at 109.74° (1500 fIIin) 4500 5250 6000 6750 7500 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1500 I I r 2250 r I I I I I I 3000 I I I 3750 I I I I I REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan: 1C-21, True North Vertical (TVD) Reference: 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) Section (VS) Reference: Slot· (O.OON, O.OOE) Measured Depth Reference: 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) Calculation Method: Minimum Curvature LEGEND -f!r Plan: 1C-21, 1C-21L1, 1C-21L1 VO ~ Plan: 1C-21, 1C-21L3, 1C-21L3 VO ""* Plan: 1C-21, 1C-21L2, 1C-21L2VO -f!r 1C-21 l1C-21L1 (0-1033~ [1c-21L2(~986..1 04081] 8250 I I I I I 9000 I I I ["" "--' ----. -'-J 1C-21L3 (9618-12933) --'-'.--'--'---'" ..,-_.,..._._..~ C ..~75/8" --.., I I I 750 I I I I I I I I I r I I I I I I r I I I I I I I I 4500 5250 6000 6750 7500 Vertical Section at 109.74° (1500 fIIln) 1 1 I I J t ! 8250 r I I I I r r 1500 I I I I I 2250 I I I 3000 I I I I I 3750 r I I 9000 Slot 1 C-21 9750 I I I I I I I I I J I I I I 9750 ........ ConocOPhillips AJask~ 10500 11250 12000 12750 I I I I I I I I I I I I I I I I I I r:;r;" ".~-" -.-'.-.'.-'] l1C-21 (12511 -15634) -_._~- ~ I I I 10500 I I I I I I I I I I r I 11250 12000 --750 -0 . -750 -1500 -2250 ~ <: CD < CD ~ =- 3000 i1 o CD "C 5' -3750 ~ o o ë!: 3 -4500 . - 5250 -6000 -6750 -7500 I I I 12750 +N/-S +EI-W 0.00 0.00 WELL DETAILS: Plan: 1C-21 (wp11) Extension Ground Level: 60.30 Eastlng Latlttude 562198.12 70019'29.434N /' . Conoc;Phillips .AJ8tska HALLIEiURTON Sp..., DrllUIIIf ServICe. Northing 5988637.75 Longitude 149"29'44.342W Slot 1 Co21 REFERENCE INFORMATION Co-ordinate (N/E) Retarence: Well Plan: 1C-21, True North Vertical (ND) Reference: 1C-21 Actual @ 101.800 (Doyon 14 (41.5+60.3)) Seclion (VS) Reference: SiOI - (O.OON. O.OOE) Measured Depth Reference: 1C-21 Actual @ 101.80ft (Doyon 14 (41.5+60.3)) Celculation Method: Minimum Curvature LEGEND . c :;ç - G) - z » r- -+- Plan: 1C-21, 1C-21L1, 1G-21L1 va -)E- Plan: 1C-21, 1C-21L3, 1C-21L3 VO -I!.r- Plan: 1C-21, 1C-21L2, 1G-21L2 va -a- 1C-21 C' æ:¡ _ ~ 6000-: 1C.21L3 (9618-12933) I ",,- ", "\\\ \"- " "\, '\,,\, " \', \\", -~ 1C.21L1 (0-10336) I 5625- 11C-21L2 (9986-10408) I 1C-21 (12511-15634) I '. .'"'. '. .....,~....~~" ..... .... '~........~ . .s:; I c ~ 6375- C t! _co 75/8" ~ _4./ ~ ...., I- 6750- ". ......,....,......, ........ -......~~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 5625 6000 6375 6750 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 11625 12000 12375 Vertical Section at 109.74" (750 It/in) HALLIBURTON Ipe.., Drlm", Servlc.. (..... , ~~... :J::J GJ - Z » r 6400- 6450- C' :¡ä 6500- ß .c õ. - ~ 6550- ~ 1:: ~ - ~ 6600- t- 6650- 6700 '" 6000 1 I 1 6050 1 1 1 I 1 1 1 6100 +N/-S +EI-W 0.00 0.00 1 I 1 6150 1 1 1 I 1 1 1 6200 1 I 1 1 1 6250 WELL DETAILS: Plan: 1C-21 (wp11) extension Northing 5968637.75 Ground Level: 60.30 Easüng Latlttude 562196.12 70019'29.434N Longitude 149°29'44.342W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plen: IC-21, True North Vertical (TVD) Refemnce: IC-21 Actual@ 101.8Oft (Doyon 14 (41.5+80.3)) Section (VS) Reference: Siot· (O.OON, O.OOE) Measured Depth Reference: 1C-21 Actual@ 101.80ft (Doyon 14 (41.5+60.3)) Calculation Method: Minimum Curvalure LEGEND -+- Plan: 1C-21, 1C-21L1, 1C-21L1 VO ~ Plan: 1C-21, 1C-21L3, 1C-21L3 va -ft- Plan: 1C-21, 1C-21L2, 1C-21L2VO -e- 1C-21 1C-21L1 (0-10336) I "'........-..~ 1 I I 6300 I I 1 I 1 I 1 1 I I 1 1 1 I 1 1 1 1 I 1 I 1 1 I I I I I I 1 1 I 6350 6400 6450 6500 6550 6600 Vertical Section at 109.74" (100 fl/in) Slot 1C-21 .........., --.... ~"" """. ~~þ ConocoPhillips ,tl,Jr.!';ki\ . 11C-21L2 (9986-10408) I ..... . .....,~ ,.........-. ".---'-7 ./~'/ ..~...- ,,/,/'/ ./,,/' 1C-21l3 (9618-1293;) I ~_.- 1 I I II 6650 I I I 1 1 6700 1 I II 1 6750 / /' / ,,//,/ 1C.21 (12511-15634) I I I I 1 1 6800 1 I I I r 6850 1 I 1 r 1 6900 1 I 1 II 6950 "",/ ConocoPhillips Alaska Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: Plan: 1C-21 WeJlbore: 1C-21 Design: 1C-21 Sperry Drilling Services 1750- 875- 0- C) ;:0 - G) - z » r ·875- '2 -1750- ~ - o LO ,... ~ ·2625- +' :c 1:: o _ ~ -3500- I :c 'S o C/) -4375- -5250- -6125- -7000- -7875- HALLIBURTON . ~sïs" I~·--~--_· \;;;l t.1 C-21 L2 (9986 - 1040.!!!J ~-7-···-~ ~-~-~--;-¡ l1C;-21L3 (9618-12933ll 7-- n - LEGEND . T ^ M Azimuths to True North ¿Magnetic North: 24.34' Magnetic Field Strength: 57604.3nT Dip Angle: 80.77' Date: 6f712005 Model: BGGM2004 -er- Plan: 1C-21, 1C-21L1, 1C-21L1 VO -+ Plan: 1C-21, 1C-21L3, 1C-21L3 VO -B- Plan: 1C-21, 1C-21L2, 1C-21L2 VO -er- 1C·21 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -875 0 875 1750 2625 3500 4375 5250 6125 7000 7875 8750 9625 10500 11375 12250 13125 14000 14875 West( - )/East( +) (1750 ftlin) . Conoc6Phillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 22, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Permits to Drill for 1 C-21 L 1, 1 C-21 L2 and 1 C-21 L3 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Permits to Drill for the three unplanned laterals for 1 C-21. We are submitting a separate permit to drill for each lateral pursuant to recent email communications with Tom Maunder and Steve Davies. The original1C-21 permit to drill application was approved and then revised to a deeper TO (205-034). All original attachments apply to these three laterals. Attached are the as-drilled preliminary directional surveys for each of the three laterals. Also attached are drawings describing the three laterals' relationship with the final1C-21 wellbore that will be cased with a 4-1/2" slotted liner. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. Sincerely, ~~ R. Thomas . Kuparuk Drilling Team Leader CPAI Drilling -=- RT/skad Re: FW: [Fwd: RE: IC-21 Open Hole Sidetracks in the Horizontal In... . . Tim and Pat: BACKGROUND To briefly recap events that occurred during drilling of the KRU IC-2I well: 1. While ConocoPhillips Alaska, Inc. ("CP AI") was drilling the proposed KRU 1 C-21 well, the wellbore exited the top of the reservoir sand into the overlying shale; 2. CPAI pulled back about 230' and performed an open-hole course correction; 3. due to steering difficulties, the wellbore again approached the top of the reservoir sand; 4. CPAI pulled back 800' and performed a second open-hole course correction; 5. based on encouraging drilling results, CPAI then obtained verbal approval trom the Commission to lengthen the well to a new bottom-hole location that is more than 500' trom the permitted bottom-hole location; and 6. CPAI submitted this permit to drill application for the new bottom-hole location. DISCUSSION The following addresses Items 1 through 4, above. The Commission is currently processing an application for a permit to drill that addresses Items 5 and 6. While drilling KRU IC-2I (permit to drill no. 205-034), CPAI made two intentional course changes to ensure that the well reached it's objective within the reservoir sand. These course changes involved pulling back and re-directing the well course while in open hole. They resulted in two orphan wellbore segments that were drilled at least partly within reservoir sand. The first orphan wellbore segment is 230' in length. Of that, approximately 70' lies within reservoir quality Kuparuk sand. The second orphan wellbore segment is 800' long, and it lies entirely within the reservoir sand. These orphan wellbore segments were not plugged and they will not be completed with slotted liner, but the operator expects them both to remain open and contribute to production trom the well. Both ofthese orphan wellbore segment clearly function as "well branches" as discussed and defined in Commission regulations 20 AAC 25.005(e), 20 AAC 25.990(73) and 20 AAC 25.990(74). They each access a separate objective within the reservoir sand, whether intended or not. They were not plugged, and they are expected to contribute to production. If a plan for the current KRU 1 C-2I primary wellbore and it's attendant orphaned wellbore segments were submitted to the Commission in advance, it clearly would have been approved as a primary wellbore with two well branches. These would have been designated, respectively, KRU IC-2I, KRU IC-2ILl and KRU IC-2IL2. Separate permit to drill applications would have been required for the primary wellbore and for each well branch, and each would have been issued a separate permit to drill, permit to drill number and API number. RECOMMENDED PROCEDURE The Commission's purpose is clear record keeping. Our business practices and computer databases require a unique API number for each well branch, and that each API number has an associated, unique permit to drill number. Accordingly, the following procedure should be followed: 1. Submit a permit to drill application for the 230' orphan well section as the KRU I C-2ILl multilateral well branch, following the abbreviated procedure described in 20 AAC 25.005(e) - attached below - and noting that the $100 fee is not required; and 2. Submit a permit to drill application for the 800' orphan well section as the KRU IC-2IL2 multilateral well branch, following the procedure described in 20 AAC 25.005(e) and noting that the $100 fee is not required. 3. Upon receipt of the approved permits to drill, CPAI must use these names and the assigned permit to drill and API numbers for all subsequent reporting purposes. 4. CPAI must re-Iabel any data from the orphaned well sections with the assigned name, permit to drill number and the API number. lof5 6/27/2005 I :45 PM Re: FW: [Fwd: RE: IC-21 Open Hole Sidetracks in the Horizontal In... 5. To close out Commission's ~les for these orphaned well segments, CP!.Ould also submit a Completion report (Commission fonn 10-407) with attendant, required data for each of the orphaned wellbore segments. I realize that this is a lengthy, bureaucratic reply, but since these orphan well bore segments will contribute production, for the sake of consistency and clear record keeping they must be treated as laterals, even though they will be pennitted after-the-fact. They can't be considered plug-backs because they weren't plugged-back, and they are expected to remain open. A while back when I worked for a company that was developing the Kuparuk, 70' of pay in a well was a considered a success. Remember, 70' of open hole in a reservoir is as nearly as long as the Unocal Building is tall! Thanks for your help, Steve Davies Petroleum Geologist AOGCC 907-793-1224 ---------------------------------------------------------------------------- 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. ---------------------------------------------------------------- Billingsley, Tim A wrote: Steve, The first try did not make it to you. Let us know if this one makes it. Tim Billingsley 265-6531 -----Original Message----- From: Perfetta, Patrick J Sent: Tuesday, June 07, 2005 5:05 PM To: 'steve davies@admin.state.ak.us' Cc: Seitz, Brian; Allsup-Drak~sharon K; Thomas, Randy L; Billingsley, Tim A Subject: RE: [Fwd: RE: 1C-21 Open Hole Sidetracks in the Horizontal Interval] Steve- Here are the answers to your questions. 1) In the initial 230' of abandoned wellbore, approx. 70' was sand. 2) The abandoned 230' of wellbore did TD in shale 3) This 70' of sand will likely remain open 4) If the shale section collapses, I would expect most of the 70' to stay open. 5) The 800' of abandoned wellbore was drilled entirely in sand 6) We do expect this portion of wellbore to remain open As far as TD goes, we should hopefully reach it within the next few days. In addition to the above, we had one additional open-hole sidetrack, as we popped out the top of the reservoir last evening. In this event we 20f5 6/27/2005 1:45 PM Re: FW: [Fwd: RE: lC-2l Open Hole Sidetracks in the Horizontal In... abandoned approx. 300,4IIÞwellbore, 200' of which was sand~his portion of the well TD'd in shale and we would expect a similar scenario as before (it's likely that the 200' of sand will remain open). Let me know if you have any questions, and what your thought is on the naming convention of these three events. Thanks, Pat Perfetta Geologist GKA Development ConocoPhillips Alaska 700 G Street Anchorage, Ak 99501 Phone: 907-263-4411 Cell: 713-446-5359 Fax: 907-265-1158 -----Original Message----- From: Lowry, Scott L Sent: Monday, June 06, 2005 11:03 AM To: Perfetta, Patrick J Cc: Seitz, Brian; Allsup-Drake, Sharon K; Thomas, Randy L; Billingsley, Tim A Subject: FW: [Fwd: RE: lC-21 Open Hole Sidetracks in the Horizontal Interval] Pat, Can you assist here? Thanks, Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.us] Sent: Monday, June 06, 2005 10:10 AM To: Lowry, Scott L Cc: Thomas Maunder Subject: Re: [Fwd: RE: lC-21 Open Hole Sidetracks in the Horizontal Interval] Scott, To briefly recap what happened: 1. CPAI first drilled the proposed lC-21 (Permit to Drill 205-034), but 2. the well bore popped out of the top of the sand into the overlying shale, so 3. CPAI pulled back about 230' and performed an open-hole sidetrack, but 4. due to steering difficulties, CPAI again approached the top of the target sand, so 5. CPAI pulled back 800', and 6. CPAI performed a second open-hole sidetrack. I have a few questions for you: How much sand was drilled in the initial 230' of abandoned hole? Did the abandoned 230' of well bore TD in shale? Do you expect the sand intervals to remain open? If the well bore collapses in the shale section, how much of the 230' 30f5 6/27/20051:45 PM Re: FW: [Fwd: RE: IC-21 Open Hole Sidetracks in the Horizontal In... . . well bore will be open in the target sand interval? Was the 800' of abandoned well bore drilled entirely in sand? Do you expect this section of abandoned well bore to remain open? When do you anticipate reaching TD in the current well bore? Thanks, Steve Davies Thomas Maunder wrote: Steve, What are your thoughts here?? Scott says it is likely that the "left" section will produce. I kind of lean toward lateral. Would the lost section become L1? Tom -------- Original Message -------- Subject: RE: 1C-21 Open Hole Sidetracks in the Horizontal Interval Date: Fri, 03 Jun 2005 17:07:24 -0800 From: Lowry, Scott L <Scott.L.I,owry@conocophillips.com> To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com>, Billingsley, Tim A <Tim. A. Bi.11ingsley@conocophi.11ips.com> Tom, The "left" hole section will not be cased. The "well section" will be cased with a slotted liner. We still have one to two weeks left on the well depending on how successful we are at staying on bottom. We have some time to wait for Steve's response. Thanks, Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* Friday, June 03, 2005 2:36 PM *To:* Lowry, Scott L *Subject:* Re: 1C-21 Open Hole Sidetracks in the Horizontal Interval Scott, I think the key words here are "approaching the top of the sand", this implies you were still in it and your conclusion that the interval is likely to contribute production is probably true. Will you be setting a slotted liner in the "well section" you ultimately keep?? This "left" hole section is probably best called "L1". Steve Davies is not here today. I need his guidance on this. The 4 of5 6/27/2005 1:45 PM Re: FW: [Fwd: RE: lC-21 Open Hole Sidetracks in the Horizontal In... . nomenclature conventions do operation, however I do see not have an effect on the need for having a YOu~timate name that logs etc can be labeled. When do you anticipate that ultimate operations will be completed?? Tom Maunder, PE AOGCC Lowry, Scott L wrote: Tom/Steve, On well lC-21 (PTD # 205034), we popped out of the top of the sand into shale and performed an open hole sidetrack, abandoning approximately 230' of open hole without plugging the interval. This section will probably cave in at some point with shale and I don't believe it will contribute to the production of the well. I would assume we would call the abandoned interval lC-21 PBl. We are currently working on a 2nd open hole sidetrack. Due to steering difficulties we were approaching the top of the sand. We are pulling back approximately 800' to perform a sidetrack to try to get lower in the section. The abandoned interval here probably will contribute to the production on this well. I am not sure if this abandoned interval will be PB2? Please advise. Thanks, Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 «Scott L Lowry (ª~g.tt.L.Lowry@c0!l0cophillips.c~~) .vcf» 5 of5 6/27/20051:45 PM I C-21 Open Hole Sidetracks in the Horizontal Interval . . Tom/Steve, On well 1 C-21 (PTD # 205034), we popped out of the top of the sand into shale and performed an open hole sidetrack, abandoning approximately 230' of open hole without plugging the interval. This section will probably cave in at some point with shale and I don't believe it will contribute to the production of the well. I would assume we would call the abandoned interval 1 C-21 PB 1. We are currently working on a 2nd open hole sidetrack. Due to steering difficulties we were approaching the top of the sand. We are pulling back approximately 800' to perform a sidetrack to try to get lower in the section. The abandoned interval here probably will contribute to the production on this well. I am not sure if this abandoned interval will be PB2? Please advise. Thanks, Scott L Lowry Operations Drilling Engineer ConocoPhillips Alaska, Inc. Office: 907-265-6869 Cell: 907-240-5322 «Scott L Lowry (Scott.L.Lowry@conocophillips.com).vcf» Lowry, Scott L <Scott.L.Lowry((i)conocophillips.com> SENIOR ENGINEER CONOCOPHILLIPS COMPANY UPSTREAM 1 of 1 6/27/2005 1 :50 PM . . KRU 1C-21L2 - 205-101 Note to File The KRU lC-21 well and its lateral well branches have a complicated history. Drilling operations began May 14,2005. A 13-112" hole was drilled to a depth of 5,690' measured depth ("MD") and 10-3/4" casing was run to 5,680' MD. A 9-7/8" hole was drilled to a depth of 9,160' MD, and 7-5/8" casing was run to 9,154' MD. A 6-3/4" hole was drilled, and a total depth of 10,336' MD was reached on May 31, 2005. The operator pulled back up-hole, and made a course correction beginning at 10,060' MD that same day. Drilling continued to a total depth of 10,408' MD and on June 2nd, the operator made the decision to pull back up-hole again for a second openhole sidetrack. On June 2nd, drilling began again at 9,600' MD, and continued to a total depth of 12,933' MD on June 6th. The operator again elected to pull back up-hole and begin a third openhole sidetrack. On June 6, drilling began again at 12,560' MD, and continued until the total depth of the well (15,634' MD) was reached on June 15, 2005. Slotted liner measuring 4-112" in diameter was then run from 8,993' MD to 15,624' MD Because none of the openhole sidetracks were plugged back, and they all traverse oil-bearing reservoir rock, they are expected to contribute to production from the well. For proper record- keeping purposes, each lateral well branch required a separate pennit to drill. The spud date for this multilateral well branch is assigned as May 31, 2005, the day drilling occurred at the kick-off-point of 1O,060'MD, the point where this branch departs from the KRU lC-21Ll well branch. This well branch was drilled to a total depth of 10,408' MD, 6,533' TVD on June 2, 2005. KRU lC-21 and the associated laterals were equipped and conditioned to produce on June 22,2005, which is the assigned completion date. The schematic diagrams (attached) illustrates tenninology and dates applied to the KRU lC-21 well and its multilateral well branches. Steve Davies August 10, 2005 VI I s KRU lC~21 Date: May 14,2005 Reached June 6 "'" "" TVD to KRU lC-21 205-034 KRU I C-21 L1 205-100 KRU IC-21L2 - 205-101 KRU 1 C-21 L3 205-102 No.3 Date TD Reached: June ¡ 5 TD: TVD 10, KRU 1 C-21 & Laterals lature KRU IC-21 Date: 2005 150' TVD KRU IL3 ~ I KOP: to KRU 1 C-21 - 205-034 KRU IC-21L - 205-100 KRU lC-2IL2 - 205-101 KRU IC-2IL3 - 205-102 I. KRU - 205-100 2. KRU lC-21L2 - 205-101 3. KRU IC-2IL3 - 205-102 4. KRU IC-21 - 205-034 Sidetrack No. KRU IC-21 Date TD Reached: June 5 Starts at: Surface TD: TVD 2005 I IC 1 s to KRU - 205-034 KRU IC-21U - 205-100 KRU JC-21L2 205-101 KRU J C-21 L3 205- 02 " KRU JC-21 Date: May 2005 150' TVD 3. 4. KRU JC-21 Date TD Reached: June 15 Starts at: Surface TD: 15,634' TVD Wen I Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 C·21 L2 Program DEV Well bore seg PTD#: 2051 01 0 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV /1-0IL GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 1 P~HmiUee attaçheø . . . . . . . . _ . . NA. ..... l'IotJequiJedper 20AAG 25..005(e):ul1planned bralJc.h.of KBU 'I C-21th<lt wa.sleft QperH!.js.c.apabJe. Qf prodLJciioll 2 .Leas.enumberappropriale......... _ . . . . . . . . . . . . No . Correçt.ed '10-407; .surface Joçatiol1 of weJI Js. ilJ ADL 025649; ihi~ unptalJneø JateraUie~ il1 ADL 028.242._ 3 .U.nique weltn.am.e.al1d lJumb.er . . . . . . . . . _ _ . . . . . . . . . . . . . _ _ . . . _ . . . . . . _ _ .Y.e$ . . . . . . . . . - . . . . . . . . . . . . . - . . - . . . . . . . . - . - . . . . . . . . . . - - - - . . . . . . . . . - . . . . . . . . . . . . . 4 WelUQcat.ed in a_ d_efjne.dpool . . . . _ . . . . Y.e$ . . _ . . . Kuparuk River Qil 1='001, governed by Con.servatipl1 Order 1'10. .432G . . . . . . . . . . . 5 WeIUQC<lt.ed prpper .distance. from driJling unitbound.ary . . . . . . . . . . . . . . Y.e$ . . ConservatiolJ Ord_er 1'10. .432G co.ntains .no spa.cing restriçtjon$ wiih. respeçtto drilling .ul1it boul1daJie~. . 6 We.IUQcated prpperdistance. from other welJs. . . . . . . _ . . . . . . Y.e$ . . . . . ConservatiolJ Order 1'10. .432G bas.no Jnten.veILspac;illg.re~trJctiOlls, - - . . . . . - . . . . . 7 .S.utfiçient.açreage_ayail<lble indJillilJg unJt. . . . . . . . . . . . . . . . . Y.e$ . . . . . . Con.servatiolJ Ord.er 1'10. .432G bas no In_ten.veILspac;ing.re~trictiOlls, WelJbprewill bemQre thalJ 500' fJQm . . 8 Jfd.eviated, Js weJlbQre platjncJuded _ . . . . . . . . . . . . . . . . . . .. Y.es. . . an. external prope.rty [in.ewh.ereownership orJandownership.chan.Qes.. - - . . . . 9 .Oper.ator only affected party. . . _ . . . . . _ _ _ . . . . . Y.es. _ . . . . . - . . . . . - . . . . . - - - . . . . .. ..... - . . . . . . 10 .Oper.ator bas_apprppriate.Qol1d inJorçe . . _ . . . . . . _ _ . . . . . . . . . . . _ _ _ . . . . . . . . .Y.es _ _ _ _ . . . . . . . - - . . . . . . . . . - . . - . . . . . . . . - . . - - - . . . . . . . - . . . . . - - . . . . . . - - . - . . - . . . . . . . 11 P.ermil c.a11 be iSSlIed witbQut conservation order. . . . . . . . . . . . . _ . _ . . . Y.es. . - . . . . . . - . . . . . . . . . . . . . . . . . . - - . . . . 12 P.ermilc.al1 be iS$lIed witbQut ad.milJistratilleapprpvaJ . . . _ _ . . . . . . . . Yes. . . . . . . . . . - - . . . . . . . - . . . . . . 6/28/2005 13 Can permit be approved before 15-day wait Yes 14 WeIUQcatedwithinareaalld.strata.authorizedby.llJjectioIJOrd.er# (p uti 0# in.cpmm.elJts) (For. NA... _..... -...... -..... ........ -...... 15 AJI welJs_ within .1 l4.mile.are.a.of reyiew jd.elJtified (Fpr ~ervJc.e.w.ell only). . _ _ _ _ . . . . . . . . . .NA. . _ _ _ . . . . . . . . _ . . . . . . . . . . . - - - . . . . . . . - . - - - - . . . . . . . . . . . - - - . . . . . . . - . - - . - . . . . . . . . 16 PJe.-produ.ced il1jector; øur<ltiQn.of pre-proøuctiOIJ l.e$s. than 3 montbs (For.service well onJy) . . NA. . . _ _ _ . . . . . . . . . . - - . . . . . . - . . . . . . 17 ACMPFindjng.ofCon.sistel1cyhas bee.nJ~sued.for.tbis pr.ojeçt . . _ . . . . . . . . NA. _..... UIJPJanl1ed_later.atweJI.branch . . . . . . . . . . . . . . - 18 .C.ol1ductor string.PJovided . _ _ . . . . . . . _ _ . _ . . . . . . . NA. _ . . . Conductor _setilJ molherbore 1 C~2'1 í205-.034). _ _ . . . . .. .............. 19 .S.ur:fac.eca~ingpJotec;t~ alLknown USDWs . . . . . . . . . . . _ . . . . . . . NA. _ . . J\ll aquife.r~ ex.empled,AOCFR 1<47.1 02 (b).(3).. - - . . . . . . - . . . . . . 20 .CMT vpt adequate.to çirc_u tate. o.n .cOnductor. & SUJf.csg . . . . . . . . _ . . . NA. .. ... Surface ca.sing setJn motberbore.. . . . . . . . - . . . . . . . - . . . . . . . 21 .CMTvotadequate.totie-inlongstril1gto_surfç~g. ........ _.... NA...... .Prodllctionc.asil1gse.tin.motheJbore... - -..... - -...... 22 .CMTwilJ coyer.aU klJow.npro.ductiYe borizon.s. _ . . . . . . . No. . . . . . . . Ope.nhpl.eJIl produçtiv.esand, _ . . . . . . . . . . . . . 23 .Ca$il1g de.sigl1s ad.equa.te fpr C,T" B.&.permafro$t . . . . . .. ..... _ . . Y.e$ . _ _ . . _ . . . - - - . . . . . . - . . . . . - - - . . . . . . . . - - . . . . 24 Mequ<lte.tan)<age.one.serve pit . _ _ . . . . _ . . . . . . . . Y.es . . . Big Js. e.quippe.dwitb sleelpjts. . NQ rese.rve.pJtplanlJe.d, AU waste to.approve.d .anlJuJlIs.or Ctas~ II well, . . . . . 25 Jfa.re·øriIL bas a to-403 fQr abandonment be.e1J apPJoved . _ . _ . . . . . . . _ . . . . NA. . . . . . . . . . . . . . . - - . . . . - . . . . . . . . - . . . . . . 26 Aøequ<lteweUbore. ~eparatJo.npropo~eø. . . . . . . _ . _ _ . . . . . . . . _ . _ _ _ . . . . . . . . . .Y.es _ . . . . . . WelJ co.urse W<lS reøiJecteø Jor mor {ayorable ph~G.emeot, .1-2 basJ_90'.grQsslengtb.. . . . . . . . - . . - . - - - - . - 27 Jf.divelÍer Jequired, does it meet reguJations. . . . .. ........... . _ . . . . . .NA. . BOP $tack.aJready In plac.e.. . . - - - . . . . . . . . . . . . - . . . . . . . . 28 .DJiUilJgfJuidprogramsc;hematic&equipJi$tadequale........ ....... Y.e$. _L2.was.drllkked.withoutproblems.Ade~uateMWempIQyed... -.................... 29BQPEs,d_o.they meelreguJation . . . . . . _ . . . . . . . _ . . . . . . . . . . Y.es . . . . . . . - . . . . . . . . . . . . . . . 30 .B.OPEpre.ss ratiog appropriate; test to (pu.t psig in.commelJt$) ....... .......... Ye$. . . . . . . M.tI.SP calc;uJaiedat 2473 psi, 3500.pJs.approprjate..GPAJ u~ualJy.tes.t~ to.5000.p.si.. 31Choke.manjfold compJies w/.tI.PI. RF'-53 (May 84) . . . . . . _ . . . . . . _ _ _ Y.e$ . . . . . . . . . . . . . . . . . . . . . . . . - - . . . . .. .... - . . - . - - . . . . 32 WQrk will occur withOLJtoperatjon.sbutdo.w.n. . . . . . _ . . . . . . _ _ Y.e$ . . . . . . . . . . . . . . . . . . . . - - . . . . . . . . . . . . . . 33 J~pre~el1ce.ofH2SgasproQable_.. _ _. _..... ............. Y.e$...... H2SisrepolÍed.o.n.1Cp<ld.MLJd~houldpr.eçlude.H2.S.0.n.rig.. Righ<l$$e.nsor$alJd.alarm$. 34 Meçba.nicaLcoodJt[oI1P{We.II$within.tl.OB yerified (for.s.ervicewe 1J0nJy).... ........ NA... ........ -................... - - -.... Administration Appr SFD Date Engineering Appr Date TJrt ?:::r05 Geology Appr SFD Date 6/27/2005 Geologic Commissioner: D1s ~ D - - - - - - - - - - - -- . - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - 35 P.e(ll)il cal1 be iS$lIed w!o. hydrogen sulfide meaSUres. _ . . . . . . 36 D.atapJeseoted on. pote.ntial oveJpre~sure .zones. . . _ . . . 37 .S.eismicanalysJs of sbaJlow gaszPlJes _ . _ . . . . . . . . . . . . . 38 .S.eabedconditioo survey .(if off-shore) . . . . . . . . . . . . . . 39 . Conta_ctnam.elphOlleJorweekly progre~s.reports [exploratory .0111y] . . _..... No.. . . . Y.es. ..NA . . . . . . NA. . . . NA. . KBU j C-Pad wellshalle.me.aSLJred 20 -90ppmH2S, . _ _ . . . . . . . . _ . . _ . Expected r.ese.rvoir pre.S$uJe is 7,3 -9.4. ppg EMW; wilLb.e .drilJed witb 8.5 - '10.0 ppg mud.. . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - -- Date: Engineering Comm issioner: Øì~e' Date The purpose of this permit to drill is clear record keeping. It is needed for proper tracking of KRU 1 C-21 L2, an unplanned ß lateral well branch that was drilled and then subsequently vacated when the ConocoPhillips Alaska, Inc.'s drilling team pulled O~~ back up-hole and made an open hole course correction. This well branch is expected to remain open and will contribute to , r--!'roduction from the KRU 1 C-21 well. AOGCC's regulations require a unique name and API number for each well branch. Our OJ business Dractices and databases reauire an associated Dermit to drill number for each API number. Date tie (IV' ~ ¿'-¿7-tJ5' . . Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ~u~J /(1:>' \ ~).-~o q Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 21 13:38:06 2005 Reel Header Service name............ .LISTPE Date.................... .05/09/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1C-21L2 500292325361 ConocoPhillips Alaska, Inc. Sperry Drilling Services 21-SEP-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003706651 P. SMITH F. HERBERT MWD RUN 5 MW0003706651 P. SMITH F. HERBERT MWD RUN 6 MW0003706651 P. SMITH F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MW0003706651 C. COCHRAN G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 11N 10E 1601 1191 101.80 60.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS . 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 16.000 10.750 7.625 . DEPTH (FT) 116.0 5680.0 9153.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 1C-21 AT 9630'MD/6546'TVD BY MEANS OF AN OPENHOLE SIDETRACK. 4. MWD RUNS 1 & 3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. NO PROGRESS WAS MADE ON RUN 2. RUN 7 WAS A FAILED OH SIDETRACK ATTEMPT. 5. MWD RUNS 4 - 8 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE-WHILE-DRILLING (PWD). MWD RUNS 5, 6, 8 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). MWD RUN 5 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUNS 6 & 8 INCLUDED AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 4 - 6, 8 REPRESENT WELL 1C-21 L2 WITH API#: 50-029-23253-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10408'MD/6532'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 (DEEP SPACING) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.75" MUD WEIGHT: 9.2 - 9.7 PPG MUD SALINITY: 3000 - 29,000 PPM CHLORIDES FORMATION WATER SALINITY: 11,500 PPM CHLORIDES FLUID DENSITY: 1.0 G/ce MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI PEF RHOB DRHO $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 5652.5 5660.0 5660.0 5660.0 5660.0 5660.0 5690.5 9076.5 9077.0 9077.0 9089.5 9153.5 9153.5 STOP DEPTH 10340.0 10347.0 10347.0 10347.0 10347.0 10347.0 10408.0 10312.0 10312.0 10312.0 10327.0 10327.0 10327.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 4 5 6 8 MERGED MAIN PASS. $ MERGE TOP 5652.5 9160.0 9700.0 10107.5 MERGE BASE 9160.0 9700.0 10107.0 10408.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN . . Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5652.5 10408 8030.25 9512 5652.5 10408 ROP MWD FT/H 1 402.36 137.287 9436 5690.5 10408 GR MWD API 27.77 423.53 116.446 9376 5652.5 10340 RPX MWD OHMM 0.3 702.39 4.96376 9375 5660 10347 RPS MWD OHMM 0.36 1634.5 6.31502 9375 5660 10347 RPM MWD OHMM 0.33 2000 12.101 9375 5660 10347 RPD MWD OHMM 0.72 2000 21.9654 9375 5660 10347 FET MWD HOUR 0.19 125.53 2.8184 9375 5660 10347 NPHI MWD PU-S 18.96 58.97 27.5773 2467 9077 10312 FCNT MWD CNTS 114.4 642.94 385.002, 2471 9077 10312 NCNT MWD CNTS 13446.1 28510.7 22724.2 2472 9076.5 10312 RHOB MWD G/CM 2.004 3.555 2.43149 2348 9153.5 10327 DRHO MWD G/CM -0.241 0.994 0.0694945 2348 9153.5 10327 PEF MWD BARN 0.87 14.84 3.273 2476 9089.5 10327 First Reading For Entire File......... .5652.5 Last Reading For Entire File.......... .10408 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPD FET RPM ROP $ 2 . header data for each bit run in separate files. 4 .5000 START DEPTH 5652.5 5660.0 5660.0 5660.0 5660.0 5660.0 5690.5 STOP DEPTH 9121.5 9114.5 9114.5 9114.5 9114.5 9114.5 9160.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 24-MAY-05 Insite 66.37 Memory 9160.0 5690.0 9160.0 46.2 81.2 TOOL NUMBER 097054 10505932 9.875 5680.0 Water 10.10 83.0 8.5 400 3.4 Based 2.300 1.110 1.940 1.970 65.0 142.0 65.0 65.0 . . Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.................. . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5652.5 9160 7406.25 7016 5652.5 9160 ROP MWD040 FT/H 1 398.91 139.67 6940 5690.5 9160 GR MWD040 API 27.77 423.53 136.581 6939 5652.5 9121.5 RPX MWD040 OHMM 0.76 9.82 2.83356 6910 5660 9114.5 RPS MWD040 OHMM 0.78 1633.39 3.30911 6910 5660 9114.5 RPM MWD040 OHMM 0.33 1592.93 3.64607 6910 5660 9114.5 RPD MWD040 OHMM 0.72 2000 8.34234 6910 5660 9114.5 FET MWD040 HOUR 0.19 95.6 1.63099 6910 5660 9114.5 First Reading For Entire File......... .5652.5 Last Reading For Entire File.......... .9160 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 5 .5000 FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF FET RPD RPM RPS RPX GR DRHO RHOB ROP $ . START DEPTH 9076.5 9077.0 9077.0 9089.5 9115.0 9115.0 9115.0 9115.0 9115.0 9122.0 9153.5 9153.5 9160.5 # 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 SLD CTN EWR4 $ # STOP DEPTH 9614.0 9616.0 9614.0 9629.0 9649.0 9649.0 9649.0 9649.0 9649.0 9641.5 9629.0 9629.0 9700.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record . 29-MAY-05 Insite 66.37 Memory 9700.0 9160.0 9700.0 86.0 92.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 FIo-pro 9.20 93.0 9.9 300 3.4 .300 .190 .200 .370 68.0 113.0 68.0 68.0 . . Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 MWD050 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9076.5 9700 9388.25 1248 9076.5 9700 ROP MWD050 FT/H 1. 51 402.36 139.545 1080 9160.5 9700 GR MWD050 API 28.91 83.33 61.357 1040 9122 9641.5 RPX MWD050 OHMM 0.3 702.39 11.165 1069 9115 9649 RPS MWD050 OHMM 0.36 1634.5 16.9546 1069 9115 9649 RPM MWD050 OHMM 0.36 2000 63.7255 1069 9115 9649 RPD MWD050 OHMM 7.62 2000 118.64 1069 9115 9649 FET MWD050 HOUR 0.21 125.53 11. 9174 1069 9115 9649 NPHI MWD050 PU-S 21.12 58.97 29.7496 1071 9077 9614 FCNT MWD050 CNTS 114.4 563.2 363.963 1079 9077 9616 NCNT MWD050 CNTS 13446.1 26891.8 22170.1 1076 9076.5 9614 RHOB MWD050 G/CM 2.266 3.555 2.44423 952 9153.5 9629 DRHO MWD050 G/CM -0.241 0.994 0.048521 952 9153.5 9629 PEF MWD050 BARN 1. 02 14.84 4.02765 1080 9089.5 9629 First Reading For Entire File......... .9076.5 Last Reading For Entire File.......... .9700 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 . Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI NCNT FCNT PEF DRHO RHOB GR RPD RPX RPS RPM FET ROP $ 4 . header data for each bit run in separate files. 6 .5000 START DEPTH 9614.5 9614.5 9616.5 9629.5 9629.5 9629.5 9642.0 9649.5 9649.5 9649.5 9649.5 9649.5 9700.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 10107.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # 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: 31-MAY-05 Insite 66.37 Memory 10107.0 9700.0 10107.0 90.5 93.7 TOOL NUMBER 87224 154267 10603684 130908 13 .500 9153.0 Flo-Pro 9.20 46.0 9.5 23000 3.3 .200 .120 .220 .320 68.0 118.0 68.0 68.0 . . # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9614.5 10107 9860.75 986 9614.5 10107 ROP MWD060 FT/H 1. 21 321.87 149.385 814 9700.5 10107 GR MWD060 API 41.59 82.43 56.6153 931 9642 10107 RPX MWD060 OHMM 6.46 17.78 11.6346 916 9649.5 10107 RPS MWD060 OHMM 8.59 20.06 13.9016 916 9649.5 10107 RPM MWD060 OHMM 10.81 27.34 15.2238 916 9649.5 10107 RPD MWD060 OHMM 10.77 443.96 16.5099 916 9649.5 10107 FET MWD060 HOUR 0.32 22.37 1.01191 916 9649.5 10107 NPHI MWD060 PU-S 18.96 33.73 26.3568 986 9614 .5 10107 FCNT MWD060 CNTS 272.26 642.94 393.109 982 9616.5 10107 NCNT MWD060 CNTS 18137.9 28510.7 22870.8 986 9614.5 10107 RHOB MWD060 G/CM 2.094 3.309 2.42557 956 9629.5 10107 DRHO MWD060 G/CM -0.15 0.915 0.0997594 956 9629.5 10107 PEF MWD060 BARN 0.87 6.3 2.72907 956 9629.5 10107 First Reading For Entire File......... .9614.5 Last Reading For Entire File.......... .10107 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 . Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM PEF ROP GR RPS RPD FET NPHI FCNT NCNT RHOB DRHO RPX $ 5 . header data for each bit run in separate files. 8 .5000 START DEPTH 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 10107.5 # 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 SLD CTN EWR4 $ STOP DEPTH 10347.0 10327.0 10408.0 10340.0 10347.0 10347.0 10347.0 10312.0 10312.0 10312.0 10327.0 10327.0 10347.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 02-JUN-05 Insite 66.37 Memory 10408.0 10107.0 10408.0 88.3 92.9 TOOL NUMBER 87224 154267 10603684 130908 13.500 9153.0 . # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O . Flo-Pro 9.20 44.0 9.3 28000 3.5 .260 . .130 .230 .260 68.0 147.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 NPHI MWD080 PU-S 4 1 68 32 9 FCNT MWD080 CNTS 4 1 68 36 10 NCNT MWD080 CNTS 4 1 68 40 11 RHOB MWD080 G/CM 4 1 68 44 12 DRHO MWD080 G/CM 4 1 68 48 13 PEF MWD080 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10107.5 10408 10257.8 602 10107.5 10408 ROP MWD080 FT/H 1. 27 272.11 89.4149 602 10107.5 10408 GR MWD080 API 45.99 75.09 59.0991 466 10107.5 10340 RPX MWD080 OHMM 4.03 14.68 9.08898 480 10107.5 10347 RPS MWD080 OHMM 5.18 16.29 11.4145 480 10107.5 10347 RPM MWD080 OHMM 8.62 16.91 12.8861 480 10107.5 10347 RPD MWD080 OHMM 8.88 16.02 13 .189 480 10107.5 10347 FET MWD080 HOUR 0.99 58.08 3.09531 480 10107.5 10347 NPHI MWD080 PU-S 21.29 31.41 24.8381 410 10107.5 10312 FCNT MWD080 CNTS 260.84 555.95 420.95 410 10107.5 10312 NCNT MWD080 CNTS 19095.1 28224.1 23826.1 410 10107.5 10312 . . RHOB MWD080 G/CM 2.004 2.994 2.41681 440 10107.5 10327 DRHO MWD080 G/CM -0.159 0.705 0.0491159 440 10107.5 10327 PEF MWD080 BARN 1.15 6.22 2.6025 440 10107.5 10327 First Reading For Entire File......... .10107.5 Last Reading For Entire File.......... .10408 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/21 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 05/09/21 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.................... .05/09/21 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