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Home My WebLink About205-102 · . 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. d 05 - 1 0 ~ Well History File Identifier Organizing (done) o Two-sided 1111111111111I11111 o Rescan Needed 1111111111111111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA \Øi5¡Skettes, No. ~ o Other, NolType: 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: Project Proofing BY: ~ Dale /;)-0/ 0 Dale 7;-9-?> 0 7 151 1M P &. X 30 = 1.a.o- + --Lfl = TOTAL PAGES-21 (Count does not include cover sheet) 151 o Other:: NOTES: BY: ~ 151 111f Scanning Preparation BY: Date: Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: ~ 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date7/d-~/D7 If NO in stage 1, page(s) discrepancies were found: YES Stage 1 BY: 151 rnp NO BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11I111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 11/1111111111111111 10/6/2005 Well History File Cover Page.doc ~ )../~~ DATA SUBMITTAL COMPLiANCE REPORT 7/2/2007 Permit to Drill 2051020 Well Name/No. KUPARUK RIV UNIT 1C-21L3 Operator CONOCOPHILLlPS ALASKA INC MD 12933- Completion Status 1-01L Current Status 1-01L TVD 6542 - Completion Date 6/22/2005 REQUIRED INFORMATION A~æo~_02~2~;;;/:-c r UIC N --- ---.-- Directional surveW__________ Mud Log No Samples No ~- DATA INFORMATION Types Electric or Other Logs Run: GRlRes Dens/Neu Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc (data taken from Logs Portion of Master Well Data Maint Received Comments 7/29/2005 IIFR 7/29/2005 MWD QQ;! [)'121 C'al..lrlð Ray SKÐ 3lab;liiðå b.i~ho Den!ity OTtJ G9I1lp Theron..' ÞJewtro.n ROP DGR EWR SLD CTN plus Graphics 12864 Open GR EWR4 ASI CNP SLD ROP PWD GeoPilot i Replaces DSN 13291 _ 12933 Open 1/29/2007 LIS Veri, GR, ROP, NCNT, NPHI, DRHO, RHOS w/Graphics -------------- Log Log Run Interval OH/ Scale Media No Start Stop CH 9618 12933 Open 9618 12933 Open 5652 12864 Open 9/26/2005 Name Directional Survey Directional Survey 13291 Induction/Resistivity D Asc D Lis r I ~ I I 13291 LIS Verification 5652 12864 Open 9/26/2005 ~o QiJQ 1/17/2886 p. C Lis 13697 Induction/Resistivity 116 12933 Open 2/22/2006 ~ D Lis 13439 Induction/Resistivity -tC_~~~44~~"d"~O"/Res;'tiv~ Well Cores/Samples Information: 5652 5652 Name Interval Start Stop Sample Set Number Comments Sent Received - GR EWR4 ASI CNP SLD ROP PWD GEOPILOT Replaced by DSN 13439 GR EWR4 ASI CNP SLD ROP ACAL PWD GEOPLOT e DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2051020 Well Name/No. KUPARUK RIV UNIT 1C-21L3 Operator CONOCOPHILLlPS ALASKA INC MD 12933 TVD 6542 Completion Date 6/22/2005 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMAl:.ION Well Cored? y~ Daily History Received? ~ 'G/N Chips Received? "i"Tf:r- Formation Tops Analysis Received? ~ API No. 50-029-23253-62-00 UIC N Comments: /k Compliance Reviewed By: Date: /TJIJ~ :t.ù'Ð) e - . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21_L1_L2_L3, 1D-28_L1, 1F-OlA, 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: dót../-;)S-C'o 11: ¡¿.{¿../:3D Digital Log Images: 1 CD Rom 50-029-23465-01 ("\O~- IOd. 'dDS--034) {)OS--IDO¡ ÐOS -101 I C/ - 1C-21_L1_L2_L3: I'-/L/?/-I 144"35"" /4L13Io 1'/LI3+ Digital Log Images: 1 CD Rom 50-029-23253-00, 60, 61, 62 1D-28 L1: Digital Log Images: 50-029-23237-00, 60 ;)6<1-~37 1'-/43';;) go4 -.931> Jl-/L/33 1 CD Rom 1F-01A: ;)O~ -Od9 d It.-ILl;)?) Digital Log Images: 50-029-20889-01 3F-19A: ÐtI-{ -ÖI(o fÍ- /L/4 3/ Digital Log Images: 50-029-22680-01 1 CD Rom 1 CD Rom 3H-14B: 0ó6 -Oé)1 ;It t4LICfì Digital Log Images: 50-103-20092-02 1 CD Rom II . . WELL LOG TRANSMITTAL J05- IDO 905 - \ 0 1 ¿)O5 -IDY February 16, 2006 I ø LI'05' 13(vQt.p :;.z..,·Q7 I ¿J/.ç I 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 1C-21 L1 + L2 + L3: LAS Data & Digital Log Images: 50-029-23253-60,61,62 1 CD Rom &foMtn )(9~ID0 . . WELL LOG TRANSMITTAL To: State of Alaska December 27,2005 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West ih Avenue, Suite 100 Anchorage, Alaska 13 L/ .3Of RE: MWD Formation Evaluation Logs 1C-21 L3, c?D5- IÖ?\K-MW-3706651 I LDWG formatted Disc with verification listing. API#: 50-029-23253-62 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: 1/31/Dlp Signed: (!;~/~') Note: This data replaces any previous data for welllC-21 L3. . 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 1C-21 L3, . September 23,2005 AK-MW-3706651 1 LDWG formatted Disc with verification listing. API#: 50-029-23253-62 *r~~Ò¡1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: À~ S~~\- ~ aifj Signed: a ò \':fCS-:L- · STATE OF ALASKA I ~ECEIVED ALASKA Oil AND GAS CONSERVATION COMM SION AUG 0 2 Z005 WELL COMPLETION OR RECOMPLETION R~J~~Q~T"AN_D LOG. 1 a. Well Status: Oil 0 Gas U Plugged D Abandoned U Suspended D WAG lJ I u. vv"" ...Ia~~""· 20AAC 25.105 20AAC 25.110 DevA\J¡;ijQl'a~ Exploratory D GINJ D WINJ D WDSPL D No. of Completions Other Service D Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: / ConocoPhillips Alaska, Inc. or Aband.: June 22, 2005 205-102/ 3. Address: 6. Date Spudded: ..I"''''' ~ ~..- 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 ~205 ~4Þ"> 50-029-23253-62 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1601' FNL, 1191' FWL, Sec. 12, T11N, R10E, UM June 6, 2005 / 1 C-21 L3 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 568' FSL, 269' FEL, Sec. 7, T11 N, R11 E, UM 42' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + lVD): Kuparuk Oil Pool 556' FSL, 173' FEL, Sec. 7, T11N, R11E, UM N/A 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + lVD): 16. Property Designation: " I ~ ADL 28242, 25649 Surface: x- 562198 y- 5968638 Zone- 4 -' 12933' MD /6542' TVD TPI: x- 570970 y- 5965604 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x-571067 ~ y- 5965593 , Zone- 4 none ALK 2292 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1928' MD 21. Logs Run: /<01' IZ,s:iíÞ'mD, c.S'$"¿'" 7"""'Þ GRlRes, Dens/Neu ~1> ¡>. þ·o$" 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 42' 116' 42' 116' 24" 9 cu yds High Early 10.75" 45.5# L-80 42' 5680' 42' 4480' 13.5" 776 sx AS Lite, 389 sx LiteCrete 7-5/8 " 29.7# L-80 42' 9154' 42' 6542' 9-7/8" 255 sx Class G 23. Perforations open to Production (MD + lVD of Top and Bottom 24. TUBING RECORD Interval. Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET n/a open hole completion from 12511'-12933' MD 6555'-6543' TVD ./ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) same as 1 C-21 Date otTest Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-Oil RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. 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". rr,:~;';;::1 qlON i iN;';;;, ~ NONE -- ¡ /12-'~"'Z:.!!- 1JID RBDMS BFL AUG 0 8 2005 L:~\"- ~I~, .J Form 10-407 Revised 12/2003 CONTINUED ON REVERSE L 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 C-21 L3 Top Kuparuk C C-4 12835' 12835' 6554' 6554' N/A 3D. 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 7/?/),S- , Signature Title: Greater KUDaruk Area DrillinQ Team Leader Phone Date -r(1?~ 7!o/Vlc:<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: 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: 5/11/2005 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 13-112" 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: 7/5/2005 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: 6.50 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. 5.00 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, 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. 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 Stand back stand and CBU @ 429 gpm @ 1400 psi. Monitor well for 10 min.lstatic. POOH 2 stands and pump dry job. Blow down top drive and POOH to BHA w/ no problems. C/O Bit and MWD Tool. RIH shallow test MWD. Tool Failure. POH. c/o MWD Tool. RIH. Shallow test MWD Tool, OK. M/U De's, Jars, & HWDP, RIH Slip & Cut Drilling Line. RIH to 1,300'. Inspect Drawworks. Drum coolant line parted. POH to repair Drawworks. Repair Draworks Drum Coolant Line. RIH to 1,300' RIH with Bit #2 to 2,839' RIH with Bit #2. M/U top drive, break circulation, wash last 60' to Btm at 4,688'. Hole in good condition. 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. AVG ROP = 120 fph. Circulate and condition Mud. Lower funnel viscosity to 100 s/qt. Monitor well for 10 min. Well static. POH 5 stds, Pump dry job, POH to BHA. Tight spot observed at 1,550'. Work tight spot clean. SLM, no correction to strap. Lay down BHA and clear floor. Down load data from MWD tool. Finish laying down BHA, Clear Rig Floor. Remove hazardous ice build up from derrick prior to running casing. 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. Service Top Drive and Crown. 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. Circulate and condition mud at 45 spm, 350 psi. RIH with 10-3/4" casing to 3,100'. Observed hazardous ice build up in derrick. Remove ice build up from derrick. RIH with 10-3/4" casing to 4,050'. 5/14/2005 17:30 - 00:00 5/15/2005 00:00 - 05:00 05:00 - 00:00 5/16/2005 00:00 - 01 :30 01 :30 - 03:00 1.50 DRILL CIRC SURFAC 03:00 - 08:00 5.00 DRILL TRIP SURFAC 08:00 - 11 :30 3.50 DRILL DEQT SURFAC 11:30 -13:30 2.00 DRILL DEQT SURFAC 13:30 - 14:30 1.00 DRILL TRIP SURFAC 14:30 - 16:00 1.50 RIGMNT RSRV SURFAC 16:00 - 16:30 0.50 DRILL TRIP SURFAC 16:30 - 17:00 0.50 RIGMNT RGRP SURFAC 17:00 - 19:00 2.00 DRILL TRIP SURFAC 19:00 - 21:00 2.00 RIGMNT RGRP SURFAC 21 :00 - 21 :45 0.75 DRILL TRIP SURFAC 21 :45 - 00:00 2.25 DRILL TRIP SURFAC 5/17/2005 00:00 - 03:30 3.50 DRILL TRIP SURFAC 03:30 - 15:30 12.00 DRILL DRLG SURFAC 15:30 - 19:00 3.50 DRILL CIRC SURFAC 19:00 - 19:15 0.25 DRILL OBSV SURFAC 19:15 - 23:00 3.75 DRILL TRIP SURFAC 23:00 - 00:00 1.00 DRILL PULD SURFAC 5/18/2005 00:00 - 01:15 1.25 DRILL SURV SURFAC 01:15 - 02:15 1.00 DRILL PULD SURFAC 02:15 - 03:15 1.00 CASE SFTY SURFAC 03:15 - 05:30 2.25 CASE RURD SURFAC 05:30 - 06:00 0.50 CASE RURD SURFAC 06:00 - 11 :30 5.50 CASE RUNC SURFAC 11:30 -12:30 1.00 CASE CIRC SURFAC 12:30 - 13:00 0.50 CASE RUNe SURFAC 13:00 - 13:30 0_50 CASE SFTY SURFAC 13:30 - 17:00 3.50 CASE RUNe SURFAC Printed: 7/5/2005 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 RUNe 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 CEMEN CIRC 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 CEMEN SFTY SURFAC PJSM with Rig Crew, Cementers, and Truck Drivers. 03:45 - 06:00 2.25 CEMEN 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 CEMEN 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 CEMEN 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 WELCT SURFAC PJSM on NID Divertor System. 10:45 - 14:00 3.25 WELCT 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 WE LeT 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 WELCT SURFAC PJSM, Review CPAI shallow gas flow procedure with rig crews. 16:15 - 23:00 6.75 WELCT 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 WELCT SURFAC Lay down 10-3/4" landing joint. Prepare to N/D hydril annular. 5/20/2005 00:00 - 02:00 2.00 CASE SURFAC N/D 21-1/4" Diverter System. 02:00 - 04:00 2.00 CASE SURFAC N/U FMC Gen 5 Wellhead Equipment. Test seals to 1,000 psi for 10 min. OK. 04:00 - 04:15 0.25 WELCT SURFAC PJSM, Review DDI N/U & Test BOPE Procedure. 04:15 -10:30 6.25 WELCT SURFAC N/U BOPE. 10:30 - 11 :30 1.00 WELCT SURFAC RIU equipment to test BOPE. 11 :30 - 20:00 8.50 WELCT 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: 7/5/2005 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: 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. RTTorq = 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, RlU 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 RUNe 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 RUNe 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 RUNe 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 WI. 160. Recipacating pipe. PJSM onn CMT job. 04:00 - 06:00 2.00 CEMEN 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 CEMEN 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/ 1 Om in. 09:30 - 11 :30 2.00 DRILL OTHR INTRM1 Change Rams, Install Variable 3 1/2" x 6" in Top and 4" Bottom, 11 :30 - 12:00 0.50 RIGMNT RSRV I NTRM 1 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. 102jts. 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,fill 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 1/8"). 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: 7/5/2005 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: 5/28/2005 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,TotaI151 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,Tota1250 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 CEMEN 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 CEMEN DSHO 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 INTRM1 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, ROTWT. 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, RT wt =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 MonitoirWell, 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" MotorW/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: 7/512005 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/ 9,104' 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 highs ide 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 altemate 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. II 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 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: 6/4/2005 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 110,693' 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, RT wt =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/11063 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, RT wt =155, Tq on btm 9k, Torq off btm 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: 7/5/2005 4:13:27 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1C-21 1C-21 ROT - DRILLING D 15CM@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, Rt wt 160K. 60 rpm. Tq on btm = 10K, Tq off btm = 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/O=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 PROD RIU BOPE test equipment. Fill stack and choke manifold with water. 06:30 - 10:00 3.50 WELCT 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 PROD Pull test plug, set wear ring. Monitor well, static. 11 :00 - 13:00 2.00 WELCT 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 MIU 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 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: 7/512005 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: 6/11/2005 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, 1 OK 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, 10K 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. 110-115K, 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: 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: 6/14/2005 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 bOttom. 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: 7/512005 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: 6/16/2005 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: 7/5/2005 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: 6/18/2005 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 4-112" 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 RIU GBR tubing handling equipment. Layout running order in pipe shed for 4-1/2" 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 4 1/2 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 RIU and Displace well W/9.5 ppg. Brine.@ 45spm 250 psi. 07:30 - 09:30 2.00 CMPL TN SOHO CMPL TN MIU 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 CMPLTN 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,OOOpsi. 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 \JUWIII¡i; \ , HALLIBURTON WELL DETAILS: Plan: 1C-21 .~.......... Sperry DrllIIlIIJ Service. eõnocáPhiUi,ps , Ground Level: 60.30 AlàSRa · +NI-S +EI-W Northing Easting Latittude Longitude Slot 1C-21 0.00 0.00 5968637.75 562198.12 70019'29.434N 149°29'44.342W Vertical Section at 109.74' (1500 ftlin) -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 -750 -750 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» 0 Section (VS) Reference: Slot - (O.DON, O.DOE) 0 Measured Depth Reference: 1C-21 Actual@ 101.800 (Doyon 14 (41.5+60.3») . Celculation Method: Minimum Curvature 750 750 1500 1500 LEGEND 2250 -A- Plan: 1c-21,1C-21L1, 1C-21L1 VO 2250 '2 ~ Plan: 1C-21, ~c-21L3, 1c-21L3 VO g ~ "*" Plan: 1C-21 , 1C-21L2,1C-21L2VO (þ 0 ~ 0 I/) 1c-Z1 ;:¡. :::- 3000 3000 [ .<: ã. CJ II) 11> C "ª ~ ~ 3750 3750 ~ 0 > 0 II) ~ ~ ä 4500 1C-21L2 (9986-10408) 4500 5250 5250 6000 6000 è <0 7 5/8" ---<2 ---., 6750 6750 7500 7500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 Vertical Section at 109.74' (1500 Wm) . . COnocoPhimps Alaska WELL DETAILS: Plan: 1C-21 (Wp11) Ex1ønslon Ground level: 60.30 +N/·S +EI.W Northing Eaatlng Latlttuda Longitude Slòt 1c.21 0.00 0.00 5968637.75 562198.12 70019'29.434N 149°29'44.342W REFERENCE INFORMATION Co-ordinate (NIE¡ R&ference: Wèl\ Þlan: 1C-21, TrUè North Vertical (lVD R&ference: 10.21 Actual ~ 101.8011 (Doyon 14 (41.5+60.3» Sèctlon (VS) R&ference: Slot· (O.OON, .OOE). Mèasured Depth R&ference: 10.21 Actual @ 101.8011 (Doyo~ 14 (41.5+60.3» calculation Mathod: Minimum Curvature LEGEND 1 C.21 1C-21L1, 1C-21L1 va 1C-21L3, 1G-21L3 VO 1C-21L2, 1G-21L2 va Plan: 10.21 Plan: 10.21 Plan: 10.21 0-21 (9618-12933) -+- * -å- -S- 1C-21L3 1C-21L2 (9986-10408) HALLIBURTON Ip..-ry DrlIII... "rvle.. 1 C·21 L 1 «()'10336) 7 5/8" 5625 "ê" ~ !£. 6000 t c B 6375 ]J :> <II 2 ¡..; 6150 12375 12000 11625 11250 10875 10500 10125 9750 6750 7125 7500 7875 8250 8625 9000 9375 Vertical Section at 109.74° (750 fIIln) 6375 6000 5625 . . ConocoPhimps AJas'ka 1C·21L2 (9986-10408) WELL DETAILS:.- Plan: 1C-21 (wp11) Extension Ground Level: 60.30 +N/-8 +EI·W Northing Eaating Latlttude Longitude Slot 1 C.21 0.00 0.00 5968637.75 562198.12 70019'29.~N 149°29'44.342W REFeRÈNCE INFORMATION Co-ordInate ~¡ Reference: We" Plan: 1C.'21. Truè North Vertlcel ( D Reference: 1C.21 Actuel @ 101.8Oft (DoyQn 14 (41.5+80.3» Section (VS) Reference: Slot. (0.001-1. Q.OOE) Measuted Depth Reference: 1C.21 Actual @ 101.ê0fl (OoyQn 14 (41.5+60.3») Calculation Method: Minimum Cutveture LEGEND 4- Plan: 1C-21 , 1C-211.1, 1C-21L1 va '"* Plan: 1C-21, 1C-21L3, 1C-21 1.3 va -6- Plan: 1C-21. 1C-21L2, 1c-21L2 va -e- 1C-21 - - 1C-21L1 l1C.2:!ill511-15634) J T""f1 I I I I I 6600 6650 6700 6750 6800 6850 6900 6950 6450 6500 6550 Vertical SecIJon at 109.74' (100ft/In) 6650 6700 6000 6050 6100 6150 6200 6250 6300 6350 6400 HALLIBURTON .p...., Drtlllng ......Ic.. 6400 6450 "2" :ï3 6500 ~ R ~ 6550 B ]¡ :> ~ 6600 F ~... .. ..I· . '. .,. '.. ". ConocoPbI Ups Alå$Ka Project Kuparuk River Unit Site: Kuparuk 1C Pad Well: Plan: 1C·21 WellbOre: 1C.21 Design: 1C·21 Sperry Drilling Services 1750 875 o -875 í? -1750 ~ o It) r-- ~ -2625 ...... .:t.. .s:: 't:: o ~ -3500 ..¿.. :5 ::¡ o CI) 4375 -5250 -6125 -7000 -7875 HALLIBURTON ì ~ LEGEND T -b- Plan: 1C-21.1C-21L1, 1C-21L1 VO -f- Plan: 1C-21 , 1C-21L3, 1C-21L3VO -a- Plan: 1C-21 , 1C-21L2, 1C-21L2VO -à- 1C-21 Magnetic Field Strength: 57604.3nT Dip Angle: 80.77' Date: 6(712005 Model: BGGM2004 -875 875 1750 2625 3500 4375 5250 6125 7000 7875 8750 9625 10500 11375 12250, 13125 14000 14875 o West(-)Æast(+) (1750 ftlin) Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 C 1C-21L3 . Job No. AK-ZZ-0003706651, Surveyed: 6 June, 2005 Survey Report 6 July, 2005 Your Ref: API 500292325362 Suñace Coordinates: 5968637.75 N, '562198.12 E (70019' 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) Surface Coordinates relative to Stucture Referance: 116.73 N, 172.97 W (True) Kelly Bushing Elevation: 101.80ft above Mean Sea Level Kelly Bushing Elevation: 101.80ft above Project V Reference Kelly Bushing Elevation: 101.80ft above Structure Referance &ip&!r"':r"'y-su., DAIL.LING seAVlces A HaUlburton COI'I'Ipln)' Survey Ref: svy2170 Halliburton Sperry-Sun SUlVey Report for Kuparuk 1C - 1C-21L3 Your Ref: API 500292325362 Job No. AK-ZZ-0003706651, SUlVeyed: 6 June, 2005 ConocoPhll/lps 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) (O/100ft) 9618.98 90.460 106.080 6446.04 6547.84 2103.22 S 5707.08 E 5966581.91 N 567922.43 E 6082.07 Tie-On Point 9630.00 90.850 106.550 6445.91 6547.71 2106.32 S 5717.65 E 5966578.90 N 567933.03 E 5.542 6093.07 Window Point 9706.85 84.080 107.630 6449.31 6551.11 2128.86 S 5790.99 E 5966556.96 N 568006.56 E 8.920 6169.71 9800.50 85.520 110.720 6457.80 6559.60 2159.49 S 5879.07 E 5966527.06 N 568094.89 E 3.628 6262.96 9893.72 87.290 113.240 6463.64 6565.44 2194.31 S 5965.33 E 5966492.96 N 568181.43 E 3.299 6355.91 9987.30 88.880 113.040 6466.77 6568.57 2231.07 S 6051.33 E 5966456.92 N 568267.74 E 1.712 6449.27 . 10081.95 87.800 110.990 6469.51 6571.31 2266.53 S 6139.04 E 5966422.18 N 568355.73 E 2.447 6543.80 10174.17 90.010 112.930 6471.27 6573.07 2301.01 S 6224.54 E 5966388.42 N 568441.52 E 3.188 6635.93 10267.36 92.610 111.950 6469.14 6570.94 2336.57 S 6310.64 E 5966353.57 N 568527.91 E 2.981 6728.98 10361.78 94.330 111.830 6463.43 6565.23 2371.70 S 6398.09 E 5966319.16 N 568615.65 E 1.826 6823.16 10454.92 91.720 112.090 6458.51 6560.31 2406.48 S 6484.35 E 5966285.10 N 568702.19 E 2.816 6916.09 10548.24 92.630 111.910 6454.97 6556.77 2441.41 S 6570.81 E 5966250.88 N 568788.94 E 0.994 7009.27 10641.91 95.440 113.290 6448.38 6550.18 2477.32 S 6657.06 E 5966215.70 N 568875.49 E 3.340 7102.58 10734.41 91.130 108.890 6443.08 6544.88 2510.52 S 6743.18E 5966183.21 N 568961.88 E 6.652 7194.86 10828.14 84.950 106.470 6446.28 6548.08 2538.96 S 6832.38 E 5966155.51 N 569051.31 E 7.080 7288.42 10921.82 85.960 108.970 6453.71 6555.51 2567.38 S 6921.33 E 5966127.82 N 569140.49 E 2.870 7381.74 11014.22 86.960 109.130 6459.41 6561.21 2597.48 S 7008.50 E 5966098.45 N 569227.91 E 1.096 7473.95 11108.34 88.090 108.840 6463.48 6565.28 2628.07 S 7097.42 E 5966068.60 N 569317.08 E 1.239 7567.98 11204.45 86.470 109.670 6468.04 6569.84 2659.73 S 7188.05 E 5966037.69 N 569407.96 E 1.893 7663.97 11295.31 87.000 108.880 6473.21 6575.01 2689.67 S 7273.67 E 5966008.46 N 569493.84 E 1.046 7754.68 11387.96 84.240 109.530 6480.29 6582.09 2720.06 S 7360.90 E 5965978.80 N 569581.31 E 3.060 7847.04 11483.34 86.220 109.040 6488.22 6590.02 2751.45 S 7450.61 E 5965948.15 N 569671.28 E 2.138 7942.09 . 11576.17 90.460 108.750 6490.91 6592.71 2781.49 S 7538.38 E 5965918.84 N 569759.30 E 4.578 8034.85 11669.15 94.960 108.860 6486.51 6588.31 2811.42 S 7626.28 E 5965889.64 N 569847.44 E 4.841 8127.69 11762.70 96.940 109.020 6476.82 6578.62 2841.62 S 7714.28 E 5965860.17 N 569935.69 E 2.123 8220.72 11856.34 97.690 108.890 6464.89 6566.69 2871.79 S 7802.12 E 5965830.73 N 570023.78 E 0.813 8313.59 11949.80 94.730 109.060 6454.79 6556.59 2901.99 S 7889.98 E 5965801.25 N 570111.88 E 3.172 8406.48 12043.67 91.040 109.970 6450.06 6551.86 2933.31 S 7978.33 E 5965770.67 N 570200.49 E 4.048 8500.21 12136.82 91.930 110.770 6447.65 6549.45 2965.72 S 8065.62 E 5965738.98 N 570288.05 E 1.285 8593.32 12230.87 87.220 107.400 6448.34 6550.14 2996.46 S 8154.46 E 5965708.98 N 570377.14 E 6.157 8687.32 12324.09 92.070 107.520 6448.92 6550.72 3024.42 S 8243.36 E 5965681.76 N 570466.26 E 5.204 8780.44 12417.57 88.740 104.580 6448.26 6550.06 3050.26 S 8333.17 E 5965656.67 N 570556.28 E 4.752 8873.70 12510.99 85.480 97.400 6452.98 6554.78 3068.04 S 8424.68 E 5965639.65 N 570647.95 E 8.431 8965.85 12603.12 89.870 99.110 6456.71 6558.51 3081.25 S 8515.76 E 5965627.19 N 570739.13 E 5.113 9056.03 12694.96 86.420 94.210 6459.69 6561.49 3091.90 S 8606.89 E 5965617.30 N 570830.34 E 6.522 9145.40 6 July, 2005 - 17:02 Page 20f3 Dril/Quest 3.03.06.008 Halliburton Sperry-Sun SUlVey Report for Kuparuk 1C - 1C-21L3 Your Ref: API 500292325362 Job No. AK-ZZ-0003706651, SUlVeyed: 6 June, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12788.89 96.360 95.780 6457.41 6559.21 3100.06 S 8700.32 E 5965609.91 N 570923.83 E 12883.19 97.120 97.690 6446.34 6548.14 3111.04 S 8793.31 E 5965599.70 N 571016.92 E 12933.00 97.120 97.690 6440.17 6541.97 -. 3117.66S 8842.29 E 5965593.49 N 571065.95 E 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 12933.00ft., The Bottom Hole Displacement is 9375.82ft., in the Direction of 109.422° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9618.98 9630.00 12933.00 2103.22 S 2106.32 S 3117.66S 5707.08 E 5717.65 E 8842.29 E Tie-On Point Window Point Projected Survey 6547.84 6547.71 6541.97 Survey toollJroaram for 1 C-21 L3 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 12933.00 6541.97 MWD+/lFR+MS+SAG (1C-21L1) Dogleg Rate (°/1 OOft) 10.713 2.167 0.000 ConocoPhillips Vertical Section Comment 9236.09 9327.34 9375.67 Projected Survey . . 6 July, 2005 - 17:02 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 L3 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,618.98' MD 9,630.00 I MD 12,933.00 I MD (if applicable) . 14-Jul-05 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 -1 J IÎ Date ) I ~ JJt'Ì Signed·· M,...J! oiJ..J. Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) Â Or - J tJ ¡ ~ 'f;... . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-21 L3 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window I Kickoff Survey: Projected Survey: 9,618.98' MD 9,630.00' MD 12,933.00' 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! Date -; I ~ ~ r Signed -~ ðft.j Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 14-Jul-05 ~ Q ~-- {OÁ rr:!f¿ . . Note to File KRU lC-21 (205-034), KRU lC-21Ll (205-100), KRU lC-21L2 (205-101), and KRU lC-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 lC-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 ofthe well at about 15,573' measured depth ("MD"). 2. KRU lC-21Ll. 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,IOTand 10,408' MD. 4. KRU lC-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 of the KRU lC-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 14,141' MD. 2. While drilling, ConocoPhillips Alaska, Inc. ("CP AI") determined that the well bore had exited the top ofthe reservoir sand into the overlying shale. After reaching a total measured depth of 10,336', CP AI pulled back to 10,101' 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 of the 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 lC-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 permit to drill number. Commission regulation 25.005(e) requires a separate permit to drill for each well branch, and paragraph ( e) specifies that the application for the permit to drill for a well branch need only include information that is unique to that branch. Having unique names, API numbers and permit to drill numbers will ensure proper management of the 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. Steve Davies June 28, 2005 . rn]Jr. i.' :... I..!F.. .1.Jf\ I.·~ ./'.W\ CQ2 ~.rw.,·!.. {ii.A."~ 1U' ir /''-'\ j L.ìì\~ '~\ #d~ \ 'LJ iJl..Jl1::! Lru æJ I Ù Lf\j . AItASIiA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 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-21L3 ConocoPhillips Alaska, Inc. Permit No: 205-102 Surface Location: 1600' FNL, 4089' FEL, SEC 12, T11N, R10E, UM Bottomhole Location: 557' FSL, 175' FEL, SEC 7, T11N, RIlE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The purpose of this permit to drill is clear record keeping. It is needed for proper tracking of KRU 1C-21L3, 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. Steve Davies at (907) 793-1224. DATED thi~ day of June, 2005 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . PERMIT TO DRILL 20 MC 25.005 1 a. Type of Work: Drilllj RedrillU 1 b. Current Well Class: Exploratory U Development oil L:J "-, (.:;Multiple Zone 0 Re-entry 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone [2] 2. Operator Name: 5. Bond: L:J Blanket U Single Well 11. Well NamE! artdNl.lmber: . ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 C-21 L3 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12933' TVD: 6543' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: ÞbZ:"--» SUITace: 1600'FNL,4089'FEL,Sec. 12, T11N, R10E, UM ADL 28242, 2564!:!~ Kuparuk Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1751' FSL, 987' FWL, Sec. 7, T11N, R11E, UM ALK 2292 5/14/2005 Total Depth: 9. Acres in Property: 14. Distance to 557' FSL, 175' FEL, Sec. 7, T11 N, R11E, UM 2469 Nearest Property: 2324' f/KRU Bndry 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest SUITace: x- 562198 y- 5968638 Zone- 4 (Hei9ht above GL): 42' RKB feet Well within Pool: 1 C-26 - 2300' , 16. Deviated wells: Kickoff depth: 9605 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92· deg Downhole: 3189 psig SUITace: 2473 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) 12933' 6543' Casing Length Size Cement Volume MD TVD Structural Conductor 76' 16" 9 cu yds High Early 116' 116' SUITace 5639' 10.75" 776 sx AS Lite, 389 sx LiteCrete 5681' 4480' Intermediate 9111' 7-5/8" 255 sx Class G 9153' 6542' Production Liner PeIToration Depth MD (ft): PeIToration Depth TVD (ft): none none 20. Attachments: Filing Fee 0 BOP Sketch U Drilling Program U Time v. Depth Plot U Shallow Hazard Analysis U Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Billingsley@ 265-6531 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~ Phone ¿é,S-6-83>0 Date b /z"dos n~ nharon 'u_ n. I Commission Use Only Permit to Drill API Number: Permit APproval(f) /:-' See cover letter Number: ;2DS" - /0 2- 50- (J¿Cj- ¿32~3-~"2- Date: <:O/Ú7 for other requirements Cood;ti,", 01 app"wa't1 I I aritples required Yes 0 No~ Mud log required Yes 0 NoH 'ogen sulfide measures Yes~ No 0 Directional survey required Yes ~ No 0 ~hec d~ rA b,'$ð lð5 APP'O''' by ',t I ~'t( APPROVED BY ...-- THE COMMISSION Date: - '-""" f , .. Form 10-401 Revised 06/2004 UR1GiNAl Submit in Duplicate · Halliburton Company. Global Report Survey: Start Date: Company: Tool: Engineer: Tied-to: Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: Kuparuk 1 C Pad Site Position: Northing: 5968522.46 ft Latitude: 70 19 28.285 N From: Map Easting: 562372.05 ft Longitude: 149 29 39.293 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: Plan: 1 C-21 Slot Name: Well Position: +N/-S 116.74 ft Northing: 5968637.75 ft Latitude: 70 19 29.434 N +E/-W -172.98 ft Easting : 562198.12 ft Longitude: 149 ·29 44.342 W Position Uncertainty: 0.00 ft Well path: Rig: 1C-21 PB3 Drilled From: Rig: 1C-21 PB1 Tie-on Depth: 9618.98 ft Current Datum: 1C-21 (40 D15 + 60.3GL) Height 100.30 ft Ahove System Datum: Mean Sea Level Magnetic Data: 6/8/2005 Declination: 24.34 deg Field Strength: 57605 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 109.74 Survey Program for Definitive WelIpath Date: 6/8/2005 Validated: No Actual From To Survey ft ft 150.45 700.98 791.69 9618.98 9706.85 12883.19 Version: 4 Toolcode Tool Name Rig:1C-21 (150.45-700.98) (1) Rig: 1 C-21 MWD (791.69-10267.9 1C-21 MWD (9706.85-12883.19) INC Inclinometer (TotcolTeledrift) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ see MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ see 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 Compan~ Global Report 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 1 09.40 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 46.91 110.17 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+IFR-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 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 MWD+IFR-AK-CAZ-SC ORIGINAL · Halliburton company. Global Report 6674.85 48.87 111.06 5153.79 5053.49 -1282.51 3382.39 5967383.44 565590.70 MWD+/FR-AK-CAZ-SC 6769.27 48.74 110.32 5215.97 5115.67 -1307.61 3448.85 5967358.89 565657.36 MWD+IFR-AK-CAZ-SC 6864.01 49.88 110.06 5277.74 5177.44 -1332.41 3516.27 5967334.66 565724.98 MWD+IFR-AK-CAZ-SC 6960.16 49.46 111.88 5339.97 5239.67 -1358.63 3584.71 5967309.00 565793.63 MWD+IFR-AK-CAZ-SC 7055.34 47.94 111.29 5402.79 5302.49 -1384.94 3651.20 5967283.25 565860.32 MWD+IFR-AK-CAZ-SC 7150.92 46.74 110.73 5467.56 5367.26 -1410.14 3716.81 5967258.59 565926.14 MWD+IFR-AK-CAZ-SC 7245.64 46.90 110.31 5532.37 5432.07 -1434.35 3781.50 5967234.92 565991.02 MWD+IFR-AK-CAZ-SC 7340.59 46.20 110.15 5597.67 5497.37 -1458.19 3846.18 5967211.63 566055.88 MWD+IFR-AK-CAZ-SC 7434.25 46.24 109.97 5662.47 5562.17 -1481.39 3909.70 5967188.96 566119.59 MWD+IFR-AK-CAZ-SC 7530.42 47.62 110.17 5728.15 5627.85 -1505.50 3975.68 5967165.40 566185.77 MWD+IFR-AK-CAZ-SC 7625.72 48.58 111.52 5791.79 5691.49 -1530.74 4041.97 5967140.71 566252.25 MWD+IFR-AK-CAZ-SC 7721.85 48.45 111.74 5855.47 5755.17 -1557.29 4108.91 5967114.72 566319.40 MWD+IFR-AK-CAZ-SC 7814.93 50.01 113.07 5916.25 5815.95 -1584.16 4174.08 5967088.39 566384.78 MWD+IFR-AK-CAZ-SC 7908.83 51.84 112.83 5975.44 5875.14 -1612.58 4241.20 5967060.53 566452.13 MWD+IFR-AK-CAZ-SC 8004.57 50.96 114.88 6035.17 5934.87 -1642.83 4309.63 5967030.85 566520.80 MWD+IFR-AK-CAZ-SC 8099.93 49.86 113.75 6095.95 5995.65 -1673.09 4376.59 5967001.15 566588.01 MWD+IFR-AK-CAZ-SC 8194.85 49.29 111.83 6157.50 6057.20 -1701.09 4443.20 5966973.71 566654.84 MWD+IFR-AK-CAZ-SC 8289.80 51.12 110.06 6218.27 6117.97 -1727.15 4511.33 5966948.22 566723.18 MWD+IFR-AK-CAZ-SC 8384.96 56.62 109.41 6274.36 6174.06 -1753.08 4583.65 5966922.89 566795.70 MWD+IFR-AK-CAZ-SC 8480.28 61.01 108.44 6323.70 6223.40 -1779.50 4660.77 5966897.11 566873.04 MWD+IFR-AK-CAZ-SC 8575.26 62.64 108.37 6368.55 6268.25 -1805.94 4740.21 5966871.34 566952.69 MWD+IFR-AK-CAZ-SC 8669.60 63.86 109.36 6411.01 6310.71 -1833.18 4819.93 5966844.76 567032.62 MWD+IFR-AK-CAZ-SC 8763.73 68.14 109.75 6449.29 6348.99 -1861.96 4900.94 5966816.65 567113.85 MWD+IFR-AK-CAZ-SC 8857.57 73.04 110.80 6480.47 6380.17 -1892.63 4983.93 5966786.67 567197.09 MWD+IFR-AK-CAZ-SC 8953.63 75.09 109.60 6506.84 6406.54 -1924.52 5070.61 5966755.51 567284.03 MWD+IFR-AK-CAZ-SC 9050.65 79.77 106.36 6527.95 6427.65 -1953.71 5160.65 5966727.06 567374.30 MWD+IFR-AK-CAZ-SC 9088.29 81.21 105.12 6534.17 6433.87 -1963.78 5196.38 5966717.29 567410.10 MWD+IFR-AK-CAZ-SC 9154.39 84.87 108.90 6542.18 6441.88 -1982.98 5259.10 5966698.62 567472.97 MWD+IFR-AK-CAZ-SC 9246.59 92.72 108.11 6544.12 6443.82 -2012.21 5346.45 5966670.11 567560.55 MWD+IFR-AK-CAZ-SC 9339.28 90.26 107.52 6541.71 6441.41 -2040.56 5434.65 5966642.50 567648.98 MWD+IFR-AK-CAZ-SC 9432.80 89.88 101.71 6541.60 6441.30 -2064.14 5525.11 5966619.67 567739.62 MWD+IFR-AK-CAZ-SC 9526.04 85.99 100.31 6544.96 6444.66 -2081.94 5616.55 5966602.63 567831.20 MWD+IFR-AK-CAZ-SC 9618.98 90.46 106.08 6547.84 6447.54 -2103.13 5706.93 5966582.19 567921.74 MWD+IFR-AK-CAZ-SC 9706.85 84.08 107.63 6552.02 6451.72 -2128.56 5790.89 5966557.46 568005.90 MWD+IFR-AK-CAZ-SC 9800.50 85.52 110.72 6560.51 6460.21 -2159.19 5878.96 5966527.56 568094.22 MWD+IFR-AK-CAZ-SC 9893.72 87.29 113.24 6566.35 6466.05 -2194.01 5965.23 5966493.46 568180.76 MWD+IFR-AK-CAZ-SC 9987.30 88.88 113.04 6569.48 6469.18 -2230.77 6051.23 5966457.42 568267.05 MWD+IFR-AK-CAZ-SC 10081.95 87.80 110.99 6572.22 6471.92 -2266.23 6138.93 5966422.69 568355.04 MWD+IFR-AK-CAZ-SC 10174.17 90.01 112.93 6573.99 6473.69 -2300.71 6224.44 5966388.93 568440.82 MWD+IFR-AK-CAZ-SC 10267.36 92.61 111.95 6571.86 6471.56 -2336.27 6310.54 5966354.09 568527.20 MWD+IFR-AK-CAZ-SC 10361.78 94.33 111.83 6566.14 6465.84 -2371.40 6397.99 5966319.68 568614.93 MWD+IFR-AK-CAZ-SC 10454.92 91.72 112.09 6561.23 6460.93 -2406.18 6484.24 5966285.62 568701.46 MWD+IFR-AK-CAZ-SC 10548.24 92.63 111.91 6557.68 6457.38 -2441.12 6570.70 5966251.41 568788.20 MWD+IFR-AK-CAZ-SC 10641.91 95.44 113.29 6551.09 6450.79 -2477.02 6656.96 5966216.23 568874.74 MWD+IFR-AK-CAZ-SC 10734.41 91.13 108.89 6545.79 6445.49 -2510.22 6743.08 5966183.74 568961.13 MWD+IFR-AK-CAZ-SC 10828.14 84.95 106.47 6549.00 6448.70 -2538.66 6832.28 5966156.05 569050.55 MWD+/FR-AK-CAZ-SC 10921.82 85.96 108.97 6556.42 6456.12 -2567.08 6921.23 5966128.36 569139.72 MWD+IFR-AK-CAZ-SC 11014.22 86.96 109.13 6562.13 6461.83 -2597.18 7008.40 5966098.99 569227.13 MWD+IFR-AK-CAZ-SC 11108.34 88.09 108.84 6566.19 6465.89 -2627.77 7097.31 5966069.14 569316.29 MWD+IFR-AK-CAZ-SC 11204.45 86.47 109.67 6570.75 6470.45 -2659.43 7187.94 5966038.24 569407.17 MWD+IFR-AK-CAZ-SC 11295.31 87.00 108.88 6575.93 6475.63 -2689.37 7273.57 5966009.01 569493.03 MWD+IFR-AK-CAZ-SC 11387.96 84.24 109.53 6583.00 6482.70 -2719.76 7360.80 5965979.35 569580.50 MWD+/FR-AK-CAZ-SC ORIGINAL · Halliburton Company. Global Report 11483.34 86.24 109.00 6590.92 6490.62 -2751.12 7450.52 5965948.74 569670.47 MWD+IFR-AK-CAZ-SC 11576.17 90.46 108.75 6593.59 6493.29 -2781.13 7538.30 5965919.46 569758.49 MWD+IFR-AK-CAZ-SC 11669.15 94.96 108.86 6589.19 6488.89 -2811.06 7626.20 5965890.26 569846.63 MWD+IFR-AK-CAZ-SC 11762.70 96.94 109.02 6579.50 6479.20 -2841.26 7714.20 5965860.80 569934.87 MWD+IFR-AK-CAZ-SC 11856.34 97.69 108.89 6567.57 6467.27 -2871.43 7802.04 5965831.36 570022.95 MWD+IFR-AK-CAZ-SC 11949.80 94.73 109.06 6557.47 6457.17 -2901.63 7889.90 5965801.88 570111.04 MWD+IFR-AK-CAZ-SC 12043.67 91.04 109.97 6552.74 6452.44 -2932.95 7978.25 5965771.31 570199.64 MWD+IFR-AK-CAZ-SC 12136.82 91.93 110.77 6550.33 6450.03 -2965.36 8065.54 5965739.62 570287.19 MWD+IFR-AK-CAZ-SC 12230.87 87.22 107.40 6551.02 6450.72 -2996.10 8154.38 5965709.62 570376.27 MWD+IFR-AK-CAZ-SC 12324.09 92.07 107.52 6551.60 6451.30 -3024.06 8243.28 5965682.40 570465.39 MWD+IFR-AK-CAZ-SC 12417.57 88.74 104.58 6550.94 6450.64 -3049.90 8333.09 5965657.31 570555.40 MWD+IFR-AK-CAZ-SC 2510.99 85.48 97.40 6555.66 6455.36 -3067.68 8424.60 5965640.29 570647.05 MWD+IFR-AK-CAZ-SC 12603.12 89.87 99.11 6559.39 6459.09 -3080.89 8515.68 5965627.84 570738.23 MWD+IFR-AK-CAZ-SC 12694.96 86.42 94.21 6562.37 6462.07 -3091.54 8606.81 5965617.95 570829.43 MWD+IFR-AK-CAZ-SC 12788.89 96.36 95.78 6560.09 6459.79 -3099.70 8700.23 5965610.56 570922.91 MWD+IFR-AK-CAZ-SC 12883.19 97.12 97.69 6549.02 6448.72 -3110.68 8793.23 5965600.35 571015.99 MWD+IFR-AK-CAZ-SC 2933.00 97.12 97.69 6542.85 6442.55 -3117.29 8842.21 5965594.14 571065.02 PROJECTED to TD ~ ~t( ~~ I \Jt; ~ ~ "'~ :: '-\ \ V Q.C".<J( '. k.O\ E: ~<ê.C-*O'l\.. \;)S\ \ - }- OR1G1NAL HALLIBURTON WELL DETAILS: Plan: 1C-21 ConocJPhillips _...,_..~...,-_._--_.,--,~ - Sperry Drillins Servic.. Ground Level: 60.30 AJa$k¡;¡ +N/-S +EI-W Northing Easting Latittude Longitude Slot 1C-21 0.00 0.00 5968637.75 562198.12 70019'29.434N 149°29'44.342W Vertical Section at 109.74· (1500 Win) -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 -750 ·750 REFERENCE INFORMATION ~ Co-ordinate (N/E) Reference: Well Plan: 1C-21, True North Vertical (TVD) Reference: 1C-21 Actual @ 101.80ft (Doyon 14 (41.5+60.3)) 0 Section (VS) Reference: Slot - (O.OON. O.OOE) 0 Measured Depth Reference: 1C-21 Actual @ 101.80ft (Doyon 14 (41.5+60.3)) Calculation Method: Minimum Curvature 750 750 1500 1500 i..__) LEGEND '-TJ -A- Plan: 1C-21, 1C-21L1, 1C-21L1 VO ,¡:. c', 2250 2250 d."_ ê ~- Plan: 1C-21 , 1C-21L3, 1C-21L3VO ---i G) ~ 2 ""* Plan: 1C-21, 1C-21L2, 1C-21L2 VO m 0 < - 0 m It) -A- 1C-21 ;:¡ s 3000 3000 ~ Z .t: 1i 0 ):> OJ () 0 "9- -¡;; ::T <> 3750 ~ r .~ 3750 0 > [1C-21L.1 (~103~~ 0 OJ ~ :J ~ 2: 4500 ['IC-2'1L2 '(9986-104081] 4500 ---"'~._.._-~_.- -....'...'-" [---- "-ill .1 C-2~ L3J96!~~933) 5250 [--- --~-ill 5250 1~~1J!2511~15634) 6000 6000 C QJ 7 5/8" _-d _ "" 6750 6750 7500 7500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 Vertical Section at 109.74· (1500 Win) HALLIBURTON 'PetrY DrllUntt lervlc.. 'i? ~ ~ 6000 .£:: ! ~ 6375 :e ~ 4> 2 f- 6150 5625 ~ A 75/8" --, +N/·S +E/-W 0.00 0.00 \ WELL DETAILS: Plan: 1C-21 (wp11) Extension Ground Level: 60.30 Northing Eastlng Latlttude Longitude 5968637.75 562198.12 70019'29.434N 149°29'44.342W REFERENCE INFORMATION Co-ordinate (N/E) Raferenca: Wall Plan: 1 C-21, Trua North Vertical (TVD) Raference: 1C·21 Actual@ 101.S0ft (Doyon 14 (41.5+60.3» Saction (VS) Refarenca: Slot· (O.OON, O.OOE) Measurad Depth Raferanca: 1C-21 Actual @ 101.S0ft (Doyon 14 (41.5+60.3)) Calculation Method: Minimum Curvature Slot 1 C-21 11C.21 (12511-15634) I '. ""-- '-",~, '~ ". "'-----.,,:...- --y/ ConocoPhillips .4J&ske, . ~,,'~ . LEGEND -r- Plan: 1C-21, 1C-21L1, 1C-21L1 VO --*" Plan: 1C-21, 1C-21L3, 1C-21L3 VO -A- Plan: 1C-21, 1C-21L2, 1C-21L2 VO -e- 1C-21 1C-2'IL3 (9618-'12933) I "" " '\"> ",...."" '\\\, '\ '"\, \,...... .~..., -........,.....". ". " ............~ 5625 6000 6375 6750 7125 7500 7875 9000 9375 9750 10125 8250 8625 Verticai Section at 109.74" (750 It/in) 10500 10875 11250 11625 12000 12375 ...-----,.............. HALL.IBURTON -'-try Drilling S.rvlc.. (_.~, ~".,.,-_. ,.-I"" 6400 6450 '2 :§ 6500 ~ % ~ 6550 13 :e ~ ~ 6600 I- 6650 6100 6000 +N/-S +EI-W 0.00 0.00 WELL DETAILS: Plan: 1C-21 (wp11) extension Northing 5968637.75 Ground Level: 60.30 Easting Latittude 562198.12 70019'29.434N Longitude 149°29'44.342W Slot 1 C-21 '- --'......... .............,.... .. --.- 'y) ConocoPhillips AlAska . '''-''> . REFERENCE INFORMATION Co-ordinate (N/E) Reference: Weil Pian: 1C-21, True North Vertical (TVD) Reference: 1C-21 Actual@ 101.800 (Doyon 14 (41.5+60.3» Seclion (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 1C-21 Actual @ 101.80ft (Doyon 14 (41.5+60.3») Calculation Method: Minimum Curvature ~"",...., '-- -_..--...~._..~:~::.// -.- " /'// ./// ,./ //1" //// LEGEND -r- Plan: 1C-21 , 1C-21L1, 1C-21L1 VO ---7f- Plan: 1C-21, 1C-21L3, 1C-21L3 va -A- Plan: 1C-21, 1C-21L2, 1C-21L2 va -e- 1C-21 1C-21L1 (0-10336) I ------ -.- '¡C-21L3 (9618-'1293;;-1 11C-21 (12511-15634) I 6050 6950 6100 6150 6200 6250 6300 6350 6600 6400 6450 6500 6550 Vel1ícal Section at 109.74' (100 Win) .......-.--""........- ~........., 6650 6700 6750 6800 6850 6900 ....../ ConocoPhillips Alaska C) :;0 - CD -- z » r ? -1750 ~ o L{) t-- ~ -2625 +' :E t: o Z ::;- -3500 :E '5 o (f) -4375 1750 875 -875 -5250 -6125 -7000 -7875 o /' ~5JaJ T M Azimuths to True North Magnetic North: 24.34' Magnetic Field Strength: 57604.3nT Dip Angle: 80.77' Date: 6f712005 Model: BGGM2004 Project: Kuparuk River Unit Site: Kuparuk 1C Pad Well: Plan: 1C-21 Wellbore: 1C-21 Design: 1C-21 HALLIBURTON --_._-~..~~'--"--~- Sperry Drilling Services [-------_._-~ 1~-21~2 (~986_-~0~ ¡:;-;---~--;\l I~C-21L3 (9618-1293311 7 ----- LEGEND -A- Plan: 1C-21,1C-21L1, 1C-21L1 VO -t- Plan: 1C-21, 1C-21L3, 1C-21L3 VO -8- Plan: 1C-21, 1C-21L2,1C-21L2VO -A- 1C-21 14875 -875 o 3500 4375 875 1750 2625 5250 6125 7875 8750 9625 10500 11375 7000 12250 13125 West(-)/East(+) (1750 ftlin) 14000 . ConocóP'hillips . 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 ¡th 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: ConocoPhjjps 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 TD (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-21 well: 1. While ConocoPhillips Alaska, Inc. ("CP AI") was drilling the proposed KRU 1 C-2l 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 ofthe 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 from the Commission to lengthen the well to a new bottom-hole location that is more than 500' from the permitted bottom-hole location; and 6. CP AI 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 lC-2l (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 from the well. Both of these 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-2l 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 lC-2l, KRU lC-21L1 and KRU lC-21L2. 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 1 C-2l L I 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 1 C-2l L2 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, CP AI 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 :46 PM Re: FW: [Fwd: RE: 1 C-21 Open Hole Sidetracks in the Horizontal In... 5. To close out commission's! files for these orphaned weU segments, CplhOUld also submil a Completion report (Commission form 10-407) with attendant, required data for each ofthe orphaned well bore 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 permitted 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: seiEz;BrIan;--ÄiIsup=ï5rajçe;-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 :46 PM Re: FW: [Fwd: RE: IC-21 Open Hole Sidetracks in the Horizontal In... . ... abandoned approx. 300' of wellbore, 200' of whlch was sand. Thls 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: 1C-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 [~~tlto~steve dav~~~@admin.state.ak.us] Sent: Monday, June 06, 2005 10:10 AM To: Lowry, Scott L Cc: Thomas Maunder Subject: Re: [Fwd: RE: 1C-21 Open Hole Sidetracks in the Horizontal Interval] Scott, To briefly recap what happened: 1. CPAI first drilled the proposed 1C-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' 3 of 5 6/27/2005 I :46 PM Re: FW: [Fwd: RE: lC-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.Lowry@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.Billingsley@conocophillips.com> Tom, The "left" hole section will not be cased. The "well section" will be cased with a slòtted 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 40f5 6/27/20051:46 PM Re: FW: [Fwd: RE: 1 C-2l Open Hole Sidetracks in the Horizontal In... . nomenclature conventions do not have an effect on operation, however I do see the need for having a .. your ultlmate 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 (~Sô'?~t,::.:_I:>_.:..J::.<?::i.EY~.r:::~.QC::'?PÈ.g~_:bP.§_~__C::'?1!l). vcf» 5 of5 6/27/2005 1 :46 PM Re: FW: [Fwd: RE: lC-21 Open Hole Sidetracks in the Horizontal In... . . Message received by Davies. Thanks. Interestingly, this message was delivered to my "In Box" folder rather than being routed to my "Junk Mail" folder like the one from Pat. I don't understand why... Steve Davies 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-Drake, 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 abandoned approx. 300' of wellbore, 200' of which was sand. This 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 10f4 6/27/20051:46 PM I C-21 Open Hole Sidetracks in the Horizontal Interval . . To mlSteve , On we1l1C-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.Lo\vry(â¿conocophiHips.com> SENIOR ENGINEER CONOCOPHILLIPS COMPANY UPSTREAM I of I 6/27/20051:46 PM . . KRU lC-21L3 - 205-102 Note to File This well and its lateral well branches have a complicated history. Drilling operations began May 14,2005. A 13-1/2" 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 ofthe well (15,634' MD) was reached on June 15,2005. Slotted liner measuring 4-1/2" 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 permit to drill. The spud date for this multilateral well branch is assigned as June 6, 2005, the day drilling occurred at the kick-off-point of 12,560'MD, the point where this branch departs from what is now the main well bore ofKRU lC-21. This well branch was drilled to a total depth of 12,933' MD, 6,542' TVD on June 6, 2005 (the same day). 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 terminology and dates applied to the KRU lC-21 well and its multilateral well branches. Steve Davies August 10, 2005 KRU 1 1 KRU J C-2 ¡ - 205-034 KRU IC-2IL! - 205-100 KRU ¡C-2JL2 205-101 KRU IC-2IL3 - 205-102 KRU IC-21 Date: May 14,2005 Reached TVD .-- Sidetrack No. Date TD Reached: June 5 TD: 1 TVD 2005 1 1 s KRU I C-2! - 205-034 KRU I C-2! L! 205-100 KRU IC-2IU - 205-10 KRU IC-2IU - 205-102 KRU IC-21 Spud Date: 2005 KOP: 150' MD, 150' TVD I KRU IC-21L! - 205-100 2. KRU IC-2IL2 205-101 3. KRU IC-2IL3 - 205-102 4. KRU I C-2 - 205-034 Sidetrack No.3 KRU IC-21 Date TD Reached: June 15 Starts at: Surface TD: I lO, 2005 U 1 1 Laterals "Spud Date" Diagram KRU IC-21 Spud Date: May 14,2005 KRLJ I C-21 - 205-034 KRU IC-2ILl - 205-100 KRU IC-2IL2 - 205-101 KRU IC-21L3 - 205-102 150' TVD KRU I C-21 L J- 205-100 2. KRU IC-2IL2 - 205-101 3. KRU IC-21L3 - 205-102 40 KRU IC-21 - 205-034 KRU IC-21 Date TD Reached: June 15 Starts at: Surface TD: 15,634' KRU JC-21 lC-21Ll KRU IC-21L2 KRU IC-21L3 June 06, 2005 S. AOGCC !O, Geologic Commissioner: ~ Engineering Commissioner: '_1,q..f)5 The purpose of this permit to drill is clear record keeping. It is needed for proper tracking of KRU 1 C-21 L3, 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 1 C-21 well. AOGCC's regulations require a unique name and API number for each well branch. Our business aractices and databases reouire an associated aermit to drill number for each API number. Date: Date 35 36 37 38 39 S~Çlbed 'condjtjpO survey CQntact namelphonefor we~!sly progre!;S reports [explorÇltory _only] Appr SFD Date 6/27/2005 if _S~Lsmic_anÇllysjs_ Qf sbaJlow gaszpoes_ P~I'1l')it _D_ata_preseoted on_ pote_ntial pveJpreS_sI,Jr~ _ZOnes off-!;h_ore) No y~s NA_ NA NA KBU 1C-Pad wells _halleiT1easyred 2Q -90_ppmH2S, Expected r~servojr pre_ssuJe is ],3- _9AppgEMW; wm b~drilled wjtb 8.5 _- 10.0 ppg myd_. Geology Date 6/28/2005 21 22 23 24 25 26 27 28 29 30 31 32 33 34 MeçbanicÇlIC9odjtion p{ -~-- c_an be tssued wfo_ hYdrogen sulfide meas!Jres .Is presence Qf H2S gas_ probable wens wtthin i\OB verified (For service welJ only) to _Choke_ manjfold cQiT1pJies w/API BF'-5~ WQr!s will OcCUr withOyt (put Ln _comments) (May 84) _operÇltion _shytdown _BOPEs, do they meet reguJation _BOPE_press raiiog appropriate; test psig Drilliog fJujd program schemÇltic& eq.uip Jfare-drilt has a 10,403 fOJ abandonment Adequate wellbore sepÇlratjon _propo!;ed Jfdjverter required, dQes it meet be~o apprQved Adequate tcm_kÇlgeor reServe pit _CMT will Coyer_all knownpro_dl,Jçlive hQrizon_s C.asiog designs adeqyate fpr C..T, B& periT1afr.ost CMT v_ot adeq uate to tie-Ln IQngstring to_surf csg_ 18 19 20 Cooductor _Surface known USDWs CMT v.ot adequate to circ_utate oncond_uctor_ _casing pJQtects all & SUJtC$g NA NA _NA NA No. y~s y~s NA y~s NA y~s Yes y~s y~s y~s y~s NA H2S is reported_on 1 C_pad MI,Jd shpuld preclI,Jde_H2Son rig._ Rig_has Sensors and alarms. Mi\SP çalcuJated.at 2473 psi, 35QOpstappr.opnate.CPAJ usualJytests to _5000ps reguJations ist adequate W~IJ co_urSe was BOP stack already In place. 1,.3 was_drilJe_dwithQui problems. Adeqyaie. MW_empJoyed_. red ire.cted JQr more. fallorabJe_ pJacement. 1,.3 ha$ .aAn' -9rO$S I~ogth Big jseqI,Jippe_d_with st~e'-pits. NQ rese_rvepjtplanoe.d. All waste toapprove_danouJusor C tass well, Surface. ca_sLng set PrpductiQn Ope.nhpte mothe.rbQre. ~-J in_iT1Qtherbore_. in produçtiv~ _sand~ casiog ~o. Engineering 6/28/2005 12 13 14 15 16 17 string_prQvided ACMP_Findingof Con_sisteocyh_as beenissI,Jed. for_ this proiect AJI welJs_withLn .1l4.iT1ile_are.a_of revieW id~otified (Fpr !;ervjcewell only) Pre.-produ_ced injeçlor; pI,JratiQnof pre-productiool~ss_ than 3 montbs_ (for Servtce Well QnJy) Can permit We.ll IQcated wtthin area and_strataauthortzed by lojectioo Ord~r # (pI,JlIO# in_c.oml'll_eots).{for Appr Date _U~nlqll~ \A'~I' js. weJlbQre plÇltincJu_ded only affected party We.ll '^'o." "creage _available welJs in drilJiog unjt "om driJling I,Jnitb.oI,Jnd.ary_ Administration 2 3 4 5 6 7 8 9 10 11 IE ,..., ,.. ,r JQcat d ,. ,_~_ "'_v,h,v'" ...-""~ ..~"JQcat d prpper _dtstance_ '. We.IUQcat d proper _dtstance from otber _S_ufficient ,.. Jfd~viated, WelJbpre_will beiT1Qre thao 5QO~ an external property line_where ownership orlan_downership _chan-ges. Conservatipo Order Conservatipo Ord_er Kuparuk River Oil F'o.ol. ConservatLoo Order be approved before _Oper_ator _Oper_ator c_an be c_an be Field & Pool i.... '" ....o...no....I nnn KUPARUK RIVER, KUPARUK RV OIL P~riT1it P~riT1it bas_apprppriate_ bond tn Jorce. tssueçl wjtbQut co_nservation order tssued witbQut 5-day wait admioistratille_ apprpvaJ NC 490100 Initial ClasslType NA No_ _Y~s Y~s y~s y~s Y~s Yes y~s Y~s Y~s Y~s Yes NA NA NA NA COndI,Jctorsetio motherþore,_ tC-21 i\11 aq_uife.rs ex~mpted,40CFR H7. (205,Q3-4 ). 02 (b).(3). UopJa_nned IÇlter_at weJI branch. ~ No. 432C No. 432C No. 432C No. 432C co_ntains no spacing restrictions with bas no jn_terwell sPÇlcing re!;trjctions, bas _no re!;trjctions, jnte.rwellspacing resp_ecUo drming _uoit bo_uodaries. frQiT1 ------.DEV Wen /1-0IL govem~d by Con_servatipo Order Name: KUPARUK RIV UNr ~1 L3 GeoArea 890 Not Je.q.uire.d_p_er 20MC 2~.005(e):,...,,,,,..., Correct~d 1 0-407;sI,Jrface loçattoo of weJI Unit î11QQ "nn'~nned braochof KBU 1C-_21 that is_ io ADL 025.649; ihis unptaOned Jate.rÇlI Program DEV On/Off Shore On - wasle.ft QpeO 8< ie!; in ADL 02&2-42 Wen bore seg Annular Disposal js_ c_apabJe Qf PrOdyction ~ D . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Penllitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this ìature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ÅtS--I~~ ()Ì'ct l Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 21 14:22:33 2005 1* 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. R \11 ~\.... ~ \4 "\ '\ ~ \1c.{> 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-21L3 500292325362 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 11 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 .00 101.80 60.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.750 CASING SIZE (IN) 16.000 10.750 7.625 DRILLERS 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 lC-21 AT 12595'MD/6558'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. 5. MWD RUNS 4, 5, 11 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 & 11 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO- DENSITY (SLD). MWD RUN 5 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 11 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, 5, 11 REPRESENT WELL lC-21 L3 WITH API#: 50-029-23253-62. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12933'MD/6542'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/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .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 FET RPX RPS RPM RPD ROP NCNT NPHI FCNT PEF DRHO RHOB $ 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 12864.5 12596.5 12872.0 12872.0 12872.0 12872.0 12933.0 12837.0 12837.0 12837.0 12852.0 12852.0 12852.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------. BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 4 5 11 MERGED MAIN PASS. $ MERGE TOP 5652.5 9160.0 9630.5 MERGE BASE 9160.0 9630.0 12933.0 # 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 DEPT ROP MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 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 12933 9292.75 14562 5652.5 12933 ROP MWD FT/H 0.95 890.81 140.152 14486 5690.5 12933 GR MWD API 27.77 423.53 98.7358 14425 5652.5 12864.5 RPX MWD OHMM 0.3 702.39 4.86789 14425 5660 12872 RPS MWD OHMM 0.36 1634.5 5.97061 14425 5660 12872 RPM MWD OHMM 0.33 2000 9.87813 14425 5660 12872 RPD MWD OHMM 0.72 2000 16.2089 14425 5660 12872 FET MWD HOUR 0.19 136.42 2.2247 13874 5660 12596.5 NPHI MWD PU-S 18.08 58.97 25.4321 7521 9077 12837 FCNT MWD CNTS 114.4 721.39 440.907 7521 9077 12837 NCNT MWD CNTS 13446.1 31750.4 23833.9 7522 9076.5 12837 RHOB MWD G/CM 1.987 3.555 2.36195 7398 9153.5 12852 DRHO MWD G/CM -0.241 1.014 0.068753 7398 9153.5 12852 PEF MWD BARN 0.74 14.84 1.97011 7526 9089.5 12852 First Reading For Entire File......... .5652.5 Last Reading For Entire File.......... .12933 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 2 header data for each bit run in separate files. 4 .5000 . VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 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................ ..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. . . . . . . . . . . . . . . . . . . . .. . . 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 . . 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: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPM RPD 3 header data for each bit run in separate files. 5 .5000 START DEPTH 9076.5 9077.0 9077.0 9089.5 9115.0 9115.0 STOP DEPTH 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 . . FET 9115.0 9630.0 RPS 9115.0 9630.0 RPX 9115.0 9630.0 GR 9122.0 9630.0 DRHO 9153.5 9630.0 RHOB 9153.5 9630.0 ROP 9160.5 9630.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MENORY 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 $ 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 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 29-MAY-05 Insite 66.37 Memory 9630.0 9160.0 9630.0 86.0 92.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 Flo-Pro 9.20 93.0 9.9 300 3.4 .300 .190 .200 .370 68.0 113.0 68.0 68.0 . . 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9076.5 9630 9353.25 1108 9076.5 9630 ROP MWD050 FT/H 1. 51 402.36 130.599 940 9160.5 9630 GR MWD050 API 28.91 83.33 61.659 1017 9122 9630 RPX MWD050 OHMM 0.3 702.39 10.8757 1031 9115 9630 RPS MWD050 OHMM 0.36 1634.5 16.6754 1031 9115 9630 RPM MWD050 OHMM 0.36 2000 65.0583 1031 9115 9630 RPD MWD050 OHMM 7.62 2000 121. 982 1031 9115 9630 FET MWD050 HOUR 0.21 125.53 12.3216 1031 9115 9630 NPHI MWD050 PU-S 21.12 58.97 29.7139 1107 9077 9630 FCNT MWD050 CNTS 114.4 563.2 363.133 1107 9077 9630 NCNT MWD050 CNTS 13446.1 26891.8 22145.7 1108 9076.5 9630 RHOB MWD050 G/CM 2.266 3.555 2.4443 954 9153.5 9630 DRHO MWD050 G/CM -0.241 0.994 0.0484811 954 9153.5 9630 PEF MWD050 BARN 1. 02 14.84 4.02409 1082 9089.5 9630 First Reading For Entire File......... .9076.5 Last Reading For Entire File.......... .9630 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: 4 . RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX PEF GR RPS RPM RPD FET FCNT NCNT RHOB DRHO NPHI ROP $ . header data for each bit run in separate files. 11 .5000 START DEPTH 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 STOP DEPTH 12872.0 12852.0 12864.5 12872.0 12872.0 12872.0 12596.5 12837.0 12837.0 12852.0 12852.0 12837.0 12933.0 # 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 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: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 06-JUN-05 Insite 66.37 Memory 12933.0 9630.0 12933.0 84.1 97.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 Flo-Pro 9.20 41.0 9.0 25000 3.0 .260 .130 .230 .260 68.0 143.6 68.0 68.0 . . # 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 MWD 11 0 FT/H 4 1 68 4 2 GR MWD110 API 4 1 68 8 3 RPX MWD110 OHMM 4 1 68 12 4 RPS MWD110 OHMM 4 1 68 16 5 RPM MWD 11 0 OHMM 4 1 68 20 6 RPD MWD110 OHMM 4 1 68 24 7 FET MWD 11 0 HOUR 4 1 68 28 8 NPHI MWD110 PU-S 4 1 68 32 9 FCNT MWD110 CNTS 4 1 68 36 10 NCNT MWD110 CNTS 4 1 68 40 11 RHOB MWD 11 0 G/CM 4 1 68 44 12 DRHO MWD 11 0 G/CM 4 1 68 48 13 PEF MWD110 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9630.5 12933 11281.8 6606 9630.5 12933 ROP MWD110 FT/H 0.95 890.81 142.021 6606 9630.5 12933 GR MWD 11 0 API 32.74 145.31 63.97 6469 9630.5 12864.5 RPX MWD 11 0 OHMM 2.93 24.04 6.08061 6484 9630.5 12872 RPS MWD110 OHMM 3.1 30.66 7.10482 6484 9630.5 12872 RPM MWD 11 0 OHMM 3.27 31.24 7.74563 6484 9630.5 12872 RPD MWD110 OHMM 3.24 27.79 7.77366 6484 9630.5 12872 FET MWD 11 0 HOUR 0.29 136.42 1.16161 5933 9630.5 12596.5 NPHI MWD110 PU-S 18.08 35.61 24.6931 6414 9630.5 12837 FCNT MWD110 CNTS 263.78 721. 39 454.33 6414 9630.5 12837 NCNT MWD110 CNTS 18004.2 31750.4 24125.5 6414 9630.5 12837 RHOB MWD110 G/CM 1.987 3.194 2.34976 6444 9630.5 12852 DRHO MWD110 G/CM -0.216 1.014 0.0717542 6444 9630.5 12852 PEF MWD110 BARN 0.74 5.89 1.62523 6444 9630.5 12852 First Reading For Entire File......... .9630.5 Last Reading For Entire File.......... .12933 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 . , . . 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 . . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 19 13:28:53 2005 J ~+3'1 ¿¿ð5-IO~ fI J>ì-.ctt Reel Header Service name. . . . . . . . . . . . .LISTPE Date.................... .05/12/19 Origin... ............... .STS Reel Name...... .... ..... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments..... ........... .STS LIS Writing Library. ~ t~(....t,~ Î' Q.~ Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .05/12/19 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 lC-21L3 500292325362 ConocoPhillips Alaska, Inc. Sperry Drilling Services 19-DEC-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003706651 P. SMITH F. HERBERT MWDRUN 5 MW0003706651 P. SMITH F. HERBERT MWD RUN 11 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 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 9.875 6.750 CASING SIZE (IN) 10.750 7.625 DRILLERS DEPTH (FT) 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 lC-21 AT 12595'MD/6558'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. 5. MWD RUNS 4, 5, 11 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 & 11 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO- DENSITY (SLD). MWD RUN 5 INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 11 INCLUDED AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16104, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 4, 5, 11 REPRESENT WELL 1C-21 L3 WITH API#: 50-029-23253-62. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12933'MD/6542'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 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name... ......... .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/12/19 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPX RPS RPM RPD ROP NCNT NPHI FCNT PEF DRHO RHOB $ . . 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 12864.5 12872.0 12872.0 12872.0 12872.0 12872.0 12933.0 12837.0 12837.0 12837.0 12852.0 12852.0 12852.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 4 5 11 MERGED MAIN PASS. $ MERGE TOP 5652.5 9160.0 9630.5 MERGE BASE 9160.0 9630.0 12933.0 # Data Format Specification Record Data Record Type.. '" .............0 Data Specification Block Type... ..0 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 12933 9292.75 14562 5652.5 12933 ROP MWD FT/H 0.95 890.81 140.152 14486 5690.5 12933 GR MWD API 27.77 423.53 98.7358 14425 5652.5 12864.5 RPX MWD OHMM 0.3 702.39 4.86789 14425 5660 12872 RPS MWD OHMM 0.36 1634.5 5.97061 14425 5660 12872 RPM MWD OHMM 0.33 2000 9.87813 14425 5660 12872 RPD MWD OHMM 0.72 2000 16.2089 14425 5660 12872 . FET MWD HOUR 0.19 136.42 2.20594 14425 NPHI MWD PU-S 18.08 58.97 25.4321 7521 FCNT MWD CNTS 114.4 721.39 440.907 7521 NCNT MWD CNTS 13446.1 31750.4 23833.9 7522 RHOB MWD G/CM 1. 987 3.555 2.36195 7398 DRHO MWD G/CM -0.241 1.014 0.068753 7398 PEF MWD BARN 0.74 14.84 1.97011 7526 First Reading For Entire File... .......5652.5 Last Reading For Entire File.......... .12933 File Trailer Service name..... .... ... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. ... ..05/12/19 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.. .....05/12/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 . 5660 9077 9077 9076.5 9153.5 9153.5 9089.5 12872 12837 12837 12837 12852 12852 12852 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 # 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 9121.5 9114.5 9114.5 9114 .5 9114.5 9114.5 9160.0 24-MAY-05 Insite 66.37 Memory 9160.0 5690.0 9160.0 46.2 81. 2 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 097054 10505932 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 . 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.......... ... .....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 . 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 Name Service Order uni t s 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...... .05/12/19 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...... .05/12/19 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF RPM RPD FET RPS RPX GR DRHO RHOB ROP $ 3 . header data for each bit run in separate files. 5 .5000 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 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 9630.0 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: J± 29-MAY-05 Insite 66.37 Memory 9630.0 9160.0 9630.0 86.0 92.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 Flo-pro 9.20 93.0 9.9 300 3.4 .300 .190 .200 .370 68.0 113.0 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... ..0 Logging Direction...... ...... .....DOWD 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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9076.5 9630 9353.25 1108 9076.5 9630 ROP MWD050 FT/H 1. 51 402.36 130.599 940 9160.5 9630 GR MWD050 API 28.91 83.33 61.659 1017 9122 9630 RPX MWD050 OHMM 0.3 702.39 10.8757 1031 9115 9630 RPS MWD050 OHMM 0.36 1634.5 16.6754 1031 9115 9630 RPM MWD050 OHMM 0.36 2000 65.0583 1031 9115 9630 RPD MWD050 OHMM 7.62 2000 121 . 982 1031 9115 9630 FET MWD050 HOUR 0.21 125.53 12.3216 1031 9115 9630 NPHI MWD050 PU-S 21.12 58.97 29.7139 1107 9077 9630 FCNT MWD050 CNTS 114.4 563.2 363.133 1107 9077 9630 NCNT MWD050 CNTS 13446.1 26891.8 22145.7 1108 9076.5 9630 RHOB MWD050 G/CM 2.266 3.555 2.4443 954 9153.5 9630 DRHO MWD050 G/CM -0.241 0.994 0.0484811 954 9153.5 9630 PEF MWD050 BARN 1. 02 14.84 4.02409 1082 9089.5 9630 First Reading For Entire File......... .9076.5 Last Reading For Entire File... ...... ..9630 File Trailer Service name.. ..... ..... .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..05/12/19 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. ..... .05/12/19 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 RPX PEF GR RPS RPM RPD FET FCNT NCNT RHOB DRHO NPHI ROP $ 4 . header data for each bit run in separate files. 11 .5000 START DEPTH 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 9630.5 # 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 12872.0 12852.0 12864.5 12872.0 12872.0 12872.0 12872.0 12837.0 12837.0 12852.0 12852.0 12837.0 12933.0 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: 06-JUN-05 Insite 66.37 Memory 12933.0 9630.0 12933.0 84.1 97.7 TOOL NUMBER 87224 154267 10603684 130908 6.750 9153.0 Flo-Pro 9.20 41. 0 9.0 25000 3.0 .260 .130 .230 .260 68.0 143.6 68.0 68.0 . . HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ...... ......0 Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point...... ..... ...Undefined Frame Spacing..................... 60 .1IN Max frames per record.. .......... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 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 MWDllO FT/H 4 1 68 4 2 GR MWDllO API 4 1 68 8 3 RPX MWD110 OHMM 4 1 68 12 4 RPS MWDll 0 OHMM 4 1 68 16 5 RPM MWD110 OHMM 4 1 68 20 6 RPD MWDll 0 OHMM 4 1 68 24 7 FET MWDllO HOUR 4 1 68 28 8 NPHI MWDllO PU-S 4 1 68 32 9 FCNT MWDll 0 CNTS 4 1 68 36 10 NCNT MWD11 0 CNTS 4 1 68 40 11 RHOB MWD11 0 G/CM 4 1 68 44 12 DRHO MWDllO G/CM 4 1 68 48 13 PEF MWDllO BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9630.5 12933 11281.8 6606 9630.5 12933 ROP MWDllO FT/H 0.95 890.81 142.021 6606 9630.5 12933 GR MWDllO API 32.74 145.31 63.97 6469 9630.5 12864.5 RPX MWD11 0 OHMM 2.93 24.04 6.08061 6484 9630.5 12872 RPS MWD11 0 OHMM 3.1 30.66 7.10482 6484 9630.5 12872 RPM MWDllO OHMM 3.27 31. 24 7.74563 6484 9630.5 12872 RPD MWDllO OHMM 3.24 27.79 7.77366 6484 9630.5 12872 FET MWDllO HOUR 0.29 136.42 1.21021 6484 9630.5 12872 NPHI MWD110 PU-S 18.08 35.61 24.6931 6414 9630.5 12837 FCNT MWDllO CNTS 263.78 721. 39 454.33 6414 9630.5 12837 NCNT MWDllO CNTS 18004.2 31750.4 24125.5 6414 9630.5 12837 RHOB MWDllO G/CM 1.987 3.194 2.34976 6444 9630.5 12852 DRHO MWDllO G/CM -0.216 1.014 0.0717542 6444 9630.5 12852 PEF MWD110 BARN 0.74 5.89 1.62523 6444 9630.5 12852 First Reading For Entire File......... .9630.5 Last Reading For Entire File... ...... ..12933 File Trailer Service name.... ... ..,.. .STSLIB.004 Service Sub Level Name. . , Version Number.......... .1.0.0 Date of Generation...... .05/12/19 Maximum Physical Record..65535 File Type................ LO Next File Name.....,.,.. .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/12/19 > . . . 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.... . . . .... . . .., . . . . .05/12/19 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