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207-122
• Image Project VNe(( History Fi(e Cover Page XNVZE 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 insp/ection of the file. p~ ©~ - I p~, ~ Well History File Identifier Organ%zing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ,,,~=a~ uumiiiuiiiuii DIG AL DATA Diskettes, No. , ^ Other, No/Type: ae,~a~~~aea iuuiuuuiuui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ] ' ~ /s/ ~ Project Proofing II I II ~I II I I III I I III BY: Maria Date: t D lsl Scanning Preparation ~ x 30 = 66 + =TOTAL PAGES ~ Count doss not include cover sheet BY: ~ Maria Date: `~~~ 7 ~~ ~ ( /s/ ) ~' IIIIIIIIIIIIIIIIIIi Production Scanning Stage 1 Page Count from Scanned File: ~_ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ` ~ , ~ D g /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I III P P P 10!6/2005 Well History File Cover Page.doc i • •F #i~ ~~ ~~- SL •!.. r m"I~ ~ ~ .. ~ +c' y - ~. ~. P +~ ~ K ~.. :, ~ ~ , ~ ~~ ~ ~ t` : F ~~'~ aaE 3 ~~ ~~ z` •L~`~ _ ,~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Micro6lm Marker.doc • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~ Tubing patch, Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ cnvert well to Waiver ^ Time E~ension ^ gaslift < Change Approved Program ~^ •Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhllllpS AIBSka, InC. Development Q Exploratory ^ 207-122 . 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23368-60 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 44' . 1J-178L1 ' 8. Property Designation: 10. Field/Pool(s): ALK 25661/ 25662 / 25663~/ 385172~ Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17083' ~ feet true vertical 3199' ` feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 20" 122 122' SURFACE 13-3/8" 3667 2199' INTERMEDIATE 9-5/8" 8980 3280' ~~ D SAND LINER 4.5" 17,046' ~~~ ~~~ 3198' ='~~f~j ~ ~' ~~~ ~ , ~' Perforation depth: Measured depth: 8384-10143, 10145-1 6882 ~~# ~l~ ~~a~ ~ true vertical depth: 3193.6-3222.9, 3222. 9-3195.7 ~G~'p~~~; ~m~'~~»~ Tubing (size, grade, and measured depth) 4-1/2", L-80, 7294' Weatherford retrievable patch from 1976'-2011' (2.25" ID) Packers & SSSV (type & measured depth) Packerless ESP No SSSV 12. Stimulation or cement squeeze summary: ~'s '" r/' %5+~~# Lf W~ LU~~:a ~il; Intervals treated (measured) N/A a ~a F av ' u ... Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A IV/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status afte~ proposed work: Oil ~^ , Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N~A if C.o. Exempt: N/A Contact Brent Rogers/Martin Walters Printed Name nt Rogers Title Problem Wells Supervisor Signature Phone 659-7224 Date 6/5/2009 ~~'1 ./S,~ ~ ~ x~ ~~'r Form 10-404 Revised 04/2004 ._ ~ lf-~P~ '~«~ ~~ ~i ~~J~~ /- ~~Submit Original ly ~~~~~ ~ 1 J-178 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/22/09 RIH AND LATCH BAKER PATCH 1960' CTMD.PULLED PATCH UP HOLE 100' AND RIH AGAIN PUMPED OFF PATCH @ ESTIMATED 1900' CTMD.WELL SHUT IN AND READY FOR SLICKLINE. 03/23/09 PULLED BAKER "45" KB PATCH FROM 1935' SLM. 03/25/09 04/14/09 04/26/09 05/10/09 05/11/09 Summary RUN #1. RIH W/ JSN AND CLEAN TUBING DOWN TO TOP OF SLIP-STOP @ 7145' CTMD. RUN #2. RIH AND PULLED SLIP-STOP FROM TOP OF PACKOFF ASSEMBLY @ 7187' CTMD. RETURN IN AM TO PULL PACKOFF ASSEMBLY AND DOWN HOLE PUMP RIH WITH DOWNHOLE TEST TOOL AND ~ESTED MOTOR @ 7240' CTMD. TEST TOOL SHOW THAT MOTOR WAS TURNING FROM THE PINS THAT WAS SHEAR ON TEST TOOL. SET LOWER ELEMENT OF A 4.5" WEATHERFORD TUBING PATCH. MID ELEMENT SET AT 2011'. SET 4 1/2" WEATHERFORD ER PKR SPACER PIPE SNAP LATCH ASSY @ 2011' RKB (OAL= 32' 2" MIN ID 2.25") WITH HES 3.59" DPU.***** NOTE: TOTAL LENGHT OF THE WHOLE PATCH ASSM, UPPER ER PKR, SPACER PIPE, STINGER & LOWER ER PKR= 34'.06 RAN 4 1/2" ER TEST TOOL TO TOP OF PATCH @ 1947' SLM. MITT TO 2500 PSI, PASS. JOB COMPLETE. MITT passed. Initial T/I/0=1700/1000/125. Start MITT T/I/0=2500/1000/125, 15 min T/I/0=2390/1000/125, 30 min T/I/0=2350/1000/125. Pulled Baker one run patch. Pulled the ESP pump and tested the motor. Test tool shows that the motor was not the failure mechanism. Set a Weatherford retrievable patch over the mandrel from 1976' - 2011'. Set the test tool in the top ER packer and performed a passing MITT. Converted the well to gas lift production instead of ESP production. ~ DATA SUBMITTAL COMPLIANCE REPORT 12/1/2008 Permit to Drill 2071220 Well Name/No. KUPARUK RIV U WSAK 1J-178L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23368-60-00 MD 17083 TVD 3199 Completion Date 11/14/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~~ ,~ Mud Log No DATA INFORMATION Types Electric or Other logs Run: GR/RES Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D Asc Directional Survey R Directional Survey pt LIS Verification ~ D C Lis 15966 ~nduction/Resistivity Induction/Resistivity "Log Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~~" Analysis 14-{d- Received? _ __ Comments: Samples No Directional Survey Yes (data taken from Logs Portio n of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 41 17083 Open 1/16/2008 41 17083 Open 1/16/2008 3631 17083 Open 2/29/2008 LIS Veri, FET, RPD, RPM, RPS, RPX, GR, ROP 3631 17083 Open 2/29/2008 LIS Veri, FET, RPD, RPM, RPS, RPX, GR, ROP 25 Col 120 3199 Open 3/7/2008 TVD Rop, DGR, EWR, DWG 9-Nov-2007 25 Col 120 17083 Open 3/7/2008 MD Rop, DGR, EWR, DWG 9-Nov-2007 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? / N Formation Tops Y L~ DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071220 Well Name/No. KUPARUK RIV U WSAK 1J-178L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23368-60-00 MD 17083 ND 3199 mpletion Date 11/14/2007 Completion Status 1-OIL Current Status 1-OIL 1, UIC N Compliance Reviewed By: ____ _ ___ _ _ _____ _______ Date: ~_3 I~s_~~ s WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1 J-178+L 1 AK-MW-5160500 February 22, 2008 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 1J-178+L1 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23368-00,60 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23368-00,60 Digital Log Images: 1 CD Rom 50-029-23368-00,60 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 Signed: GUS ~ ~~ ~'~'~ ~S, s • WELL LOG TRANSMITTAL To: State of Alaska February 18, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-178 L1 AK-MW-516050 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23368-60 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 -~ ~~, ~.~ 1'~ , ,: ~ =., ; n Date: _ - -~ ~ ~ vC;: ;~ ,: Signed: ~D~-/c~2- ~ lSS6~6 -~~ ~ ,, ~~~~ , 13a}~e l u~ i • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, January 23, 2008 12:35 PM To: Randy Thomas Subject: 1J-178L1 (207-122) Randy, I have finished reviewing the completion report for this well. Looks like both the motherbore and lateral had issues with breathing. In the narrative, calculated and actual fill volumes are listed. In most cases, there is a loss on trips. However the entries for 08:30 11/03 and 21:30 on 11/09 would indicate a gain was experienced. It does appear that the crews were paying close attention to the hole fill, but in these cases it looks like the numbers might be reversed or that the text needed some editing. Call or message with any questions. Tom Maunder, PE AOGCC IJ-178 Operations Text Discussion Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com) Sent: Tuesday, February 12, 2008 9:29 AM To: Maunder, Thomas E (DOA) Subject: 1J-178 Operations Text Discussion Attachments: Patrick.J.Reilly@conocophillips.com.vcf Tom, Page 1 of 1 I have reviewed the operations entries and discussed them with the company men. The volumes on the first entry were for a trip in the hole. We believe the numbers are accurate and the fluid loss was a result of reaming to bottom. The second entry appears to contain a calculation error. The calculated volume of the steel in the string was approximately 75.6 BBLs, not 85.5 BBLs as indicated in the entry. We actually filled the hole with 79.28 BBIs. Therefore the report should indicate a loss of 3.68 BBLs. Thank you for bringing this to our attention and making the correction to your records. 11/3/2007 0:00 8:30 18:00 9.5 11769 17083 PROD2 DRILL TRIP P Resume reaming in the hole. Pumping 168 gpm w/ 500 to 750 psi. Rotate 55 rpm w/ 17 to 23k ft Ibs of torque. At TD: PU wt 260k, SO wt 72k (block wt), Rot wt (w/ pumps on) 125k, Rot wt (w/ pumps off 165k. Rotating torque (w/ pumps) 23k ft Ibs, Rot torque (w/o pumps) 24-25k ft lbs. Note: While trip in the hole: Calculated displacement 71.16 bbls, actual 61.2 bbls =loss of 10 bbls. 11/9/2007 0:00 21:30 22:30 1 72 0 COMPZN CASING OTHR P L/D MWD. L/D BAker F]D Seal Bore Diverter running tool. Note: Calculated fill 85.5 bbls, actual fill 79.28 bbls (loss of 6.22 bbls). Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J. Reilly@conocophillips.com C ConocoPhillips January 15, 2008 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner ~~.~,~ ~ ; ~,~~~ State of Alaska V Alaska Oil & Gas Conservation Commission °~ei~~~~ iE ~~ ~~~~;~ 9~~i~ 333 West 7th Avenue Suite 100 ~~~r Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-178 and 1 J-178L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the Kuparuk West Sak multi-lateral 1 J-178 and 1 J-178L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ._ ~~-~ \ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ~ ~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION QQ WELL COMPLETION OR RECOMPLETION REPORT ~~ L~~G$ 1a. Well Status: Oil a Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25,110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: S I DevelopmentA~(~)"~~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 14, 2007 12. Permit to Drill Number: 207-122 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 27, 2007 ~ 13. API Number: 50-029-23368-60 ' 4a. Location of Well (Governmental Section): Surface: 1647' FSL, 2452' FEL, Sec. 35, T11N, R10E, UM ' 7. Date TD Reached: November 1, 2007 14. Well Name and Number: 1J-178L1 Top of Productive Horizon: 1569' FSL, 1631' FEL, Sec. 3, T10N, R10E, UM 8. KB (ft above MSL): 40.4' RKB Ground (ft MSL): 121.9' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1856' FNL, 1498' FEL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17026' MD / 3198' TVD West Sak Oil Pool s 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558760 y- 5945459' Zone- 4 10. Total Depth (MD + TVD): 17083' MD / 3199' TVD ~ 16. Property Designatioi~ J-/& " ~ - ~ A~.y~6~'25663, 385172 TPI: x- 554349 y- 5940068 Zone- 4 Total Depth: x- 554560 ~ - 5931366 ' Zone- 4 11. SSSV Depth (MD + TVD): none 17. Land Use Permit: 471, 217, 472, 2181 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1536' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window ~ 8365' MD l~ 1GfJ ~..wv~ GR/RES ~ r~ ,E-_ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RECORD PULLED 20" x 34" 78.6# H-40 40' 120' 40' 120' 42" 347 sx AS 1 13.375" 68# L-80 40' 3664' 40' 2203' 16" 843 sx AS Lite, 223 sx DeepCRETE 9.625" 40# L-80 40' 8980' 40' 3280' 12.25" 599 sx Class G 4.5" 11.6# L-80 8354' 17027' 3188' 3198' 8.5" slotted liner 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore none slotted liner from 8354'-17027' MD 3188'-3198' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 27. CORE DATA Conventional Core(s) Acquired? Yes No Q ~ Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~ ~~~~i i`g~~~(V NONE ~ OAS f .~ ~fl~ ~~Fiil"! D . ,. j Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE r~ 28. GEOLOGIC MARKERS (List all formations and mar encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1758' 1536' ~ needed, and submit detailed test information per 20 AAC 25.071. T-3 3600' 2185' K15 3600' 2185' Ugnu C 6080' 2720' Ugnu B 6511' 2810' Ugnu A 6957' 2900' K13 7740' 3061' West Sak D 8365' 3190' West Sak C 17083' 3199' West Sak B 17083' 3199' N/A Formation at total depth: West Sak D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na ~ Thomas Title: Drillino Team Leader Si t D l ~ - f -- t t ~C ~ ~o ~ ~ gna ure (lone ~ s ~ -y, S ~ a e - ~ INSTRUCTIONS Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 w;---~ KRU 1J-178L1 ~t3t1UC4PhlI~1~?S A~~tSCa, InC, _ , ,1J- 71 SL1 - -- - _ API: 500292336860 Well T e: PRDD An le iil TS: d a) TusING ' SSSV Type: NONE Orig 11/14/2007 Angle @ TD: 89 deg @ 17083 (a729a, oD:a.SOO, Com letion: ID:3.858) 3 Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo : 40' RKB Ref Lo Date: Last U date: 12/8/2007 ~`' LastTa TD: 17083ftKB Last Tag Date: Max Hole Angle• 94 deg n 14021 Casin Strin -ALL STRINGS Descri Ion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 3664 2203 68.00 L-80 BTC j TERMEDIATE 9.625 0 8980 3233 40.00 L-80 BTCM D-SAND LINER 4.500 8354 17027 3198 11.60 L-80 BTC/HYD 521 D-SAND WINDOW 10.000 8365 836fi 3191 0.00 Tubing String -TUBING _ I Size Top Bottom ND Wt Grade Thread a s~o o ~2~a ~~~o 1~ co - _ _ ~ ao IBTtu1 Perforations Summary Interval TVD Zone Status Ft SPF Date T Commem 8384- 10143 3194- 3223 WS D 1759 32 11/11/2007 SLOTS 2.5'k .125", 4 PUMP { s i circumferential rows (7oo-3~so~oj ~ centers staggered 18 deg 3' nonslotted ends I 10145 - 16882 3223 - 3196 WS D 6737 32 11/11/2007 SLOTS 2.5"x .125", 4 :. circumferential rowslft 3" SEAL ~ ~~ ~~~t~-1 : f centers staggered 18 deg 3' pza2a2as, 00:5.130) -- -~ . _- nonslotted ends ~Gas Lift MandrelsNalves _ _ - St MD TVD Man Mfr Man T e yp V Mfr V T yl~ V OD Latch Port TRO Date Run VN I I I Cmnt SEAL - 1 1993 1651 CAMCO KBMG SOV 1.0 BEK-5 0 000 2000 11/14/200 (7249-7256, oDS.13o> ~ _ Other plugs, equip., etC.)_-COMPLETION __,__ ~' MOTOR (725s-7zas, 7231 2956 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE 0.000 oD:5s2o> GAUGE __ _ __ - 7234 2857 PUMP TTC ESP PUMP ASSEMBLY (OAL 40.03'), D&D PACKOFF ASSEMBLY & SLIP STOP set 11/21/2007 0.000 (726s-72x2• ~ 7242 2959 SEAL UPPER TANDEM SEAL SECTION GS63DB FER HL SSCV SB/SB PFSA 0.000 OD:4.500) : ~. 7249 2960 SEAL LOWER TANDEM SEAL SECTION GS63DB FER HL SSCV SB/SB PFSA 0.000 7256 2962 MOTOR 418 HP KMHG MOTOR 0.000 7289 2969 GAUGE A-WELL 1 PUMP GAUGE 0.000 7292 2969 Centralizer MOTOR CENTRALIZER 0.000 8354 3188 RAM HANGER D-SAND LINER RAM HANGER 6.625 8362 3190 RAM Diverter D-SAND RAM SEAL BORE DIVERTER, CAMCO DB-6 NIPPLE w/3.562" NO GO PROFILE @8417' & BAKER SEAL ASSEMBLYw/3.88" ID @ 8451' -TOP IN B-SAND LINER, BOTTOM IN D-SAND LINER set 3.880 RAM Dieerter 17026 13198 I SHOE I D-SAND LINER BTC BAKER GUIDE SHOE I 0.000 (s3sz-ea51, I-G_ eneral Notes OD:a.5oo) I Date I Note TERMEDIATE (0-8980, OD:9.625, Wt:40.00) Perf (838410143) DSAND LINER (835417027, OD:4.500, Wt:11.60) Wellhead /Tubing Head /Tree, 13-3/8" x Doyon 15 Rig Floor to Upper Lockdown Screws = 35.76' ~ !~ ~+ "" Lrsulated Conductor ~"~,~ Casing, 20", 94#, K55 x ~- 34", 0.312" WT (a~ x tR 120' MD ~.- KBMG Gaa Lift Mandrel, 1993' (aj 67 degrees 13-3/8", 68#, L-80, BTC ~7 \ \ ~ 5. 0 OpD Co ~loay 12.6 #, L-B0, IBTM, 3664' MD / 2203' TVD / 73 deg ESP, Motor Centralizer 7294' (} 78 degrees 418HP KMH Motor, FC6000 pump, A-Well I-Pump gaugq #1 Round Skva Cable _ RAM Haoger 8354.41'to 6391.19' Ported X-over and 4-'/s" pup 83191.19 to 8395.09' 1J-176 As completed on Doyon 15, Nov 2007 All Depths As Drilled All Depths MD unless noted D Sand Liner, 4-1/2", 11.60# L80, 178 Ll "D" Sand Window: Blank Hydri1521: 8395'to 8484' 8365'to 8381.6' ~ 79.55 degrees i - Slotted Hdril 521: 8484'to 10,144' RAM Sealbore Diverter, Position 1 8359'to 8386 Slotted BTCM w/torque nags: 10,144 to 13,537 Slotted BTCM: 13,537' tc 16,982' Blank BTCM: 16,982' to 17,027' 1J-178 Ll "D" sand lateral 8-Ya" OH TD: 17,083' MD / 3,199' TVD / 89 degrees 4-Y::" Liner shoe: 17,027' MD / 3198.5' TVD 3.562" "DH"nipple 8417' ~ 4-Y" 12.60# L-80 Hydri1521, 6386' to 8424' MLHR Producttoa Anchor (120k snap-out), 8424' to 8428' 4.75" Seal Assembly to 8453' MLZXP & Flexloc 8415.74'to 8442.25 4.750" ID Sealbore 8443.67 to 6463.31 9-5/8", 40#, L-80, BTCM, _~ 8980' MD / 3,280' TVD / 86 degrees B Sand Liner, 5-1/2", 15.5# L80 Blank Hydri1521: 8467'to 6960' Slotted Hydril 521: 8960'to 11,835' Slotted BTCM w/ torque sings: 11,835' to 14,883' Slotted BTCM: 14,883' to 16,657' Blank BTCM: 16,657' to 16,829' Slotted BTCM: 16,829' to 17,002' 1J-176 `B" sand lateral Blank BTCM: 17,002'to 17,046.24' 8-Y" OH TD: 17,083' MD 3,262' TVD / 89 degrees S-Y:" Liner shoe: 17,046' MD / 3260' TVD s ~ ~ 1J-178 "D" Lateral liner Well: 1J-178 ~OnO4O1- ~r~ ~.~p~. 4-1/2", 11.s ppf ,L-80, BTC and Hyd 521 ,Slot and Blank "D" lat liner Date: 11/11/07 Alaska; Inc: Rig: Doyon 15 Depth Jt Number Nul~of Well Equipment Description and Comments ~!, : , ; Page 1 ~~~ ~~ Length Tops .. '~V ..i;~LLri,~,i;.%~lR i.kk ' ... .;~17r~:;I:::::::%:::::>::::::::::::::::::: ':::+:i:::'::: ......... '< I< . :i::i:i:i:i:i:i:ii:Pi::i:iiii[iiii: ii:''i 5" DP to Surface =_> 8337.72 Baker Lubricated Bum er Sub Does not sta in hole 9.00 8337.72 Liner Runnin Too15" Does not sta in hole 7.69 8346.72 RAM Han er above Collet 7.59 8354.41 RAM Han er 6.625" 20 f H dri1521 Below Collet Pin down 29.19 8362.00 Cross over -Ported 6-5/8" 20 f H dril 521 x 4-1/2" H dril 521 3.90 8391.19 Pu Jt.4-1 /2" 12.6# L-80 H dri1521 3.72 8395.09 Jts 202 to 203 2 Jts 4-1/2" 11.6 f L-80 H dril 521 Blank Casin 85.18 8398.81 Jts 162 to 201 40 Jts 4-1 /2" 11.6 f L-80 H dril 521 Slotted Casin 1659.02 8483.99 Cross over- 4-1/2", 12.6 f H dril 521 box x 4-1/2" BTC in 1.65 10143.01 Jts 82 to 161 80 Jts 4-1 /2" 11.6 f L-80 BTC Slotted Casin W/for ue rin S 3392.97 10144.66 Jts 1 to 81 81 Jts 4-1/2" 11.6 f L-80 BTC Slotted Casin 3444.63 13537.63 4-1/2" 11.6 f L-80 BTC Blank Casin 42.58 16982.26 X-O 4-1/2" 12.6 f L-80 BTC Box x 5-1 /2" 15.5 f L-80 BTC Pin 1.39 17024.84 5-1/2" BTC Baker Guide Shoe 1.10 17026.23 Bttm of Shoe =_> 17027.33 17027.33 The To of the Baker Seal Bore Diverter is 8359.03'. 17027.33 Ram Han er will Collet into the collet rofile inside of the Seal Bore Diverter 17027.33 The Collet rofile is 2.97' down from the to of the Seal bore diverter 17027.33 The Collet de th will be 8362' 17027.33 Seal. Bore Diverter "window"--Oriented to 50.1 De Ri ht of hi h side. 17027.33 To of 'B' liner Oriented to 3 De Left of hi h side. 17027.33 TD 8-1/2" hole 17 083' MD / 3199.31' TVD 89.14 de 17027.33 5-1/2" Shoe 17 027.33' MD / 3198.5' TVD 89.02 de 17027.33 55.67' Rat Hole 17027.33 Run 1 H dro-Form 4-1/2" x 6.13" PN 80590 er 'oint =Total of 203 17027.33 On 'ts # 1 thru # 203 17027.33 17027.33 Milled TOW 8365' MD 3190.4' TVD 79.55 de 17027.33 Milled BOW 8381.62' MD 3193.3' TVD 79.72 de 17027.33 Casing exit was planned to be milled 16L but most indicators show the whipstock was set 23 17027.33 Mills also walked off to the right of the whipstock face by 31 R which resulted in a casing exit at 54R. 17027.33 Slots are: 2.5" x 1/8" , 8 slots per row, 4 rows/ft, 3 ft stand off each end. 17027.33 17027.33 Remarks: Ran total of 203 'ts Cs + shoe 't = 8 624.38' 201 'ts Slotted= 8 496.62', 3 'ts Inc S hoe Blank, Blank=127.76' Ran Total of 203 H dro-Forms on 't #1 thru 203. Up Wt 240k Used Run-N-Seal thread com ound on all connections. Dn Wt 102k Tor ue: BTC to 2600 BTC w/for rin 5000 H d 521 to 4300 6-5/8"H d 521 to 6600 ft Ib: Block Wt 70k Tor ue Rin sin 'oints 82 thru 161 = 80 for ue rin s. Drifted liner w/ 3.875" teflon rabbit. Rot wt 135k Supervisors: Fred Herbert/ Granville Rizek Rot torque 11 k Ft Ibs Halliburton Company Survey Report Com~r,~nv: ConocoPhilllps Alaska Inc. Uatc: 11/27/2007 Timr. 14:25:58 P:i~c I Field: Kuparuk River Unit ('u -ordin~le(1'I'~R eFerence: Well: 1J-172. Tru e North Site: Kuparuk 1J Pad ~c rtiail (ll'D) ke fereuce: 1J-178L1. 122.0 Well: 1J-178 tiectiun ll`ti)12eCer enca: 1Ne!I (O.OON.O OO E180,OOAzi) Wellpath: i J-i78L1 Su rvey Calculation Method: Minimum Curvat __ ure t)h: Orade Field: Kuparuk River Unit _ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-178 Slot Name: j Well Position: +N/-S -460.41 ft Northing: 5945459.03 ft Latitude: 70 15 41.730 N ~ +E/-W -33.10 ft Easti ng : 558760.45 ft Longitude: 149 31 29.970 W Position Uncertainty: 0.00 ft Wellpath: 1J-178L1 Drilled From: 1J-178 50-029-23368-60 Tie-on Depth: 8328.73 ft Current Datum: 1 J-178L1: Height 122.02 ft Above System Datum: Mean Sea Level Magnetic Data: 10/4/2007 Declination: 23.15 deg I Field Strength: 57620 nT Mag Dip Angle; 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ' i ft ft ft deg 41.02 0.00 0.00 180.00 Survey Program for DeSnitive Wellpath Date: 11/27/2007 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 120.00 461.00 1J-178 gyro (120.00-461.00) (0 CB-GYRO-SS Camera based gyro single shot 509.47 8328.73 1J-178 IIFR+MS+SAG (509.47-170 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8365.00 17083.00 1J-178L1 I IFR+MS+ SAG (8365.00- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD In~l ~zio~ TVl) Sys"I'~'D V/S E,n~' ~>rlap~ti ',IapF. Tonl ft deg deg ft ft ft ft ft ft 41.02 0.00 0.00 41.02 -81.00 0.00 0.00 __ 5945459.03 ~ 558760.45 ~ _ ___ TIE LINE ~ 120.00 0.26 234.52 120.00 -2.02 -0.10 -0.15 5945458.92 558760.30 CB-GYRO-SS ~ 211.00 0.40 300.81 211.00 88.98 -0.06 -0.59 5945458.96 558759.86 CB-GYRO-SS 272.00 1.08 235.87 271.99 149.97 -0.27 -1.25 5945458.75 558759.21 CB-GYRO-SS 353.00 2.79 230.37 352.94 230.92 -1.96 -3.40 5945457.04 558757.07 CB-GYRO-SS 461.00 5.45 227.40 460.66 338.64 -7.11 -9.20 5945451.85 558751.31 CB-GYRO-SS 509.47 6.31 225.80 508.87 386.85 -10.52 -12.80 5945448.41 558747.73 MWD+IFR-AK-CAZ-SC 559.36 7.64 220.50 558.39 436.37 -14.96 -16.92 5945443.94 558743.65 MWD+IFR-AK-CAZ-SC 603.70 8.65 219.21 602.28 480.26 -19.78 -20.94 5945439.09 558739.66 MWD+IFR-AK-CAZ-SC 698.86 13.31 219.82 695.68 573.66 -33.75 -32.49 5945425.03 558728.23 MWD+IFR-AK-CAZ-SC 794.04 18.42 222.67 787.20 665.18 -53.23 -49.71 5945405.42 558711.16 MWD+IFR-AK-CAZ-SC 888.85 20.31 221.82 876.64 754.62 -76.51 -70.83 5945381.98 558690.22 MWD+IFR-AK-CAZ-SC 983.21 24.55 220.58 963.84 841.82 -103.62 -94.52 5945354.69 558666.76 MWD+IFR-AK-CAZ-SC 1078.96 28.76 223.00 1049.40 927.38 -135.59 -123.18 5945322.50 558638.35 MWD+IFR-AK-CAZ-SC 1174.06 31.93 221.50 1131.46 1009.44 -171.16 -155.45 5945286.68 558606.35 MWD+IFR-AK-CAZ-SC ~ 1269.33 37.13 221.46 1209.92 1087.90 -211.61 -191.21 5945245.96 558570.92 MWD+IFR-AK-CAZ-SC 1364.51 42.44 222.60 1283.04 1161.02 -256.81 -232.00 5945200.44 558530.49 MWD+IFR-AK-CAZ-SC 1459.30 46.59 221.38 1350.62 1228.60 -306.21 -276.43 5945150.70 558486.45 MWD+IFR-AK-CAZ-SC 1552.28 48.68 222.35 1413.27 1291.25 -357.36 -322.28 5945099.20 558441.00 MWD+IFR-AK-CAZ-SC ~ 1648.96 53.41 224.04 1474.04 1352.02 -412.12 -373.75 5945044.04 558389.97 MWD+IFR-AK-CAZ-SC 1742.85 55.34 221.44 1528.73 1406.71 -468.18 -425.52 5944987.59 558338.64 MWD+IFR-AK-CAZ-SC 1838.57 59.05 221.58 1580.58 1458.56 -528.42 -478.83 5944926.95 558285.80 MWD+IFR-AK-CAZ-SC 1932.77 63.28 221.05 1626.00 1503.98 -590.39 -533.29 5944864.56 558231.83 MWD+IFR-AK-CAZ-SC 2028.87 67.78 219.41 1665.80 1543.78 -657.16 -589.75 5944797.35 558175.90 MWD+IFR-AK-CAZ-SC 2124.17 71.39 219.09 1699.04 1577.02 -726.31 -646.25 5944727.77 558119.95 MWD+IFR-AK-CAZ-SC 2219.07 70.40 220.30 1730.10 1608.08 -795.31 -703.52 5944658.33 558063.23 MWD+IFR-AK-CAZ-SC 2313.37 72.04 223.27 1760.46 1638.44 -861.86 -763.01 5944591.32 558004.26 MWD+IFR-AK-CAZ-SC 2410.17 70.25 224.40 1791.75 1669.73 -927.94 -826.44 5944524.76 557941.35 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Comp.~n}: ConocoPhillips Alaska InC. Date: 11!27/2D07 Time: 14:25'58 Pale: 2 Field: Kuparuk River Unit Co-ordinate(~E) Reference: Well_ 1J-17P,, True North Site: Kuparuk 1J Pad Verticai(1'~'1)) Reference: 1J-~78L1: 122.0 ~~cll: 1J-178 Sectionl~ti)Referencc Well (O OON,O.OOE,180.OOAzi) ~1cllpath: 1J-17EL1 Su~~~c. Calculation ~1clhad: Minimum Curvature I)b: Oracle tiuroev MD Intl ~tim 1'FI) ~y. "Il D \IS i:n~~ MapA ~lapi~: Tonl ft deg deg ft ft ft ft ft ft 2504.67 70.09 224.83 1823.80 1701.78 -991.22 -888.88 5944461.00 557879.42 MWD+IFR-AK-CAZ-SC 2598.97 69.44 222.91 1856.42 1734.40 -1055.00 -950.20 5944396.75 557818.61 MWD+IFR-AK-CAZ-SC 2694.89 70.99 223.77 1888.89 1766.87 -1120.64 -1012.14 5944330.63 557757.18 MWD+IFR-AK-CAZ-SC ~ 2790.25 71.46 222.99 1919.58 1797.56 -1186.26 -1074.15 5944264.54 557695.69 MWD+IFR-AK-CAZ-SC 2885.93 71.24 219.79 1950.19 1828.17 -1254.26 -1134.08 5944196.08 557636.30 MWD+IFR-AK-CAZ-SC 2980.37 71.44 222.61 1980.41 1858.39 -1321.58 -1193.01 5944128.31 557577.90 MWD+IFR-AK-CAZ-SC 3075.16 72.37 221.82 2009.85 1887.83 -1388.31 -1253.55 5944061.12 557517.89 MWD+IFR-AK-CAZ-SC 3170.67 69.57 221.94 2040.99 1918.97 -1455.53 -1313.82 5943993.43 557458.15 MWD+IFR-AK-CAZ-SC 3268.78 69.20 223.19 2075.53 1953.51 -1523.16 -1375.93 5943925.33 557396.58 MWD+IFR-AK-CAZ-SC 3358.68 68.17 223.48 2108.21 1986.19 -1584.07 -1433.41 5943863.97 557339.58 MWD+IFR-AK-CAZ-SC 3455.06 71.60 223.03 2141.35 2019.33 -1649.98 -1495.41 5943797.59 557278.10 MWD+IFR-AK-CAZ-SC 3550.41 73.07 222.32 2170.28 2048.26 -1716.78 -1556.99 5943730.32 557217.05 MWD+IFR-AK-CAZ-SC i 3636.97 73.49 223.09 2195.19 2073.17 -1777.70 -1613.22 5943668.97 557161.31 MWD+IFR-AK-CAZ-SC j 3661.67 .72.99 223.33 2202.31 2080.29 -1794.93 -1629.41 5943651.61 557145.25 MWD+IFR-AK-CAZ-SC 3758.49 74.64 224.26 2229.30 2107.28 -1862.04 -1693.76 5943584.01 557081.43 MWD+IFR-AK-CAZ-SC 3854.40 78.78 225.10 2251.34 2129.32 -1928.40 -1759.38 5943517.15 557016.34 MWD+IFR-AK-CAZ-SC 3950.08 79.41 224.08 2269.44 2147.42 -1995.30 -1825.34 5943449.74 556950.91 MWD+IFR-AK-CAZ-SC 4043.04 78.18 222.23 2287.51 2165.49 -2061.82 -1887.71 5943382.74 556889.07 MWD+IFR-AK-CAZ-SC 4138.64 78.70 220.68 2306.67 2184.65 -2132.01 -1949.71 5943312.07 556827.62 MWD+IFR-AK-CAZ-SC 4232.15 78.14 221.29 2325.44 2203.42 -2201.16 -2009.79 5943242.46 556768.09 MWD+IFR-AK-CAZ-SC 4327.26 77.64 221.52 2345.39 2223.37 -2270.91 -2071.29 5943172.24 556707.14 MWD+IFR-AK-CAZ-SC 4422.00 77.00 221.04 2366.19 2244.17 -2340.37 -2132.27 5943102.31 556646.71 MWD+IFR-AK-CAZ-SC 4519.14 78.07 221.17 2387.15 2265.13 -2411.84 -2194.63 5943030.37 556584.92 MWD+IFR-AK-CAZ-SC 4611.70 78.84 221.13 2405.68 2283.66 -2480.13 -2254.30 5942961.62 556525.78 MWD+IFR-AK-CAZ-SC 4707.09 77.32 221.85 2425.38 2303.36 -2550.04 -2316.13 5942891.24 556464.51 MWD+IFR-AK-CAZ-SC 4801.83 78.21 222.43 2445.46 2323.44 -2618.69 -2378.25 5942822.11 556402.93 MWD+IFR-AK-CAZ-SC 4897.49 77.51 222.55 2465.57 2343.55 -2687.66 -2441.42 5942752.66 556340.31 MWD+IFR-AK-CAZ-SC 4993.09 76.81 222.88 2486.82 2364.80 -2756.14 -2504.65 5942683.70 556277.62 MWD+IFR-AK-CAZ-SC 5086.68 78.19 223.99 2507.08 2385.06 -2822.49 -2567.47 5942616.87 556215.33 MWD+IFR-AK-CAZ-SC 5182.99 77.19 223.13 2527.61 2405.59 -2890.67 -2632.31 5942548.19 556151.03 MWD+IFR-AK-CAZ-SC 5278.13 77.41 221.99 2548.53 2426.51 -2959.03 -2695.09 5942479.34 556088.79 MWD+IFR-AK-CAZ-SC 5373.74 77.91 221.58 2568.96 2446.94 -3028.68 -2757.32 5942409.22 556027.11 MWD+IFR-AK-CAZ-SC I 5468.32 78.28 222.56 2588.47 2466.45 -3097.37 -2819.33 5942340.05 555965.64 MWD+IFR-AK-CAZ-SC 5563.34 77.31 223.46 2608.56 2486.54 -3165.28 -2882.68 5942271.65 555902.83 MWD+IFR-AK-CAZ-SC 5657.36 77.78 224.94 2628.84 2506.82 -3231.10 -2946.68 5942205.35 555839.35 MWD+IFR-AK-CAZ-SC 5753.79 77.99 224.13 2649.08 2527.06 -3298.31 -3012.81 5942137.63 555773.76 MWD+IFR-AK-CAZ-SC 5848.95 76.50 223.63 2670.08 2548.06 -3365.20 -3077.14 5942070.25 555709.96 MWD+IFR-AK-CAZ-SC I I 5944.60 77.63 223.78 2691.50 2569.48 -3432.59 -3141.55 5942002.36 555646.08 MWD+fFR-AK-CAZ-SC 6039.74 78.05 222.08 2711.54 2589.52 -3500.69 -3204.89 5941933.78 555583.28 MWD+IFR-AK-CAZ-SC 6134.96 77.75 221.04 2731.50 2609.48 -3570.35 -3266.66 5941863.64 555522.07 MWD+IFR-AK-CAZ-SC 6229.51 78.28 221.23 2751.13 2629.11 -3640.01 -3327.50 5941793.52 555461.77 MWD+IFR-AK-CAZ-SC 6323.38 77.27 221.98 2771.01 2648.99 -3708.61 -3388.41 5941724.45 555401.40 MWD+IFR-AK-CAZ-SC 6418.54 78.27 221.27 2791.17 2669.15 -3778.13 -3450.19 5941654.46 555340.18 MWD+IFR-AK-CAZ-SC ~ 6513.62 78.25 221.92 2810.51 2688.49 -3847.74 -3511.99 5941584.37 555278.93 MWD+IFR-AK-CAZ-SC 6608.71 79.03 222.11 2829.24 2707.22 -3917.01 -3574.38 5941514.63 555217.08 MWD+IFR-AK-CAZ-SC 6704.24 78.21 222.35 2848.09 2726.07 -3986.35 -3637.33 5941444.80 555154.69 MWD+IFR-AK-CAZ-SC 6798.95 78.42 221.98 2867.27 2745.25 -4055.10 -3699.59 5941375.58 555092.97 MWD+IFR-AK-CAZ-SC 6894.64 77.89 221.30 2886.92 2764.90 -4125.09 -3761.81 5941305.11 555031.30 MWD+IFR-AK-CAZ-SC 6989.88 77.99 221.07 2906.82 2784.80 -4195.18 -3823.14 5941234.55 554970.52 MWD+IFR-AK-CAZ-SC 7085.13 78.54 221.48 2926.19 2804.17 -4265.27 -3884.66 5941163.99 554909.56 MWD+IFR-AK-CAZ-SC 7180.90 77.63 220.36 2945.96 2823.94 -4336.07 -3946.04 5941092.72 554848.74 MWD+IFR-AK-CAZ-SC ; 7275.43 78.22 220.68 2965.74 2843.72 -4406.34 -4006.10 5941021.99 554789.24 MWD+IFR-AK-CAZ-SC ~ i ~, Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 1 1 /2 712 007 l imc 14:25:58 P:+;;e: 3 Field: Kuparuk River Unit Co-ordinatc(~~~EI ketcrencc Well_ 1J-178. True North Site: Kupanik 1J Pad Vertical(1~'DI Rc(crcncc: 1J-178L1: 122.0 VVeiF. 1J-178 Section (~~ti) ReCerencc Well (O.OON,O OOE,190.OOAzi1 Wellpath: 1J-178L1 SurveyC;ilculalion tilcthod: Minimum Curvature Db: Oracle Sun°ey MD tncl 12im TVD Svs'I'~~I) V'ti El~~' ~1apA ~taipF 1onl ft dey deg ft ft ft ft ft ft --- 7370.73 77.76 219.19 2985.57 2863.55 -4477.81 -4065.93 5940950.06 554729.97 MWD+IFR-AK-CAZ-SC 7466.43 78.90 215.50 3004.93 2882.91 -4552.31 -4122.77 5940875.13 554673.72 MWD+IFR-AK-CAZ-SC 7562.06 77.64 212.99 3024.37 2902.35 -4629.70 -4175.46 5940797.34 554621.64 MWD+IFR-AK-CAZ-SC 7656.57 78.46 211.65 3043.94 2921.92 -4707.84 -4224.89 5940718.82 554572.83 MWD+IFR-AK-CAZ-SC 7752.10 78.55 209.33 3062.98 2940.96 -4788.50 -4272.39 5940637.80 554525.97 MWD+IFR-AK-CAZ-SC 7847.12 77.84 205.55 3082.43 2960.41 -4871.03 -4315.24 5940554.95 554483.76 MWD+IFR-AK-CAZ-SC 7940.83 77.44 202.14 3102.50 2980.48 -4954.74 -4352.24 5940470.96 554447.42 MWD+IFR-AK-CAZ-SC 8035.94 77.12 198.22 3123.44 3001.42 -5041.80 -4384.24 5940383.66 554416.10 MWD+IFR-AK-CAZ-SC 8132.06 77.95 195.15 3144.20 3022.18 -5131.69 -4411.18 5940293.57 554389.87 MWD+IFR-AK-CAZ-SC 8233.54 78.19 191.58 3165.18 3043.16 -5228.27 -4434.13 5940196.82 554367.68 MWD+IFR-AK-CAZ-SC 8328.73 79.33 187.24 3183.74 3061.72 -5320.35 -4449.38 5940104.63 554353.15 MWD+IFR-AK-CAZ-SC / 8365.00 79.55 185.82 3190.39 ~" 3068.37 -5355.78 -4453.43 5940069.18 554349.37 MWD+IFR-AK-CAZ-SC 8411.40 80.02 185.70 3198.62 3076.60 -5401.21 -4458.02 5940023.72 554345.14 MWD+IFR-AK-CAZ-SC 8505.81 82.20 185.46 3213.21 3091.19 -5494.04 -4467.09 5939930.83 554336.80 MWD+IFR-AK-CAZ-SC 8601.27 85.34 185.22 3223.57 3101.55 -5588.51 -4475.92 5939836.30 554328.71 MWD+IFR-AK-CAZ-SC ~ 8696.74 86.98 184.99 3229.96 3107.94 -5683.39 -4484.39 5939741.37 554320.97 MWD+IFR-AK-CAZ-SC 8711.50 87.60 184.95 3230.66 3108.64 -5698.08 -4485.67 5939726.68 554319.81 MWD+IFR-AK-CAZ-SC 8792.38 89.08 184.18 3233.00 3110.98 -5778.66 -4492.10 5939646.05 554314.00 MWD+IFR-AK-CAZ-SC 8887.31 89.82 181.14 3233.91 3111.89 -5873.47 -4496.51 5939551.21 554310.34 MWD+IFR-AK-CAZ-SC 8983.33 90.75 178.81 3233.43 3111.41 -5969.48 -4496.47 5939455.22 554311.13 MWD+IFR-AK-CAZ-SC 9078.59 90.56 176.03 3232.34 3110.32 -6064.63 -4492.18 5939360.11 554316.16 MWD+IFR-AK-CAZ-SC j 9173.24 90.19 174.98 3231.73 3109.71 -6158.99 -4484.76 5939265.83 554324.31 MWD+IFR-AK-CAZ-SC 9267.66 90.13 175.83 3231.46 3109.44 -6253.10 -4477.20 5939171.78 554332.61 MWD+IFR-AK-CAZ-SC ~ 9363.53 89.76 176.52 3231.55 3109.53 -6348.76 -4470.80 5939076.19 554339.75 MWD+IFR-AK-CAZ-SC 9458.75 90.38 177.92 3231.44 3109.42 -6443.86 -4466.18 5938981.13 554345.11 MWD+IFR-AK-CAZ-SC 9554.07 90.99 179.00 3230.30 3108.28 -6539.14 -4463.62 5938885.89 554348.42 MWD+IFR-AK-CAZ-SC 9649.31 90.50 178.50 3229.06 3107.04 -6634.35 -4461.54 5938790.71 554351.24 MWD+IFR-AK-CAZ-SC 9743.95 90.68 176.66 3228.08 3106.06 -6728.90 -4457.55 5938696.20 554355.97 MWD+IFR-AK-CAZ-SC 9838.98 90.75 176.63 3226.90 3104.88 -6823.76 -4451.99 5938601.40 554362.27 MWD+IFR-AK-CAZ-SC 9933.72 91.12 177.02 3225.35 3103.33 -6918.34 -4446.74 5938506.87 554368.25 MWD+IFR-AK-CAZ-SC i ~ 10029.01 90.68 177.75 3223.86 3101.84 -7013.52 -4442.39 5938411.74 554373.34 MWD+IFR-AK-CAZ-SC 10123.43 89.88 176.75 3223.39 3101.37 -7107.82 -4437.86 5938317.48 554378.61 MWD+IFR-AK-CAZ-SC 10218.20 92.10 177.34 3221.76 3099.74 -7202.45 -4432.98 5938222.90 554384.23 MWD+IFR-AK-CAZ-SC 10313.93 93.71 178.17 3216.91 3094.89 -7297.98 -4429.23 5938127.42 554388.72 MWD+IFR-AK-CAZ-SC 10408.66 91.54 178.16 3212.57 3090.55 -7392.55 -4426.20 5938032.88 554392.49 MWD+IFR-AK-CAZ-SC I 10503.57 92.04 177.70 3209.60 3087.58 -7487.35 -4422.78 5937938.11 554396.65 MWD+IFR-AK-CAZ-SC I 10599.24 92.10 178.30 3206.15 3084.13 -7582.90 -4419.44 5937842.60 554400.74 MWD+IFR-AK-CAZ-SC I 10693.27 91.24 179.02 3203.41 3081.39 -7676.87 -4417.24 5937748.67 554403.67 MWD+IFR-AK-CAZ-SC 10788.52 91.30 178.83 3201.30 3079.28 -7772.08 -4415.46 5937653.48 554406.20 MWD+IFR-AK-CAZ-SC 10883.86 89.51 178.01 3200.62 3078.60 -7867.37 -4412.83 5937558.22 554409.57 MWD+IFR-AK-CAZ-SC 10978.79 89.82 179.15 3201.18 3079.16 -7962.27 -4410.48 5937463.35 554412.66 MWD+IFR-AK-CAZ-SC 11074.39 90.81 180.20 3200.65 3078.63 -8057.86 -4409.93 5937367.78 554413.95 MWD+IFR-AK-CAZ-SC 11169.00 90.06 179.86 3199.93 3077.91 -8152.47 -4409.98 5937273.18 554414.64 MWD+IFR-AK-CAZ-SC 11264.16 90.81 180.69 3199.21 3077.19 -8247.63 -4410.44 5937178.03 554414.92 MWD+IFR-AK-CAZ-SC I 11360.04 90.81 180.39 3197.86 3075.84 -8343.49 -4411.34 5937082.17 554414.77 MWD+IFR-AK-CAZ-SC I j 11454.46 90.50 180.45 3196.78 3074.76 -8437.90 -4412.04 5936987.77 554414.81 MWD+IFR-AK-CAZ-SC 11549.14 90.75 179.35 3195.74 3073.72 -8532.58 -4411.87 5936893.11 554415.72 MWD+IFR-AK-CAZ-SC 11644.23 89.08 179.43 3195.88 3073.86 -8627.66 -4410.86 5936798.05 554417.47 MWD+IFR-AK-CAZ-SC 11738.54 90.32 179.75 3196.38 3074.36 -8721.96 -4410.18 5936703.76 554418.88 MWD+IFR-AK-CAZ-SC 11836.42 89.14 179.74 3196.84 3074.82 -8819.84 -4409.75 5936605.90 554420.08 MWD+IFR-AK-CAZ-SC 11930.29 90.87 178.80 3196.83 3074.81 -8913.70 -4408.55 5936512.06 554422.01 MWD+IFR-AK-CAZ-SC 12026.33 90.68 180.18 3195.53 3073.51 -9009.72 -4407.70 5936416.06 554423.61 MWD+IFR-AK-CAZ-SC 12120.98 89.14 176.19 3195.68 3073.66 -9104.30 -4404.70 5936321.51 554427.35 MWD+IFR-AK-CAZ-S Halliburton Company Survey Report Company: ConocoPhiilips Alaska Inc. Date: 1 1 /2712 0 07 Time: 14:25:58 P:~~c: ~ I~icld: Kuparuk River Unit Co-ordinatc(~U:J Reference: Weil: 1J-172, True North Site: Kuparuk 1J Pad ~~crtical (fell) Reference: 1J-178L1: 122.0 ~~'ell: 1J-173 Section l~~S)Reference_ Well (O.OON.O.OOE,120.OOAzi) ~,-:Wei{path: 1J-172L1 tiurveg(~akula~ionNlethod: PJlinimumCurvature Dh: Orade Sun ce \iU Iucl Azim TVD SysTVD V!S Ei~~~ ~lapA 11apF: Tool ft deg deg ft ft ft ft ft ft 12215.99 87.66 177.16 3198.33 3076.31 -9199.11 -4399.19 5936226.76 554433.59 MWD+IFR-AK-CAZ-SC 12311.41 87.29 179.42 3202.54 3080.52 -9294.39 -4396.35 5936131.51 554437.18 MWD+IFR-AK-CAZ-SC 12406.90 89.02 181.55 3205.61 3083.59 -9389.82 -4397.15 5936036.09 554437.12 MWD+IFR-AK-CAZ-SC 12501.96 88.27 179.89 3207.86 3085.84 -9484.84 -4398.35 5935941.07 554436.66 MWD+IFR-AK-CAZ-SC 12597.44 88.46 179.53 3210.58 3088.56 -9580.28 -4397.87 5935845.65 554437.89 MWD+IFR-AK-CAZ-SC 12691.91 88.52 177.41 3213.07 3091.05 -9674.68 -4395.34 5935751.28 554441.15 MWD+IFR-AK-CAZ-SC 12786.88 88.77 174.01 3215.32 3093.30 -9769.34 -4388.24 5935656.69 554448.99 MWD+IFR-AK-CAZ-SC ~ 12880.82 89.39 175.73 3216.83 3094.81 -9862.89 -4379.85 5935563.22 554458.12 MWD+IFR-AK-CAZ-SC j 12975.92 90.63 179.59 3216.81 3094.79 -9957.89 -4375.96 5935468.26 554462.74 MWD+IFR-AK-CAZ-SC 13072.89 91.43 181.36 3215.07 3093.05 -10054.83 -4376.77 5935371.32 554462.69 MWD+IFR-AK-CAZ-SC 13167.89 90.37 179.40 3213.58 3091.56 -10149.81 -4377.40 5935276.34 554462.80 MWD+IFR-AK-CAZ-SC 13262.19 88.83 178.52 3214.24 3092.22 -10244.09 -4375.69 5935182.09 554465.25 MWD+IFR-AK-CAZ-SC 13357.94 91.23 177.53 3214.19 3092.17 -10339.78 -4372.39 5935086.44 554469.30 MWD+IFR-AK-CAZ-SC 13452.36 89.82 178.24 3213.32 3091.30 -10434.13 -4368.90 5934992.13 554473.52 MWD+-FR-AK-CAZ-SC 13547.10 89.70 177.99 3213.72 3091.70 -10528.81 -4365.78 5934897.48 554477.37 MWD+IFR-AK-CAZ-SC 13642.61 89.70 178.95 3214.22 3092.20 -10624.29 -4363.23 5934802.04 554480.67 MWD+IFR-AK-CAZ-SC 13738.14 90.81 181.06 3213.79 3091.77 -10719.81 -4363.24 5934706.53 554481.40 MWD+IFR-AK-CAZ-SC 13830.69 93.03 180.37 3210.69 3088.67 -10812.29 -4364.40 5934614.05 554480.97 MWD+IFR-AK-CAZ-SC 13926.27 91.61 179.30 3206.82 3084.80 -10907.79 -4364.12 5934518.57 554481.99 MWD+IFR-AK-CAZ-SC 14021.26 94.01 179.85 3202.17 3080.15 -11002.66 -4363.42 5934423.72 554483.43 MWD+IFR-AK-CAZ-SC 14116.54 93.83 180.02 3195.65 3073.63 -11097.72 -4363.31 5934328.67 554484.28 MWD+IFR-AK-CAZ-SC 14211.20 93.15 179.41 3189.89 3067.87 -11192.20 -4362.84 5934234.21 554485.49 MWD+IFR-AK-CAZ-SC I 14306.78 90.37 179.90 3186.95 3064.93 -11287.72 -4362.27 5934138.70 554486.81 MWD+IFR-AK-CAZ-SC 14401.84 88.95 179.01 3187.52 3065.50 -11382.77 -4361.36 5934043.67 554488.46 MWD+IFR-AK-CAZ-SC 14497.18 89.33 177.42 3188.95 3066.93 -11478.05 -4358.39 5933948.42 554492.17 MWD+IFR-AK-CAZ-SC 14592.38 89.20 176.61 3190.17 3068.15 -11573.11 -4353.43 5933853.41 554497.87 MWD+IFR-AK-CAZ-SC 14687.19 88.21 178.68 3192.31 3070.29 -11667.81 -4349.54 5933758.76 554502.50 MWD+IFR-AK-CAZ-SC 14782.09 88.65 180.37 3194.91 3072.89 -11762.67 -4348.75 5933663.92 554504.03 MWD+IFR-AK-CAZ-SC 14877.47 89.20 181.78 3196.70 3074.68 -11858.01 -4350.54 5933568.57 554502.98 MWD+IFR-AK-CAZ-SC 14972.93 90.81 183.15 3196.70 3074.68 -11953.38 -4354.65 5933473.18 554499.62 MWD+IFR-AK-CAZ-SC 95067.85 90.19 182.15 3195.87 3073.85 -12048.19 -4359.04 5933378.35 554495.97 MWD+IFR-AK-CAZ-SC 15163.46 91.12 183.85 3194.77 3072.75 -12143.66 -4364.04 5933282.85 554491.72 MWD+IFR-AK-CAZ-SC 15257.74 90.13 184.25 3193.75 3071.73 -12237.70 -4370.70 5933188.78 554485.79 MWD+IFR-AK-CAZ-SC 15352.92 90.13 184.04 3193.53 3071.51 -12332.63 -4377.58 5933093.80 554479.65 MWD+IFR-AK-CAZ-SC 15447.35 89.94 182.07 3193.47 3071.45 -12426.92 -4382.61 5932999.49 554475.36 MWD+IFR-AK-CAZ-SC 15542.51 90.93 183.41 3192.75 3070.73 -12521.97 -4387.16 5932904.42 554471.55 MWD+IFR-AK-CAZ-SC ~ 15638.02 89.88 180.94 3192.07 3070.05 -12617.40 -4390.78 5932808.97 554468.67 MWD+IFR-AK-CAZ-SC 15733.62 90.19 178.15 3192.02 3070.00 -12712.98 -4390.02 5932713.40 554470.18 MWD+IFR-AK-CAZ-SC ~ 15828.28 89.32 177.06 3192.42 3070.40 -12807.56 -4386.07 5932618.87 554474.87 MWD+IFR-AK-CAZ-SC j 15923.85 89.39 176.11 3193.50 3071.48 -12902.95 -4380.38 5932523.53 554481.31 MWD+IFR-AK-CAZ-SC j 16017.82 89.63 177.30 3194.30 3072.28 -12996.76 -4374.97 5932429.78 554487.44 MWD+IFR-AK-CAZ-SC i 16113.78 89.70 177.70 3194.86 3072.84 -13092.63 -4370.79 5932333.96 554492.37 MWD+IFR-AK-CAZ-SC 16208.99 89.32 178.46 3195.68 3073.66 -13187.78 -4367.60 5932238.84 554496.30 MWD+IFR-AK-CAZ-SC 16304.71 89.82 176.93 3196.39 3074.37 -13283.42 -4363.75 5932143.25 554500.90 MWD+IFR-AK-CAZ-SC 16399.96 90.69 175.29 3195.97 3073.95 -13378.44 -4357.29 5932048.28 554508.10 MWD+IFR-AK-CAZ-SC 16495.03 90.00 173.90 3195.40 3073.38 -13473.08 -4348.33 5931953.72 554517.79 MWD+IFR-AK-CAZ-SC 16589.12 91.06 174.78 3194.53 3072.51 -13566.71 -4339.05 5931860.18 554527.80 MWD+IFR-AK-CAZ-SC 16682.58 90.19 178.79 3193.51 3071.49 -13660.00 -4333.81 5931766.95 554533.77 MWD+IFR-AK-CAZ-SC 16778.77 89.14 176.55 3194.07 3072.05 -13756.10 -4329.90 5931670.89 554538.43 MWD+IFR-AK-CAZ-SC 16873.80 89.08 175.80 3195.55 3073.53 -13850.90 -4323.57 5931576.14 554545.51 MWD+IFR-AK-CAZ-SC 16969.59 88.77 175.79 3197.34 3075.32 -13946.42 -4316.54 5931480.69 554553.27 MWD+IFR-AK-CAZ-SC 17053.41 89.14 177.83 3198.87 3076.85 -14030.09 -4311.88 5931397.07 554558.59 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConacoPhitlips Alaska Inc. hale: 11/27/2007 Timc: 14:25:58 Pa;;e: 5 Field: KuparukRiver Unit Co-ordi~~ate(NE)Re[ercnrr. Well: iJ-178, True North Sic Kuparuk 1d Pad Vertical ('fVD)Referencc 1J-178L1: 122.0 ~~cll: 1 J-178 Section (VS) RePereucc Well (O.OON.O-OOE,180.OOAzi) 1~elipath: 1J-178L1 Survey Cakutation Method: tviii~imum Curvature ])h: Oracle Sunny MD fncl ~zim TAD SysTVD NlS 4:/11 11apN )laph: fool ft deg deg ft ft ft ft ft ft 17083.00' 89.14 177.83 3199.32 0 3077.30 -14059.66 -4310.76 5931367 .52 % 554559.94 ' MWD+IFR-AK-CAZ-SC Tirrie Logs _ T COM Date From To ' - Dur ? = S. De h E. De th Phase Code Subcode 10/26/2007 23:30 23:45 0.25 6,900 6,900 COMPZ ~ CASINC OTHR _ P Monitor well. Static. 23:45 00:00 0.25 6,900 6,600 COMPZ CASINC RUNL P Pump out of the hole, pumping 168 m w/ 310 si. Pullin seed 90'/min. 10/27/2007 00:00 01:30 1.50 6,600 5,500 COMPZ CASINC RUNL P Pump out of the hole, pumping 168 m w/ 310 si. Pullin seed 90'/min. 01:30 01:45 0.25 5,500 5,500 COMPZ CASINC OTHR P Monitor well-- static. 01:45 05:00 3.25 5,500 81 COMPZ CASINC RUNL P POOH on elevators, monitor well on the trip tank. Record PU and SO wt's every 10 stands. Note: Calculated fill f/entire trip 88.25, actual 90.5 for a loss of 2.25 bbl. 05:00 05:30 0.50 81 81 COMPZ CASINC OTHR P Monitor well-- static. Clean floor. Bring Baker blue small ton s to the floor. 05:30 06:30 1.00 81 0 COMPZ CASINC OTHR P Making service breaks on Baker HR running tool and inner string including S er Sun MWD. La down same. 06:30 07:00 0.50 0 0 COMPZ CASINC OTHR P Clear and clean floor. 07:00 08:15 1.25 0 0 PROD2 STK PULD P Break down a stand of 5" HWDP and lay down into the pipe shed. Bring Baker whi stock tools to the ri floor. 08:15 11:15 3.00 0 167 PROD2 STK PULD P PJSM. PU/MU Baker Milling assembly, then lay down to the pipe shed. PU Baker whipstock assembly. Orient MWD to the face of the whipstock (Highside). Orient anchor lug below the whipstock to 13 deg right of the whipstock (this makes the whipstock 13 deg left of the lug). Orientation by Rig Supervisor, DD, MWD, Baker.PU milling assembly and bolt up to whipstock w/ 35k shear bolt. Unloader set to shear @ 6k overpull. MU MWD then orient MWD to the face of the whi stock Hi hside . 11:15 11:45 0.50 167 167 PROD2 STK OTHR P Downlaod MWD 11:45 12:15 0.50 167 329 PROD2 STK PULD P Continue to PU/MU Baker milling BHA BHA #5 . 12:15 12:30 0:25 329 329 PROD2 STK CIRC P Shallow test MWD. Pumping 450 gpm w/ 720 m. Good test. 12:30 18:00 5.50 329 7,178 PROD2 STK WPST P Trip in the hole with the 9-5/8" whipstock assembly on 5" drill string consisting of 37 stands of slick drill pipe, 30 stands of super sliders, 5 stands slick dp, then make a connection on first stand of 5" HWDP. 18:00 19:00 1.00 7,178 7,266 PROD2 STK OTHR P Make a top drive connection. MADD pass. Pumping 500 gpm w/ 1880 psi. GR sensor depth 7046' to 7133'. Bit de th 7178' to 7266'. 19:00 20:00 1.00 7,266 8,370 PROD2 STK WPST P Continue in the hole with the Baker whipstock on 5" HWDP. Page 25 of 49 C~ ~, Time. Logs ~ _ Subcode T COM Date From To Dur S. De th E. De th Phase 'Code 10/27/2007 20:00 20:30 0.50 8,370 8,402 PROD2 _ STK OTHR P MU a single of drill pipe, make a top drive connection. Pumping 470 gpm w/ 2140 psi. PU wt 210k, SO wt 115k. Orient the whipstock starting from 41 Ri ht to 17 Left of hi h side. 20:30 22:15 1.75 8,402 8,426 PROD2 STK WPST P MU stand 86 with single still in the string. Make a top drive connection. Pumping 470 gpm w/ 2140 psi. PU wt 210k, SO wt 115k. Work pipe and orientation self oriented to 17-20 Right prior to latch. Latch in @ (8425.79') and pull test to 230k (20k overpull), ~- ,,,_` ~~ slack off to 80k (30k down). MWD and whipstock face went from 20 Right to ~ ~ ~ „ {~ 6 left of high side. After shearing bolt: i ~ ~ PU wt 200k, SO wt 110k, Rotating wt \ J ` 150k .Note; After shearing mills free ~~ ~ from whipstock MWD showed 15 left ~ of highside but this was after the bolt sheared. PU 10' to confirm sheared free f/ whipstock. Top of window to be 8365'. 22:15 23:00 0.75 8,365 8,355 PROD2 STK CIRC P After picking mills up 10' to 8355', displace well f/ 8.8 ppg SFOBM to 8.7 ppg MOBM. Pumping 606 gpm w/ 3000 psi. After pumping 382 bbls, start millin o erations. 23:00 00:00 1.00 8,365 8,367 PROD2 STK WPST P Begin milling window in 9-5/8" 40 ppf L-80 casing @ 8365'. Pumping 606 ~~ ~ gpm w/ 3000 psi. Rotate 60 rpm w/ ~~\ 10k ft Ibs of torque. PU wt 200k, SO wt 110k, Rot wt 150k. 10/28/2007 00:00 07:00 7.00 8,367 8,407 PROD2 STK WPST P Continue milling window in 9-5/8" 40 ppf L-80 casing, TOW @ 8365' (79.55 deg) (6 deg left of highside). BOW @ 8381.62'. Pumping 606 gpm w/ 3000 psi. Rotate 100 rpm w/ 12-13k ft Ibs of torque. PU wt 200k, SO wt 110k, Rot wt 150k. Note: Pump a 40 bbl sweep while milling @ 8381'.(8.8 ppg/ 200 vis) with medium increase in cuttin s. 07:00 08:15 1.25 8,407 .8,407 PROD2 STK OTHR P Check and cleanup window. Work mills through window.While pumping @ 446 gpm w/ 1620 psi, pump a 40 bbls 8.8 ppg 210 vis sweep. Work mills across window. Window in good condition. Obtain SPR's. 08:15 08:30 0.25 8,407 8,407 PROD2 STK OTHR P Monitor well- static. 08:30 10:15 1.75 8,407 7,390 PROD2 STK TRIP P Attempt to pull on elevators, hole swabbing. Pump out of the hole. Hole fill correct. 10:15 10:30 0.25 7,390 7,116 PROD2 STK TRIP P Pull out of the hole. The hole took ro er dis lacement. 10:30 10:45 0.25 7,116 7,116 PROD2 STK OTHR P Monitor the well- static. Page 2S of 49 ..Time Logs Date From To Dur S: De~ th E: De th Phase Code ~`Subcode T CQM _____ 10/28/2007 10:45 11:00 0.25 7,116 7,116 PROD2 STK CIRC P Pump a dry job. Blow down the top drive. 11:00 13:15 2.25 7,116 268 PROD2 STK TRIP P Pull out of the hole. The hole took ro er dis lacement. 13:15 13:45 0.50 268 106 PROD2 STK PULD P Lay down BhA. Stand back the HWDP wears. 13:45 14:15 0.50 106 106 PROD2 STK OTHR P Download Sperry Sun MWD. 14:15 15:00 0.75 106 0 PROD2 STK PULD P Lay down BHA #5: Window mill under guage a 1/4", lower mill and upper mill is full ua a 8.5" . 15:00 15:30 0.50 0 0 PROD2 STK PULD P Clean and clear rig floor of all milling tools. 15:30 16:00 0.50 0 0 PROD2 STK OTHR P Flush the BOP stack. 16:00 17:00 1.00 0 77 PROD2 DRILL PULD P MU BHA #6: MU bit #5, geopilot, geo flex, MWD, HOC. 17:00 17:30 0.50 77 77 PROD2 DRILL OTHR P Upload MWD 17:30 18:00 0.50 77 353 PROD2 DRILL PULD P Continue to PU/MU BHA #6. 18:00 18:30 0.50 353 353 PROD2 DRILL OTHR P Shallow test MWD. Pumping 510 gpm w/ 930 psi. Rotate 30 rpm breaking in seals on eo ilot. 18:30 18:45 0.25 353 353 PROD2 DRILL OTHR P Blow down top drive and kill line. 18:45 20:00 1.25 353 2,539 PROD2 DRILL TRIP P RIH w/ BHA #6 on 5"drill pipe. Record PU and SO wt's eve 10 stands. 20:00 20:15 0.25 2,539 2,730 PROD2 DRILL TRIP P Install ghost reamer on the top of stand #23, MU stand 24, Make top drive connection on #25. PU wt 180k, SO wt 110k. 20:15 20:45 0.50 2,730 2,730 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 3k ft Ibs of torque.. Pump 500 gpm w/ 1230 psi. Rot wt 115k. Test MWD-OK. 20:45 21:30 0.75 2,730 5,110 PROD2 DRILL TRIP P Trip in the hole w/ BHA #6. Record PU and SO wt's eve 10 stands. 21:30 21:45 0.25 5,110 5,110 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 6-7k ft Ibs of torque.. Pump 210 gpm w/ 400 psi. Rot wt 125k. 21:45 22:30 0.75 5,110 7,488 PROD2 BRILL TRIP P Trip in the hole wJ BHA #6. Record PU and SO wt's eve 10 stands. 22:30 22:45 0.25 7,488 7,488 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 9k ft Ibs of torque.. Pump 210 gpm w/ 530 psi. Rot wt 125k. 22:45 23:15 0.50 7,488 8,345 F~ROU2 DRILL TRIF P Trip in the hole w/ BHA #6. Record PU and SO wt's eve 10 stands. 23:15 23:45 0.50 8,345 8,345 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 11 k ft Ibs of torque.. Pump 210 gpm w/ 540 psi. Rot wt 130k. Blow down top drive. Note: Calculated displacement 74.5, actual displacement 76.2 f/ loss of 1.7 bbl. Page 27 of 49 Time Logs Date From To '' ' Dur _S. DQPth E. De th Phase Code - Subcode T _COM _ 10/28/2007 23:45 00:00 0.25 8,345 8,345 PROD2 RIGMN SVRG P Hang blocks for slip and cut drilling line. Will slip and cut 91' of drilling line. 10/29/2007 00:00 01:30 1.50 8,345 8,345 PROD2 RIGMN SVRG P Slip and cut 91' of 1-3/8" drilling line. 01:30 02:45 1.25 8,345 8,345 PROD2 RIGMN SVRG P Service rig (grease topdrive, drawworks, and crown. Do a visible inspection on drawworks chains and brake bands. Complete PM's on chain oiler for the drawworks, deadman f/ the drilling line, and top drive. Inspect and gauge sheaves in the crown cluster f/ the 1-3/8" drillin line. 02:45 03:15 0.50 8,345 8,407 PROD2 DRILL TRIP P Make a top drive connection. Slack off w/bit past whipstock. Noticed only 5k drag across whipstock. Start rotating f/ 8395' to 8407' and tag bottom. Pumping 500 gpm w/ 1900 psi. Rotate 40 rpm w/ 15k ft Ibs of torque. Rot wt 130k, SO wt 115k. 03:15 06:00 2.75 8,407 8,575 PROD2 DRILL DDRL P Directional drill "D" lateral 06:00 12:00 6.00 8,575 9,230 PROD2 DRILL DDRL P Directional drill "D" lateral 12:00 18:00 6.00 9,230 10,152 PROD2 DRILL DDRL P Directional drill "D" lateral 18:00 00:00 6.00 10,152 10,900 PROD2 DRILL DDRL P ' Directional drill "D" lateral 10/30/2007 00:00 06:00 6.00 10,900 11,960 PROD2 DRILL DDRL P Directional drill "D" lateral 06:00 12:00 6.00 11,960 12,589 PROD2 DRILL DDRL P Directional drill "D" lateral 12:00 18:00 6.00 12,589 13,169 PROD2 DRILL DDRL P Directional drill "D" lateral 18:00 00:00 6.00 13,169 13,766 PROD2 DRILL DDRL P Directional drill "D" lateral 10/31/2007 00:00 06:00 6.00 13,766 14,103 PROD2 DRILL DDRL P Directional drill "D" lateral 06:00 12:00 6.00 14,103 14,578 PROD2 DRILL DDRL P Directional drill "D" lateral 12:00 16:45 4.75 14,578 15,002 PROD2 DRILL DDRL P Directional drill "D" lateral 16:45 20:45 4.00 15,002 14,526 PROD2 DRILL REAM P Backream out of the hole. ECD's were running 12 ppg. Pumping 660 gpm w/ 3650 psi. Rotating 120 rpm w/ 19k ft Ibs of torque. PU wt 255-260k, SO 72 (block wt}, Rot wt 125-130k. Pulling speed 2-3'/min. Pumped a total of 2990 bbls. 20:45 22:00 1.25 14,526 14,621 PROD2 DRILL CIRC P Circualte and reciprocate pipe while pumping a 30 bbl sweep (9.3+ppg/ 185 vis) to clean the hole. PU 265k, SO wt 72k (block wt), Rotating wt 145k, rotating torque 19k ft Ibs..While circulating 660 gpm w/ 3660 psi: ECD's circulated down f/ 11.95 ppg to 11.61 ppg after sweep was out of the hole. Pum ed a total of 1355 bbls. Page 28 of 49 Time Logs Date From ' To Dur S. De th" E De th Phase Code Subcode T COM _ __ 10/31/2007 22:00 23:00 1.00 14,621 15,002 PROD2 DRILL _ TRIP P Trip back into the hole. Rotate 50 rpm w/ 20k ft Ibs of torque. Pumping 84 gpm w/ 500 psi. Pu wt 255k, SO wt 72k Block wt), Rotatin wt 145k. 23:00 00:00 1.00 15,002 15,175 PROD2 DRILL DDRL P Directional drill "D" lateral 11/01/2007 00:00 06:00 6.00 15,175 15,857 PROD2 DRILL DDRL P Directional drill "D" lateral. 06:00 12:00 6.00 15,857 16,428 PROD2 DRILL DDRL P Directional drill "D" lateral. Pumped a 30 bbls hi vis sweep (8.8 ppg/ 180 vis) while drilling @ 16048'. Slight increase in cuttings. Pump a 30 bbls high vis sweep while drilling @ 16428' (8.7 / 240 vis . 12:00 13:00 1.00 16,428 16,428 PROD2 DRILL CIRC P Circ until high vis sweep is out of the hole. Backream @ 2.5'/min f/ 16428' to 16325' while rotating 120 rpm w/ 22k ft Ibs of torque. Slight increase in cuttings. Pumping 605 gpm w/ 3380 si. Rotatin wei ht 125k. 13:00 16:30 3.50 16,428 16,653 PROD2 DRILL DDRL P Directional drill "D" lateral. 16:30 17:30 1.00 16,653 16,653 PROD2 RIGMN RGRP T Repalce valve and seat in # 2 mud pump. Backream out to 16590' while working on pump. Pumping 462 gpm w/ 2160 psi, #1 mud pump. Pulling 2'/min. Rotate 120 rpm w/ 21 k ft Ibs of torque. Rotatin wt 130k, 17:30 18:00 0.50 16,653 16,712 PROD2 DRILL DDRL P Directional drill "D" lateral. 18:00 21:00 3.00 16,712 17,083 PROD2 DRILL DDRL P Directional drill "D" lateral. 21:00 00:00 3.00 17,083 16,915 PROD2 DRILL CIRC P Obtain SPR's. Pump a 30 bbl sweep (8.8 ppg/ 200 vis). Backream out of the hole slow while circulating sweep out of the hole, then another BU. Pulling speed 1-2'/min. Pumping 600 gpm to 550 gpm w/ initial 3460 psi and 12 ppg ECD's to mostly 550 gpm w/ 2930 psi and 11.7 ppg ECD's. Rotate 120 rpm w/ 22-23k ft Ibs of torque. PU wt 275k, SO wt 72k (block wt), Rot wt 145k. 11/02/2007 00:00 00:30 0.50 16,915 16,905 PROD2 DRILL CIRC P Backream out of the hole slow while circulating another BU. Pulling speed 2'/min. Pumping 550 gpm w/ 3180-2930 psi and 11.7 ppg ECD's. Rotate 120 rpm w/ 22-23k ft Ibs of torque. PU wt 275k, SO wt 72k (block wt ,Rot wt 145k. 00:30 04:30 4.00 16,905 15,500 PROD2 DRILL REAM P Backream out of the hole. Pulling speed 20'/min. Pumping 550 gpm w/ 3180-2930 psi and 11.7 ppg ECD's. Rotate 120 rpm w/ 22-23k ft Ibs of torque. PU wt 275k, SO wt 72k (block wt ,Rot wt 145k. Page 29 of 49 TimQ Lags _ Date From To Dur . S. De th E. De th Phase Code ' Subcode T` COM __ 11/02/2007 04:30 06:00 1.50 1,500 14,526 PROD2 DRILL REAM P Backream out of the hole slow. Pulling speed 25'/min. Pumping 600 gpm w/ initial 3260 psi and 11.4 ppg ECD's Rotate 120 rpm w/ 20k ft Ibs of torque. PU wt 265k, SO wt 72k (block wt), Rot wt 130k. 06:00 12:00 6.00 14,526 11,582 PROD2 DRILL REAM P Backream out of the hole slow. Pulling speed 40'-30'/min. Pumping 650 gpm w/initial 3150 psi and 11.84 -11.4 ppg ECD's Rotate 120 rpm w/ 15-16k ft Ibs of torque. PU wt 265-235k, SO wt 72k block wt ,Rot wt 125k. 12:00 18:00 6.00 11,582 8,634 PROD2 DRILL REAM P Backream out of the hole slow. Pulling speed 40'/min. Pumping 615 gpm w/ initial 3150-2260 psi and 11.4- 9.83 ppg ECD's Rotate 120 rpm w/ 14-15k ft Ibs of torque. PU wt 190k, SO wt 100k, Rot wt 125k. Note calculated fill 68 bbls, actual 111 bbls loss of 43 bbls 18:00 19:30 1.50 8,634 8,254 PROD2 DRILL TRIP P Pull out of the hole. Pumping 615 gpm w/ 2260 si. 19:30 20:15 0.75 8,254 8,155 PROD2 DRILL CIRC P Circulate 1.3 BU. Pumping 600-650 gpm w/ 2210- 2530 psi. Rotate 120 rpm w/ 11-12k ft Ibs of torque. Pump 743 bbls. 20:15 20:45 0.50 8,155 8,155 PROD2 DRILL CIRC P Pump a 40 bbl sweep (8.8 ppg/ 290 vis). Pump 650 gpm w/ 2530 psi. Rotate 120 rpm w/ 11-12k ft Ibs of torque. Reciprocate pipe. Circulate surface to surface 1355 bbls). 20:45 23:45 3.00 8,155 8,155 PROD2 DRILL CIRC P Circulate casing clean. Circulated 8 BU till casing was clean.Pumping 650 gpm w/ 2500 psi (ECD's 9.96 ppg), then 700 gpm w/ 2800 psi (ECD's 9.96 ppg). Rotate 120 rpm w/ 12-14k. PU wt 185k, SO wt 105k, Rot wt 140k. 23:45 00:00 0.25 8,155 8,254 PROD2 DRILL OWFF P Pull stripper rubbers. Monitorwell- static. 11/03/2007 00:00 00:45 0.75 8,254 8,254 PROD2 RIGMN' SVRG P Service rig. Blocks, top drive, crown and drawworks. 00:45 01:00 0.25 8,254 8,254 PROD2 RIGMN' SFTY P Pre job safety meeting on changing saver sub on the to drive. 01:00 02:00 1.00 8,254 8,254 PROD2 RIGMN SVRG P Change out the 4-1 /2" IF saver sub on the to drive. 02:00 03:30 1.50 8,254 9,834 PROD2 DRILL TRIP P Trip in the hole on elevators. Ran out of down wei ht. 03:30 06:00 2.50 9,834 11,769 PROD2 DRILL TRIP P Ream in the hole. Pumping 128 gpm w/ 41 G psi. Rotate 50 rpm w/ i 6-i 7k ft Ibs of torque. PU wt 230k, SO wt 72k blook wt ,Rot wt 130k. 06:00 06:45 0.75 11,769 11,769 PROD2 DRILL OTHR T Blow down top drive. Rig up circulating head pin. Circulate 128 gpm w/ 450 m. Page 30 of 49 ...Time Logs _ Date From To Dur S'. De th E_. De tR Phase Code Subcode T COP/1 11/03/2007 06:45 08:15 1.50 11,769 11,769 PROD2 RIGMN SVRG T While changing the swivel packing/washpipe. Circulate 130 gpm w/460 gpm using a headpin and 2" cementin hose. 08:15 08:30 0.25 11,769 11,769 PROD2 DRILL OTHR T Rig down the 2" hose, break the head in. 08:30 18:00 9.50 11,769 17,083 PROD2 DRILL TRIP P Resume reaming in the hole. Pumping 168 gpm w/ 500 to 750 psi. Rotate 55 rpm w/ 17 to 23k ft Ibs of torque. At TD: PU wt 260k, SO wt 72k (block wt), Rot wt (w/ pumps on) 125k, Rot wt (w/ pumps off 165k. Rotating torque (w/ pumps) 23k ft Ibs, Rot torque (w/o pumps) 24-25k ft Ibs. Note: While trip in the hole: Calculated displacement 71.16 bbls, actual 61.2 bbls =loss of 10 bbls. 18:00 20:45 2.75 17,083 17,083 PROD2 DRILL CIRC P Circulate 400 bbls (open hole volume), then pump a 40 bbls sweep (8.6 ppg/ 265 vis). Circulate sweep to surface. Pumping 500 gpm w/ 2750 psi. Reciprocate 80'. Rotate 120 rpm w/ 22k ft Ibs of torque while pumping. Rotating torque with pumps off =25k ft Ibs. PU wt 260k, SO wt 72k (block wt). Rotating wt while pumping is 165k. ECD's while pumping 500 gpm = 11.7 ppg• Final circulating rate of 500 gpm w/ 2680 psi. Rotating 120 rpm w/ 21 k ft Ibs of torque. PU wt 260k, SO wt block wt, Rotating wt 165k. Torque w/ pumps off= 24-25k ft Ibs. Final ED's of 11.47 20:45 21:00 0.25 17,083 17,083 PROD2 DRILL SFTY P PJSM on displacement while still circulating 500 gpm w/ 2610 psi. Reciprocate 80'. Rotating 120 rpm w/ 22k ft Ibs of torque. ECD's 11.7 ppg. Rotatin wt 130k. 21:00 23:00 2.00 17,083 17,083 PROD2 DRILL CIRC P Displace 8.4 ppg MOBM to 8.4 ppg SFOBM. Reciprocate 80'. Rotate 120 rpm w/ 21 k ft Ibs of torque. Pumping 500 gpm w/ 2450 psi. PU wt 170k, SO wt =block wt, Rotating wt 138k. Torque w/ pumps off is 21 k ft Ibs. ECD's 10.54 23:00 23:15 0.25 17,083 16,904 PROD2 DRILL OTHR P Obtain slow pump rates. Pull out two stands to 16904'. Monitor well static. 73;15 23:30 0.25 16;904 16,809 PROD2 DRILL TRIP P POOH on elevators. Hole appears to be swabbing while pulling pipe. Static hole when not movin . 23:30 00:00 0.50 16,809 16,619 PROD2 DRILL TRIP P Pump out of the hole. Pulling 70-90'/min. Pumping 190 gpm w/ 500 psi. PU wt 270k, SO wt is block wt. Monitoring hole via Active Mud System. Record PU and SO values eve 5 stands in o en hole. Page. 31 of 49 ~~ .Time Logs ~ Dane `From To Duf S.`De th E. De t Phase `Code Subcode T = COM _ _ 11/04/2007 00:00 06:00 6.00 16,619 11,484 PROD2 DRILL TRIP P Pump out of the hole. Pulling 70-90'/min. Pumping 190 gpm w/ 500 psi. PU wt 270k, SO wt is block wt. Monitoring hole via Active Mud System. Record PU and SO values eve 5 stands in o en hole. 06:00 10:45 4.75 11,484 8,159 PROD2 DRILL TRIP P Pump out of the hole. Pulling 70-90'/min. Pumping 195 gpm w/ 500 to 400 psi. PU wt 270 to 235k, SO wt is block wt to 90k. Monitoring hole via Active Mud System. Record PU and SO values every 5 stands in open hole. Note: On trip out f/ 17083' to 8159': Calculated fill 77.52 bbls, actual 105 bbls for a loss of 27.48 bbls. 10:45 12:15 1.50 8,159 8,069 PROD2 DRILL CIRC P Reciprocate 90'. Displace to 8.8 ppg/ 65 vis SFOBM w/ 3% 776 lubricants. Pumping 475 gpm w/ 1760 psi. Rotate 120 rpm w/ 12k torque. PU wt 215k, SO wt 90k. Noted a significant increase in cuttings after pumping 361 bbls. Continued to pump till 8.8 ppg SFOBM was all the way to the surface. PU wt 170k, SO wt 115k, Rotating wt 130k, Rot torque 9k After 8.8 ppg SFOBM was to surface, increased the flow rate to 550 gpm w/ 2480 psi. No increase in cuttin s. Circulated a total of 763 bbls. 12:15 12:30 0.25 8,069 8,069 PROD2 DRILL OWFF P Monitor well- static. 12:30 12:45 0.25 8,069 7,873 PROD2 DRILL TRIP P Pull out of the hole. Appeared to be swabbin . 12:45 14:00 1.25 7,873 6,447 PROD2 DRILL TRIP P Pump out of the hole. Pulling 90'/min. Pumping 169 gpm w/ 400 psi. PU wt 170k, SO 115k. Monitoring hole via Active Mud System. Record PU and SO values every 10 stands in cased hole. 14:00 14:15 0.25 6,447 6,447 PROD2 DRILL OWFF P Monitor well- static. 14:15 17:45 3.50 6,447 350 PROD2 DRILL TRIP P Pull out of the hole on elevators and the trip tank.. Record PU and SO wt's every 10 stands. Lay down the ghost reamer (1/16" under the original 8-3/8" measurement . 17:45 18:15 0.50 350 350 PROD2 DRILL OWFF P Monitor well at the BHA- static. Crew change. Clean rig floor. Note: Trip f/ 8159' to the BHA: Calculated displacement 65.7 bbls, Actual 71 bbls. Loss of 5.4 bbls. 18:15 19:00 0.75 350 58 PROD2 DRILL PULD P Lay down BHA #6. Monitor well on the tri tank. 19:00 20:15 1.25 58 58 PROD2 FISH PULD P Download Sperry Sun MWD. Page 32 of 49 ~ ~ Time Logs Date From To Dur S: De th E. De fh Phase" Code Subcode T COM __ _ 11/04/2007 20:15 21:00 0.75 58 0 PROD2 DRILL PULD P Continue to lay down BHA #6. Monitor well on the tri tank. Grade the bit. 21:00 21:15 0.25 0 0 PROD2 FISH PULD P Clear floor of subs and handling tools. 21:15 22:15 1.00 0 0 COMPZ FISH PULD P Pickup to the floor: Baker tools f/ BHA #7 (Whipstock retrieval). Blind rams functioned while out of the hole. 22:15 22:30 0.25 0 0 COMPZ FISH SFTY P PJSM on PU/MU BHA#7. 22:30 00:00 1.50 0 99 COMPZ FISH PULD P PU/MU BHA #7, orient circulating port on the box of the retrieval hook w/ MWD highside (MWD will correct f/ hole bein 72.64 de ri ht of MWD) 11/05/2007 00:00 00:30 0.50 99 99 COMPZ FISH PULD P PU/MU BHA #7. Install pulsar. MU HOC. 00:30 01:15 0.75 99 99 COMPZ FISH PULD P Upload MWD. 01:15 01:45 0.50 99 219 COMPZ FISH PULD P PU/MU BHA #7. 01:45 02:00 0.25 219 313 COMPZ FISH TRIP P Trip in a stand of 5"drill pipe. Shallow pulse test MWD. 330 gpm w/ 3260 si. Detection 250 m. 02:00 03:15 1.25 313 313 COMPZ FISH CIRC T Trouble shoot excessive pressure while circulating. 85 gpm w/ 440 psi. 126 gpm w/ 760 psi, 168 gpm w/ 760 psi, 210 gpm w/ 1800 psi. 252 gpm w/ 2200 psi. 294 gpm w/ 2670 psi. 336 gpm w! 3260 psi. 378 gpm w/ 3900 si. PU wt 90k, SO wt 90k. 03:15 04:00 0.75 313 34 COMPZ FISH CIRC T POOH to 34'. Pump through one jt of 5" HWDP and the retrieving hook. Pumped 200 gpm w/ 320 psi, 250 gpm w/ 460 psi, 300 gpm w/ 670 psi, 350 gpm w/ 940 psi, 400 gpm w/ 1170 psi. A ears to be ok-normal. 04:00 05:15 1.25 34 55 COMPZ FISH CIRC T Break connection at the float sub. Check float-OK. RU 4-1/2" headpin and 2" circ hose. Pump 200 gpm w/ 670 si. A ears ok. 05:15 05:30 0.25 55 106 COMPZ FISH CIRC T Break and lay down bumper sub. Circ through HOC. Pumping 200 gpm w/ 1130 psi, 300 gpm w/ 1990 psi, 400 m w/ 2850 si. 05:30 06:00 0.50 106 106 COMPZ FISH RURD T Blow down top drive and cement hose. Han 2" hose in the derrick. 06:00 08:00 2.00 106 106 COMPZ FISH PULD T Lay down MWD. MU top drive on the float sub. perform pumping test. 100 gpm w/ 80 psi, 200 gpm w/ 290 psi, 300 gpm vr/ 660 psi, 400 gpm w/ 1280 psi, 450 gpm w/ 1560 psi. PU/MU MWd. Perform pumping test: 100 gpm w/ 120 psi, 200 gpm w/ 1170 psi (vibration in the MWD . 08:00 08:15 0.25 110 110 COMPZ FISH RURD T Blow down the top drive. 08:15 09:00 0,75 110 82 COMPZ FISH PULD T Lay down Sperry Sun MWD (RLL). Page 33 of 49 -Time: Logs .' Date From To~ Dur S. be th E:~ De th Phase Code ~ Subcode T_ COM 11/05/2007 09:00 09:30 0.50 82 110 COMPZ FISH PULD T PU/MU MWD. 09:30 10:00 0.50 110 COMPZ FISH OTHR T Orient MWD to the hook. 10:00 10:45 0.75 110 110 COMPZ FISH PULD T Upload MWD. 10:45 11:00 0.25 110 200 COMPZ FISH TRlP T Trip in on a stand. Pumping 100 gpm w/ 120 psi, 200 gpm w/ 1230 psi, 300 gpm w/ 1980 psi, 400 gpm w/ 2890 psi.. There is vibration in the MWD, then the pressure increased to 3320 si and sta ed there. 11:00 12:00 1.00 200 50 COMPZ FISH OTHR T Function the Annular, top pipe rams and the bottom pipe rams a couple of times. POOH to clean off the ma net.Biow down the to drive. 12:00 13:00 1.00 50 220 COMPZ FISH TRIP T Trip into 127', make up a pump out sub above the oil jars.. MU a stand of HWDP, RIH to 220'. 13:00 13:30 0.50 220 2,595 COMPZ FISH TRIP P Trip in the hole w/ retrieving hook. Shallow test MWD: 200 gpm w/ 500 psi, 250 gpm w/ 700 psi, 300 gpm w/ 950 psi, 350 gpm w/ 2950 psi. Good detection. 13:30 17:15 3.75 2,595 8,258 COMPZ FISH TRIP P Continue tripping in w/ BHA #7. Fill pipe 4973': 300 gpm w/ 770 psi. Fill pipe @ 7336': 300 gpm w! 940 psi. Record PU and SO wt's every 10 stands. 17:15 20:15 3.00 8,258 8,371 COMPZ FISH FISH P PU a single of HWDP, continue RIH to 8365'. Establish circulation. Orient to wash slot on whipstock. Wash 8365' to 8371'. Pumping 300 gpm w/ 1220 psi. PU wt 220k, So wt 125k. Rotating wt 168k, Rot torque :30 rpm, 7k ft lbs. Hook whipstock 14 R in the PU mode. 20:15 21:00 0.75 8,371 8,360 COMPZ FISH FISH P PU to 250k, confirm latched fish. Set down and confirmed engaged whipstock. PU to 250k, jar, then pull to 70k over. Set down and cock jars. PU to 290k, fire jars. PU and pulled free w/ 10k dra to 230k. 21:00 22:30 1.50 8,360 8,255 COMPZ FISH CIRC P Stand back a stand of HWDP, UD a single HWDP, drop the shearout ball f/ circ sub (2-3/16" ball/rod), Circulate bottom's up. Lost 14 bbls while circulating. Pump 583 gpm w/ 2180 psi. Obtain SPR's. 22:30 23:00 0.50 8,255 8,255 COMPZ DRILL OWFF P Monitor well. Lite flour then to static. Blow down to drive. 23:00 00:00 1.00 8,255 7,851 COMPZ FISH TRIP P POOH with the whipstock. Swabbing. 11/06/2007 00:00 03:15 3.25 7,851 6,575 COMPZ FISH TRIP P Pump out of the hole with the whipstock. Pumping 270 gpm w/ 500 si. Pullin slow 10-20'/min). Page 34 of 49 ~ ~ Time Logs __ Da ~e ~ ` • ~ ~ From To~' ` C2ur S. De th E;~ De nth Phase • ~: Code ~~ Subcode T _COM 11/06/2007 03:15 04:45 1.50 6,575 5,150 COMPZ FISH TRIP P Pull out of the hole on elevators. Hole not takin correct fill. 04:45 05:00 0.25 5,150 5,150 COMPZ DRILL OWFF P Monitor well- slight flow to static. 05:00 05:30 0.50 5,150 4,775 COMPZ FISH TRIP P Pump 4 stands out of the hole. Pum in 126 m w/ 175 si. 05:30 06:00 0.50 4,775 4,400 COMPZ FISH TRIP P Pull out of the hole on elevators. After breathng subsided, the hole is taking ro er fill. 06:00 10:00 4.00 4,400 280 COMPZ FISH TRIP P Continue to pull out of the hole w/ whipstock retrieval BHA #7. Monitor the well on the tri tank. 10:00 14:00 4.00 280 0 COMPZ FISH PULD P Lay down the whipstock retrieval hook assembly. Check orientation of the whipstock w/the anchor. Note: Calculated fill 87.12 bbls, actual 90 bbls for the entire tri . 14:00 14:30 0.50 0 0 COMPZ FISH PULD P Lay down subs and handling tools. Clean and clear rig floor. Shut the blind rams. 14:30 15:00 0.50 0 0 COMPZ FISH PULD T PU/MU MWD from BHA #7. MU a joint of 5" drill pipe and the stack washing tool. Run in the hole to 93'. Flow test MWD. Pumping 300 gpm w/ 310psi, pumping 400 gpm w/ 490 psi, pumping 450 gpm w/ 750 psi. Pull out of the hole and stand back in the derrick. 15:00 15:15 0.25 0 0 COMPZ FISH SFTY T Pre job safety meeting on PU/MU BHA #8 (Reverse circ junk basket and ma nets 15:15 17:00 1.75 0 56 COMPZ FISH PULD T PU/MU BHA # 8. (8-1/2" OD Reverse circ 'unk basket and two ma nets 17:00 23:00 6.00 56 8,360 COMPZ FISH TRIP T Run in the hole w/ BHA # 8 on the 5" drill string (6 stands slick, 30 stands w/super sliders, 35 stands slick, 17 stands of 5" HWDP, then a stand of 5" slick to work f/ TOW (8365') to the top of the MLZXP liner top f/the "B" lateral (8415.74')) PU wt 210k, SO wt 125k, Rotating wt 165k, Rotating 30 rpm w/ 8k ft Ibs of for ue. 23`.00- 23:15 0.25 8,360 8,365 COMPZ FISH TRIP T Drop the 1"ball to shift the reverse circ basket. MU stand # 89 and pump ball down. Pumping 5 bpm w/ 590 psi, 6.5 bpm w/ 920 psi, 7 bpm w/ 950 psi. Ball on seat after um in 120 bbls. 23:15 00:00 0.75 8,365 8,415 COMPZ FISH CIRC T Increase pump rate to 8 bpm w/ 2660 psi. PU wt 210k, SO wt 125k, Rot wt 150k down and 180K up. Rotate 30 rpm w/ 8k ft Ibs of torque. Work 8360' to 8415' .Rotate f/ 8360' to 8409', then slack off to to to of liner 8415'. Page 35 of 49 Time Logs COM _ Date From To Dur S. De th E. De th Phase' Code Subcode T 11/07/2007 00:00 00:45 0.75 8,415 8,360 COMPZ FISH CIRC __ T Pumping 8 bpm w/ 2660 psi. PU wt 210k, SO wt 125k, Rot wt 150k down and 180K up. Rotate 30 rpm w/ 8k ft Ibs of torque. Work 8360' to 8415' . Rotate f/ 8360' to 8409', then slack off to tag top of liner @ 8415'. Worked across the interval for a total of 5 times. 00:45 01:15 0.50 8,360 8,360 COMPZ FISH CIRC T Break off and set back stand #89, drop the 2-1/8" ball rod. Pump ball to seat w/ initial rate of 202 gpm w/ 1090 psi. Increase pumps to 253 gpm w/ 1560 psi. Once the pump out sub is opened. Shut down. 01:15 02:00 0.75 8,360 8,360 COMPZ DRILL OWFF T Obtain SPR's. Monitor well. 02:00 06:00 4.00 8,360 5,381 COMPZ FISH TRIP T Pump out of the hole. Pumping 42 spm w 500 psi. Pulling 30-40'/min. Monitor displacement on the active pit system. Calculated fill to this point is 40.3 bbls, actual is 52 bbls. 06:00 07:00 1.00 5,381 5,070 COMPZ FISH TRIP T Pump out of the hole. Pumping 30 spm w 190 psi. Pulling 50-70'/min, Monitor displacement on the active pit s stem. 07:00 07:15 0.25 5,070 5,070 COMPZ FISH OTHR T Monitor well- static. Blow down the top drive. 07:15 10:00 2.75. 5,070 53 COMPZ FISH TRIP T Pull out of the hole on elevators. Monitor hole on the trip tank. Record PU and SO wt's every 10 stands. Calculated fill for entire trip is 89.22 bbls, actual fill was 98.5 bbls. Lost 9.28 bbls to hole on the tri . 10:00 11:00 1.00 53 0 COMPZ FISH PULD T Lay down BHA #8. 2.5 gallons of formation debris in reverse junk basket. 1 coffee cup of metal shavin son strip ma nets. 11:00 11:30 0.50 0 0 COMPZ FISH PULD T Lay down subs and handling tools for BHA #8. Clear and clean floor. Shut the blind rams. 11:30 12:15 0.75 0 0 COMPZ CASIN( RURD P Rig up to run the Baker Seal Bore Diverter. 12:15 12:30 0.25 0 0 COMPZ CASIN( SFTY P Pre job safety meeting on running the Seal Bore Diverter. 12:30 15:15 2.75 0 151 COMPZ CASIN( RNCS P PU/MU/RIH with the Seal Bore Diverter assembly to 151'. Oriented the Seal bore PU Seal Bore Diverter and the MLZX production Anchor. Note: The Diverter!^.~ndo~v is 50.1 deg to the right of the anchor lug. The MLZXP in the hole is 3 deg left of high side, therefore the diverter window will end up 47.1 de ri ht of hi h side. 15:15 15:30 0.25 151 139 COMPZ CASIN( RUNL P PU/MU MWD with a 30' single and 10' pup jt. Break off the single, Make up the 10' pup, then make a top drive connection. Pull out of the hole to 139' Page 36 of 49 Time Logs ~ ~ _.,= ~ . bate From ' To Dur ' S: De~ th E: De th Phase Code ' Subcode T ' COM _ __ 11/07/2007 15:30 16:00 0.50 139 139 COMPZ CASIN( OTHR P Upload Sperry Sun MWD. 16:00 16:15 0.25 139 89 COMPZ CASIN RUNL P Pull out of the hole to the top of the Seal Bore Diverter. Obtain offset between MWD and Seal Bore Diverter window. 16:15 16:45 0.50 89 89 COMPZ CASINC OTHR P Manually relase FJD running tool. PU and disengage the running tool. Test volume and pressure for MWD detection and release of the FJD running tool. Results: 250 gpm w/ 500 psi with good MWD detection. Tool reelased (fingers collapsed) at 400 m w/ 1250 si. 16:45 17:00 0.25 89 89 COMPZ CASINC OTHR P Slack off and engage the FJD running tool back into the Seal Bore Diverter. 17:00 17:15 0.25 89 151 COMPZ CASINC RUNL P Trip in the hole to 151'. Lay down the 10' pu ~t. 17:15 17:30 0.25 151 260 COMPZ CASINC RUNL P Run in the hole w/ a stand of 5" drill pipe to 182', break off the first single in the hole, install two string magnets (drifted to 2.87"), then make up the other two drill ipes for stand #1. 17:30 18:00 0.50 260 735 COMPZ CASINC RUNL P Continue to run the Seal Bore Diverter on the 5"drill string. Running speed 60'/min. No rotation. Monitor returns on the trip tank. Note: The 5" drill string will consist of: 6 stands slick, 30 stands w/ super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 64.5' on another stand of HWDP (stand # 88 18:00 23:00 5.00 735 8,296 COMPZ CASINC RUNL P Continue to run the Seal Bore Diverter on the 5" drill string. Running speed 60'/min. No rotation. Monitor returns on the trip tank. Note: The 5"drill string will consist of: 6 stands slick, 30 stands w/ super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 64.5' on another stand of HWDP (stand # 88) 23:00 23:30 0.50 8,296 8,379 COMPZ CASIN OTHR P Make a top drive connection on stand # 87. Pu wt 210k, SO wt 130k. Establish circulation. 23:30 00:00 0.50 8,379 8,379 COMPZ CASINC CIRC T Pumping at varies rates to acquire detection w/ Sperry Sun MWD. Cycle pumps to try to mode switch. No Success. 250 gpm (59 spm) 940 psi. 275 gpm (65 spm) w/ 1090 psi. 300 gpm. (71 spm) w/ 1180-1240 psi. Tried 300 gpm three different times. No Pulse-No Detection. Page 37 of 49 • .Time Logs . . Date-"" ' From To Dur S. De th E: De th~Phase Gode Subcod~~ T COM _ _ _ __ 11/08/2007 00:00 01:30 1.50 8,379 8,379 COMPZ CASINC OTHR T Pumping at varies rates to acquire detection w/ Sperry Sun MWD. Cycle pumps to try to mode switch. No Success. 325 gpm (77 spm) w/ ??? psi. 338 gpm w/ 1560 psi. No Pulse-No Detection. 01:30 06:00 4.50 8,379 4,061 COMPZ CASINC RUNL T Pump out of the hole w/the Seal Bore Diverter. Pumping 40 spm initial then to 20 s m 85 pm) w/ 200 psi. -06:00 06:15 0.25 COMPZ CASINC OTHR T Monitor the well- static. 06:15 07:45 1.50 4,061 4,061 COMPZ CASINC RUNL T Pull out of the hole on elevators. Monitor well on the trip tank. Pulling s eed 20-30'/min 07:45 08:00 0.25 4,061 4,061 COMPZ CASINC OTHR T Monitor the well- static. Blow down the to drive. Install stri in rubbers. 08:00 11:30 3.50 4,061 151 COMPZ CASINC RUNL T Pull out of the hole on elevators. Monitor well on the trip tank. Lay down two string magnets. Pulling speed 40-60'/min. Note Calculated fill 84.26 bbls, actual 84.5 bbls. 11:30 12:15 0.75 151 141 COMPZ CASINC OTHR T POOH to 141', Download MWD. 12:15 12:45 0.50 141 141 COMPZ CASINC OTHR T Break the hang off collar, remove the pulsar, install a new pulsar, make up the han off collar. 12:45 13:15 0.50 141 141 COMPZ CASINC OTHR T Upload Sperry Sun MWD. 13:15 13:45 0.50 141 248 COMPZ CASINC RUNL T Trip in the hole. Shallow pulse test MWD. Pumping 250 gpm w/ 400 psi. Good detection. 13:45 18:00 4.25 248 7,271 COMPZ CASINC RUNL T Trip in the hole with the Baker Seal Bore diverter assembly. Record PU and SO wt's every 10 stands. Fill pipe every 25 stands. Fill pipe @ 2529'- pumping 250 gpm w/ 520 psi, PU wt 115k, SO wt 105k. Fill pipe @ 4911'- pumping 250 gpm w/ 630 psi, PU wt 140k, SO wt 100k. Fill pipe @ 7271'- pumping 250 gpm w! 800 psi, PU wt 165k, So wt 110k. Good detection and pulses every time pipe was filled. RIH on the 5" drill string. Note: The Diverter Window is 50.1 deg to the right of the anchor lug. The MLZXP in the hole is 3 deg left of high side, therefore the diverter window will end up 47.1 deg right of high side. Note: The 5"drill string will consist of: 6 stands slick, 30 stands w/super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 75.85' on another stand of HWDP (stand # 88 Page 38 of 49 • :Time Cogs ., Date From: To Dur S: be th E:'De'th Phase Code `Sukcode T- COM___`__ _ 11/08/2007 18:00 19:15 1.25 7,271 8,295 COMPZ CASINC RUNL T Continue to RIH w/ the Seal bore diverter assembl on the 5"drill strin . 19:15 19:30 0.25 8,295 8,375 COMPZ DRILL TRIP T Make a top drive connection w/stand # 86 in the hole, #87 out. Obtain PU wt 205k, SO wt 130k with pump rate of 250 gpm (59 spm) 940 psi. Obtain PU 210k, SO wt 130k with out the pumps. MWD showing 59 right of hi hside. RIH stand # 87. 19:30 20:00 0.50 8,375 8,241 COMPZ CASIN RUNL P Make a top drive connection on stand # 88, pump 250 gpm w/ 940 psi, MWD still showing 59 right. Slack off and observe taking weight @ 76' in (Collet profile @ 8428.53')(8453.73' -mule shoe of seals), Set down 40k to 87k(79' in) on the weight indicator. MWD showing 50 right of highside. PU to 285k (75k overpull) (72' in }. Slack off to 120k. Pump 425 gpm (101 spm) w/ 2240 psi to try and release FJD running tool. PU to 230k- not released. Slack off to 110k, then increase pumps to 450 gpm (106 spm) w/ 2520 psi. PU to 230k- still not released. Slack off to 100k, then pump 475 gpm w/ 2860 psi. PU with 200k. Continue to pull stand # 88 out and rack it back while pum in 475 m w/ 2860 si.. 20:00 20:45 0.75 8,241 7,875 COMPZ CASIN( RUNL P Pump four more stands of 5" HWDP out of the hole. Pumping 475 gpm w/ 2860 si. 20:45 21:00 0.25 7,875 7,875 COMPZ CASINC CIRC P Finish circulating a bottom's up. 440 bbls pum ed 475 m w/ 2860 si. 21:00 22:30 1.50 7,875 0 COMPZ WELCT OTHR P PU/MU Baker 9-5/8" "EA Retrievamatic- storm packer". RIH on two singles of 5" dp and set w/ Center of packer element @ 76.41' (top of retrievamatic @ 63.97'). Tail of the Seal bore running tool @ 7957'. Lay down two singles and running tool. Test the annulus to 500 psi f/ 5 min - OK. 22:30- 22:45 0.25 0 0 COMPZ WELCT OTHR P Pull Vetco Gray wear bushing. 22:45 23:30 0.75 0 0 COMPZ WELCT OTHR P Rig up to test BOPE. 14 day test. Fill stack with water. Witness of test waived by AOGCC inspector Jeff Jones. 2_3:30 0000 0.50 0 0 COMPZ WELCT BOPE P Test annular w/ 4-1/2" test joint. Test against choke line HCR, kill line Demco valve, floor dart valve. Test to 250 psi low and 3000 psi high. Hold each test 5 min. Chart test. Page 39 of 49 Time Loc,~s Date From To " Dur '` S. De th E. be th Phase Code Subcode T COM _ ___ _ 11/09/2007 00:00 05:30 5.50 0 0 COMPZ WELCT BOPE P Finish testing BOPE (14 day test). Witness of test waived by AOGCC inspector Jeff Jones. Test w/ 4-1/2" test joint: Top pipe rams (3-1/2" x 6" variables) and floor safety valve, both valves on the kill line and choke line, top drive manual and IBOP valve. Test upper pipes rams w/ 5" test joint: Test all valves on the choke manifold. Test accumulator: 3000 psi initial ,after closing 1500 ps. 200 psi build up in 49 seconds, full charge in 3 min 18 seconds. Test the blind rams. All tests to 250 psi high and 3000 psi low. Chart tests. Gas alarms tested. 05:30 06:30 1.00 0 0 COMPZ WELCT OTHR P Rig down testing equipment. Drain the stack, pull the test plug, set Vetco wear bushing. Blow down choke manifold and choke and kill lines. 06:30 06:45 0.25 0 0 COMPZ RIGMN SFTY P PJSM on slipping and cutting drilling line. 06:45 08:15 1.50 0 0 COMPZ RIGMN SVRG P Slip and cut 161' of 1-3/8"drilling line. Inspect brake linkage, brake bands for even and or excessive wear. 08:15 08:45 0.50 0 0 COMPZ RIGMN SVRG P Service the top drive, blocks, and crown. 08:45 09:15 0.50 0 0 COMPZ RIGMN SVRG P Adjust the brakes on the drawworks. 09:15 09:30 0.25 7,810 COMPZ WELC SFTY P Pre job safety meeting on 09:30 10:00 0.50 0 64 COMPZ WELCT OTHR P MU retrieving tools and two joints of 5" drill pipe with a floor safety valve to retrieve the Baker "EA retrievamatic storm packer. 10:00 10:45 0.75 64 7,810 COMPZ WELCT OTHR P Screw into the Baker "EA retrievamatic" storm packer. Check for pressure. Pull free. Pull to the rig floor, break and la down same. 10:45 11:00 0.25 7,810 7,810 COMPZ CASIN( OTHR P Monitor the well- static. 11:00 12:30 1.50 7,810 7,810 COMPZ CASIN CIRC P Circulate bottom's up. Pumping 350 gpm w/ 1590 psi.. Circulated 472 bbls. Pu wt 200k, SO wt 125k. 12:30 12:45 0.25 7,810 7,810 COMPZ CASIN OTHR P Monitorwell-static. 12:45 13:30 0.75 7,810 7,600 COMPZ CASINC RUNL P Pull out of the hole 3 stands of 5" HWDP. Hole a pears to be swabbin . 13:30 16:00 2.50 7,600 5,961 COMPZ CASINC RUNL P Pump out of the hole. Pumping 210 gpm w/ 670 psi. PU wt 150k, SO wt 100k. Monitor well on the activice s stem. 16:00 16:15 0.25 5,961 5,961 COMPZ CASINC RUNL P Monitorwell-static. 16:15 21:00 4.75 5,961 72 COMPZ CASINC RUNL P Pull out of the hole on elevators. Pulling speed 80'/min. Monitor well on the tri tank. Page 40 of 49 Time Logs Date From To Dur S; De th E; De th' Phase Code Subcode ' T CQM _, _ 11/09/2007 21:00 21:30 0.50 72 72 COMPZ CASINC OTHR P Download Sperry Sun MWD. 21:30 22:30 1.00 72 0 COMPZ CASINC OTHR P UD MWD. UD BAker FJD Seal Bore Diverter running tool. Note: Calculated fill 85.5 bbls, actual fill 79.28 bbls (loss of 6.22 bbls . 22:30 22:45 0.25 0 0 COMPZ CASINC OTHR P Clear and clean rig floor. 22:45 23:45 1.00 0 107 COMPZ CASINC RNCS P PU/MU Baker Ram Hanger Dummy Run assembl . 23:45 00:00 0.25 107 200 COMPZ CASINC RUNL P Run first stand of 5" Drill string 11/10/2007 00:00 06:00 6.00 200 8,329 COMPZ CASIN RUNL P Continue to run in the hole with the Baker RAM Hanger "Dummy Run" on 5"drill string. Monitor displacement on the trip tank. RIH 60' per min = 90 sec per stand running speed. Fill pipe every 20 stands. Pumping 20 spm w/ 160 psi. Max 1000 psi limit. Note: The 5"drill string will consist of: 6 stands slick, 30 stands w/super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 31.83' single drill pipe, then another stand of HWDP (stand # 88 . 06:00 06:45 0.75 8,329 8,446 COMPZ CASINC RUNL P With stand # 87 in the hole, PU/MU a single of 5"drill pipe (31.83'). Then a top drive connection. Obtain parameters: PU wt 205k, SO wt 135k, Rotating weight 165k, rotating rpm @ 30, Rot torque 5-8k ft lbs. Then set the torque limit f/ 10k ft Ibs max. While pumping 5 bpm w/ 860-870 psi, wash the single in the hole (8329' to 8361'). Make a top drive connection on stand #88. Pumping 5 bpm until 57' on the stand is the hole (8418'), then turn off pumps. Calculated depth: Guide shoe @ full ramp of the diverter with 10.62' in. Calculed depth's: Shoe @ the top of SB Diverter w/ 1.98' up on the single, @ top of milled window 4' in on #88, Center of milled window 12.49' in, bottom of milled window 21' in. Calculated depth's: Bottom of ported x-o: 48.46' in places it at the top of the SB diverter. 52.36' in =bottom of hanger @ top of diverter. 81.55' _ collet @ top of SB diverter. Latch in 84.52'. Indications of latched in with 10k set down with 86.5' in (120k on the weight indicator). with 40k set down (90k on the wei ht indicator): 87.75' in. Page d1 of 49 • Time Logs - Date From To Dur S. De th E De th Phase Code Subcode T COM _ _ 11/10/2007 06:45 07:30 0.75 8,446 8,401 COMPZ CASIN( RUNL P Pick up to snap out. Snap out occured with weight indicator reading 275k (70k over) and 80' in on jt. Pick up to 40' in (8401'). Start pumping 5 bpm and rotating with 152k rotating weight, 30 rpm w/ 6-9k ft Ibs of torque. Rotate while slacking off @ 7'/min. Turn off the pumps again @ 57' in (8418'). Continue rotating while slacking off w/ 155k rot weight. Tag up w/ 84.75' in (8445.75'). With indications of 10k set down @ 85.25' in (8446.26'). Shut down the rotary. Set down 30k to snap in (100k on the weight indicator) with 86' in (8447.01'). Continue to slack off 40k set down (90k on the indicator) with 87.5' in (8448.51'). Pick up to snap out: Snap out occured w/ 265k on the weight indicator (60k over). Pull out of the hole w/ PU wt 210-220k. Pull stand # 88 out of the hole (Shoe above the diverter). Run in the hole to exit the shoe again past the diverter ramp. RIH 40' in 8401.01' . SO wt 135k. 07:30 07:45 0.25 8,401 8,326 COMPZ CASINC RUNL P Pull out of the hole on elevators to 8360', POOH, UD the single 5"drill i e, 07:45 08:00 0.25 8,326 8,326 COMPZ CASINC OTHR P Monitor well- static. Install air slips and stri in rubbers. 08:00 10:45 2.75 8,326 6,381 COMPZ CASIN RUNL P Pump out of the hole w/ Baker "Dummy run" RAM Hanger. Pumping 220 gpm w/ 710 psi. Monitor well on active mud s stem. 10:45 11:00 0.25 6,381 6,381 COMPZ CASINC OTHR P Pull stripping rubbers and air slips. Monitor well- static.. Install stripping rubbers and air sli s. 11:00 11:30 0.50 6,381 5,905 COMPZ CASINC RUNL P Pull out of the hole on elevators, monitoring well on the trip tank. A ears to be swabbin .. 11:30 12:30 1.00 5,905 4,859 COMPZ CASINC RUNL P Continue to pump out of the hole w/ Baker "Dummy run" RAM Hanger. Pumping 220 gpm w/ 710- 550 psi. Monitor well on active mud s stem. 12:30 12:45 0.25 4,859 4,859 COMPZ CASINC OTHR P Pull stripping rubbers and air slips. Monitor well- static.. Install stripping rubbers and air sli s. 12:45 13:15 0.50 4;859 4,383 COMPZ CASINC RUNL P Pull out of the hole on elevators, monitoring well on the trip tank. A ears to be swabbin .. 13:15 18:15 5.00 4,383 295 COMPZ CASINC RUNL P Continue to pump out of the hole w/ Baker "Dummy run" RAM Hanger Assembly. Pumping 220 gpm w/ 550- 210 psi. Monitor well on active mud. s stem. Page 42 of 49 ~I :Time Logs. _, Date From To` Dur S De th E`De th` Phase '` Gode Subcode T COM _ _ _ 11/10/2007 18:15 18:45 0.50 295 107 COMPZ CASIN< RUNL P Pull the last two stands of slick 5"drill i eon elevators. 18:45 19:00 0.25 107 107 COMPZ CASIN( OTHR P Blow down top the top drive. 19:00 20:00 1.00 107 0 COMPZ CASIN( OTHR P Break and lay down the Baker 6.25" bumper sub, Baker 9-5/8" x 6-5/8" "RAM Hanger, 6-5/8" ported crossover w/ 4-1/2" pup jt, 4-1/2" hyd 521 x 4-1 /2" BTC crossover, then the Shoejt (4-1/2" BTC blank jt w/ 4-1/2" x 5-1/2" crossover and 5-1/2" uide shoe). 20:00 20:30 0.50 0 0 COMPZ CASIN OTHR P Clean rig floor. 20:30 21:15 0.75 0 0 COMPZ CASINC RURD P Rig up to run the 4-1 /2" slotted/blank liner f/ the "D" lateral using the Baker RAM hanger. Lay down Sperry Sun short tools (HOC) from the pipe shed via ri floor to beaver slide. 21:15 21:45 0.50 0 0 COMPZ CASIN SFTY P Pre job safety mmeting on the liner run. 21:45 00:00 2.25 0 3,322 COMPZ CASINC RNCS P Run the 4-1/2" slot/blank liner f/ the "D" lateral per the detail. Monitor returns on the trip tank. Jt # 77 in the hole @ midnight. Recod PU and SO wt's er the Ri En ineer. 11/11/2007 00:00 04:45 4.75 3,322 8,333 COMPZ CASINC RNCS P Continue to run the 4-1/2" slot/blank liner f/the "D" lateral per the detail f/ jt # 77 to jt # 196. Monitor returns on the trip tank. Recod PU and SO wt's per the Ri En ineer. 04:45 05:15 0.50 8,333 8,333 COMPZ CASINC OTHR P MU rig floor crossovers. Make a top drive connection to obtain PU wt 120k, SO wt 93k, rotating 30 rpm w/ 4500 ft Ibs of torque, Rot wt 102k. PU rotating wt 115k, SO rotating @ 10'/min w/ 102k. 05:15 05:30 0.25 8,333 8,628 COMPZ CASINC RNCS P Continue to run the 4-1 /2" slot/blank liner f/the "D" lateral per the detail f/ jt # 196 to jt # 203. Monitor returns on the trip tank. Recod PU and SO wt's er the Ri En ineer. 05:30 07:00 1.50 8,628 8,689 COMPZ CASINC RNCS P Make up the ported x-o, then PU The RAM hanger, MU inner string, MU the RAM Hanger, RIH, make up the Baker bum er sub and RIH, 07:00 07:30 0.50 8,689 8,774 COMPZ CASIN RUNL P Run the first stand of 5" drill string. Make a top drive connection to obtain PU wt 125k, SO wt 95k, rotating 30 rpm w/ 5000 ft Ibs of torque, Rot wt 100k. PU rotating wt 115k, SO rotating @ 10'/min w/ 102k. Circulate 5 b m 210 pm w/ 290 si. Page 43 of 49 a • Time Ldgs _ Date From To Dur S De th E. De th Phase Code Subcode T " COM _ ___ 11/11/2007 07:30 11:45 4.25 . 8,774 14,581 COMPZ CASIN( RUNL P ___ Continue to RIH w/the 4-1/2" 11.6 ppf, L-80 BTC & Hyd 521 slot/blank liner f/ the "D" lateral, on the 5" drill string. Record PU and SO wt's. every 5 stands, per the Rig Engineer. Fill pipe @ 11059' pumping 5 bpm w/ 490 psi. Fill pipe @ 14390' pumping 210 gpm w/ 650 psi. Note: The 5"drill string will consist of: 6 stands slick, 30 stands w/super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 31.83' single drill pipe, then another stand of HWDP stand # 88). 11:45 12:00 0.25 14,581 14,676 COMPZ CASIN( RUNL P Rotate in the hole w/the liner due to insufficient SO wt. Rotate 30 rpm w/ 8-10k ft Ibs of torque. PU wt 182k, SO wt 72k. 12:00 15:15 3.25 14,676 16,942 COMPZ CASIN( RUNL P Continue to rotate in the hole w/ the liner due to insufficient SO wt. Record PU and SO wt's every 5 stands, per the Rig Engineer. Depth 16942': No pumps/no rotation PU wt 240k, SO wt 105k. RIH w/ stand 87 and PU &RIH w/single, MU stand 88. Rotate 30 rpm w/ 9-11 k ft Ibs of torque, PU wt 200k, SO wt 148k. Set top drive limit to 13k ft-Ibs. Calculated displacement 79.17 bbl, actual 72.5 bbls. 15:15 15:45 0.50 16,942 17,027 COMPZ CASINC RUNL P Pump 210 gpm w/ 830 psi and start rotating stand 88 in. Pumps off 54' in on stand 88 (shoe at 16,996.8', ported sub at 8364.6'). By 80' in rotation decreased to 10rpm at 13k ft-Ibs w/ 130k down. Continue to 86' in by which point top drive stalled. Set down to 110k (20k setdown). Turn top drive off, slowly release torque. PU, see bumper sub open at 210k, snap-out at 260k (50k snap-out) w/ minimal PU after snap-out. Set down w/ no rotation to 95k. PU, bumper sub open at 210k and continue to PU at 220k w/ no overpull (RAM was not snapped in). Set down to 80k. PU, bumper sub open at 210k and snap out at 250k (40k snap-out). Set down to 80k to same mark as previous set down. PU, bumper sub open at 210k and continue to 220k (10k overpull). Set down to 80k. Page 44 of 49 • Time Logs .Date F From To Dur " S. De th E De th Phase Code ' Subcode T COM __ _ ~ 11/11/2007 15:45 17:15 1.50 8,514 8,430 COMPZ CASINC CIRC P Break off top drive, drop ball, and -make up top drive. Pump 29/32" ball to seat, 84 gpm w/ 300 psi. Ball on seat after 160bb1 pumped. Pressure up to 3500psi, bleed off. PU, see bumper sub at 210k and continue to 230k (not released). Set down to 80k. Pressure up to 3500psi, bleed off. PU, see bumper sub at 210k and continue to 235k and hold for several seconds, weight dropped off to 210k (released). Pull entire stand 88 out (bottom of inner string at 8369.7'), RIH to 20' in on stand 88 (bottom of inner string at 8389.7', expected sealbore diverter tag at 8381.9'). Pull entire stand 88 back out plus another 8' of the single, RIH and set down 9k 10' in on stand 88 (bottom of inner string at 8379.7). PU and stand back stand 88. 17:15 17:30 0.25 8,430 8,338 COMPZ CASINC OTHR P UD single. MU top drive and pressure to 4400 si to shear ball seat. 17:30 19:30 2.00 8,338 8,338 COMPZ CASINC CIRC P Circulate 280 gpm w/ 740 psi. Pump a total of 747 bbls. 19:30 21:30 2.00 8,338 7,600 COMPZ CASINC RUNL P Pull out of the hole, Laying down 5" HWDP. Monitor well on the tri tank. 21:30 21:45 0.25 7,600 7,600 COMPZ CASINC OTHR P Observe well- static. 21:45 23:30 1.75 7,600 6,868 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP. Monitor well on the tri tank. 23:30 23:45 0.25 6,868 6,868 COMPZ CASINC CIRC P Pump a 20 bbl dry job (10 ppg/194 vis- using safe Carb 250-1400 pounds--28 sx), chase w/ 10 bbls. Drop Haggard ID pipe wiper (1-3/4" OD float tube). Blow down the top drive. 23:45 00:00 0.25 6,868 6,800 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP. Monitor well on the tri tank. 11/12/2007 00:00 06:00 6.00 6,800 1,950 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP, 5" w/super sliders, and 5" slick drill pipe. Monitor well on the tri tank. 06:00 08:00 2.00 1,950 100 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP, 5" w/super sliders, and 5" slick drill pipe. Monitor well on the tri tank. 08:00 08:15 0.25 100 100 ~=OMPZ CASINC OTHR P Remove super sliders and hardware from the floor. Clear floor. 08:15 08:30 0.25 100 100 COMPZ CASINC SFTY P Pre job safety meeting for laying down Baker running tools and inner string f/ the RAM han er f/the "D" lateral. Page 45 of 49 ,Time Logs , Date ~ From ,To Dur S. De th~ E: De th Phase Code- Subcode T- COM _ _ 11!12/2007 08:30 09:45 1.25 100 0 COMPZ CASINC OTHR P Lay down Baker running tool. Monitor well on the trip tank. Retrieve the Haggard ID wiper. Calculated fill 85.41 bbls, actual 95 bbls- f/ a 10 bbl loss while POOH. 09:45 10:00 0.25 0 0 COMPZ DRILL OTHR P Pull the mouse hole. Remove the drain line and install a bull plug. Set mouse hole in the rotary table. Monitor well on the tri tank. 10:00 10:15 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on laying down 5"drill pipe from the derrick using the mouse hole. 10:15 12:00 1.75 0 0 COMPZ DRILL PULD P Lay down 5"drill pipe from the derrick. 12:00 13:00 1.00 0 0 COMPZ DRILL OTHR P Clear floor of Baker tools, GBR tools and drillin tools host reamer 13:00 14:15 1.25 0 0 COMPZ DRILL PULD P Continue to lay down 5" drill pipe from the derrick. Monitor well on the trip tank. 14:15 15:15 1.00 0 0 COMPZ RIGMN SVRG P Service rig, top drive and drawworks. 15:15 18:00 2.75 0 0 COMPZ DRILL PULD P Continue to lay down 5" drill pipe from the derrick. Monitor well on the trip tank. (37 stands layed down-- 36 stands left to la down. 18:00 20:45 2.75 0 0 COMPZ DRILL PULD P Continue to lay down 5" drill pipe from the derrick. Monitor well on the trip tank.No gain or loss while laying down dp f/derrick. Note: 22 stands of 5" drill pi-pe left in the derrick. 20:45 21:15 0.50 0 0 COMPZ DRILL OTHR P Remove mouse hole f/the rotary table. Pull Vetco/Gra 's wear bushin . 21:15 21:45 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 21:45 23:00 1.25 0 0 COMPZ RPCOti RURD P Change elevators, prepare casing tongs. PU tools for HOWCO slickline, brin Centralift tools to the floor. 23:00 23:30 0.50 0 84 COMPZ RPCOti RCST P PU TTC crossover w/screen intake, 4-1/2" 12.6 ppf IBT-m L-80 pup joint, MU first two joints of 4-1/2" 12.6 ppf, L-80 IBT-m tubin . 23:30 23:45 0.25 84 84 COMPZ RPCO6 SFTY P Pre job safety meeting w/ HOWCO slickline. 23:45 00:00 0.25 84 84 COMPZ RPCOti PULD P Install TTC x-o/pump eye, gas separator, Pump 63 stage FC 6000 (High volume Middle Tandem), Pump 53 stage FC6000 (High Volume Middle Tandem and set inside the strin^. Page 46 of G9 C~ ;~ Time Logs S: De th E De th' Phase' ! Code ' Subcode T COM Date From To Dur 11/13/2007 00:00 00:45 _ 0.75 84 84 COMPZ RPCOh PULD P Finish making up the TTC x-o/pump eye, gas separator, Pump 63 stage FC 6000 (High volume Middle Tandem), Pump 53 stage FC6000 (High Volume Middle Tandem), HV Bolton discharge Head 2-3/8", X-O 2-3/8"to 2-7/8", 2-7/8" pinto pin spacer pipe, Bow spring 450 TTC, nip tbg 2.88- 8 rd EUE x 12" J55, Hanger Rece tical, Polishbore/ Fishin neck. 00:45 01:00 0.25 84 84 COMPZ RPCOh RURD P Rig up HOWCO slickline. Using .125" wire, 8' of 2-5/8" stem, and LSS. Usin 4-1 /2 GS 01:00 01:45 0.75 84 84 COMPZ RPCOti SLKL P Howco slickline Install TTC x-o/pump eye, gas separator, Pump 63 stage FC 6000 (High volume Middle Tandem), Pump 53 stage FC6000 (High Volume Middle Tandem), HV Bolt on discharge Head 2-3/8", X-O 2-3/8" to 2-7/8", 2-7/8" pinto pin spacer pipe, Bow spring 450 TTC, nip tbg 2.88- 8 rd EUE x 12" J55, Hanger Receptical, Polishbore/ Fishing neck.Overall length 48.03'. HOWCO slickline install D&D stinger, 2-7/8" dart type check valve, 2-7/8" EUE 8rd spacer pipe, Kobe Knock out, D&D packoff assembly. Overall length 10.29'. Howco slickline RIH w/ D&D test tool. then POOH. 01:45 02:45 1.00 84 84 COMPZ RPCOti DHEO P Rig up the 4-1/2"IBT X-O to 4-1/2" IF with a headpin, fill w/water, test to 1000 psi f/ 15 min. Good test- lost 20 psi first 5 min, then held steady f/ 10 more minutes.. Rig down headpin and test hose. 02:45 03:00 0.25 84 84 COMPZ RPCOh SLKL P Howco slickline retrieve the D&D test tool. RIH and set the Slip stop/Tubing sto . Ri down HOWCO slick line. 03:00 03:15 0.25 84 0 COMPZ RPCOti RCST P MU the 4-1/2" 12.6 ppf L-80 IB-m pup jt, Unique pressure discharge sub, and 4-1/2"_12.6 ppf L-80 IBT-m pup joint. Stand back the stand of completion arts: 101.05' 03:15 03:30 0.25 0 0 COMPZ RPCOti SFTY P Pre job safety meeting on running the 4-1/2" ESP com letion. 03:30 05:00 1.50 0 37 COMPZ RPCOh PULD P PU motor, attatch the mtr centralizer, service motor pumping CL-5 oil to fill. Attatch the 1/4 stainless cable to the A-Well pump guage. Install six 1-1/4" stainless steel bands on the motor, securin the 1/4" ca illa tube. Page 47 of 49 J Time Logs _ Date ~ From To Dur S. De th' ~E De ih` Phase Code ~~ Subcode T COM 11/13/2007 05:00 06:00 1.00 37 49 COMPZ RPCOfu PULD P PU Upper and Lower Tandem seal section. Install coupling. Bolt seal section to motor section. Service seal section. Used (1) 5.875" Protecttolizer gauard on motor and (2) on pump, lus 2) 5.625" flat uards. 06:00 10:15 4.25 49 72 COMPZ RPCOti RURD P Rig up the Centralift sheave f/the 1.40" diameter ESP cable. Perform continuity test (good). Install 5.13" screen intake and connect stainless cap tube to discharge port, banding while RIH. (6 Stainless steel bands used on motor assembly). String ESP over sheave and continuit test. 10:15 12:00 1.75 72 974 COMPZ CASIN( RNCS P Run 2 joints of 4-1/2", 12.6 Ib/ft, L-80 IBT-M SCC tubing, PU/MU Pressure discharge sub, continue running Tbg and checking continuity every 30 joints. Record SO weights every 10 joints, starting at #50 and monitor dis lacement on the tri tank. 12:00 18:00 6.00 974 4,745 COMPZ CASIN RNCS P Continue runing 4-1/2" tbg completion checkin continui eve 30'oints. 18:00 22:00 4.00 4,745 7,294 COMPZ CASINC RNCS P Contunue running 4-1/2" tubing completion to 7,294', checking continuity every 30 joints and monitoring displacement on TT. (hole took proper fill while running Tbg). NOTE: 208 Canon clamps, an 20 flat SS bands used on ESP cable. 22:00 22:30 0.50 7,294 7,294 COMPZ CASINC RNCS P Remove air slips, PU tubing hanger and orient roduction port. 22:30 22:45 0.25 7,294 7,294 COMPZ CASINC RURD P RD power tongs and casing equipment, monitor well -static. Turn on Automatic hole fill to monitor trip tank during cable splice. Continuity test ood. 22:45 00:00 1.25 7,294 7,294 COMPZ CASINC OTHR P Install Penetrator, measure, cut and splice ESP cable to enetrator. 11!14/2007 00:00 02:00 2.00 7,294 7,294 COMPZ RPCOI~ OTHR P Continue to splice ESP cable 02:00 02:30 0.50 7,294 7,294 COMPZ RPCOti DHEQ P Connect ESP cable and Penetrator. Test continui - ood. 02:30 03:15 0.75 7,294 0 COMPZ RPCOti HOSO P Drain stack, land tbg hanger, RILDS and install BPV. 03:15 03:45 0.50 0 0 COMPZ RPCOh PULD P LD landing joint. Test lower hanger seals and void space to 250 psi -Low and 5,000 si - Hi h. 03:45 05:30 1.75 0 0 GOMPZ RPCO[4 NUND P Disconnect Kil! and Choke lines, ND stack. Clean and clear rig floor and clean drip pan. 05:30 06:15 0.75 0 0 COMPZ RPCOI~ DHEQ P Perform final continuity test per Centrilift technician -good. Change out Saver sub and Upper/lower IBOPs valves. PagQ 4$ of 49 r: • Time Logs ' Date From To Dur 8r De th E. De th Phase ' Code Subcode T COM _ 11/14/2007 06:15 10:30 4.25 0 0 COMPZ RPCOti NUND P NU tree adaptor and tree. Test void to 250 psi low and 5,000 psi high for 15 min. Pull BPV and install TWC. Test tree to 250 psi low and 5,000 psi high for 10 min. Clean its. 10:30 11:30 1.00 0 0 COMPZ RPCOti RURD P RU Hot Oil equipment and lines to wellhead for freeze rotect. 11:30 14:45 3.25 0 0 COMPZ RPCOti FRZP P Freeze protect well with 172 bbl of diesel pumped down the annulus. Lost 7 bbl to formation while pumping. Pumped diesel to 2,408' tmd. (1,791' tvd. Finnish change out of Saver sub and IBOPs. Continue cleaning pits. RD ri floor to skid. 14:45 17:30 2.75 0 0 COMPZ RPCOti FRZP P Continue RD rig floor. U-tube freeze protect diesel for 1 hour. Blow down air /water /steam lines to rig floor. Continue cleaning pits. NOTE: final pressure on Tbg = 100 psi and final annulus pressure = 350 psi after U-tube of diesel FP. 17:30 18:00 0.50 0 0 DEMOB MOVE RURD P Pin back Beaver Slide, ready upper deck for skidding floor, RD freeze protect equipment and lines. Pin back Mezzanine landing, RD interconnect mud lines to the it module. 18:00 21:00 3.00 0 0 DEMOB MOVE RURD P PJSM for skidding rig floor, skid same. Diesel FP did not U-tube due to check valve above pump. Skid rig floor back and ull BPV with lubricator. 21:00 21:45 0.75 0 0 COMPZ RPCOh FRZP T RU Hot Oil and lines to tree. Pump 1.3 bbl. and shear out SV valve in GLM at 1,993'. Valve sheared at 2100 psi. Pump two addition bbl of diesel to ensure shear out was o en. 21:45 22:45 1.00 0 0 COMPZ RPCOh FRZP T U-tube diesel to 1993' MD / 1651' TVD in tbg and 2521' MD / 1829' TVD in annulus. Monitor well. Final Tbg pressure & Annulus pressure = 300 psi. Shut-in and secure well. Continue cleanin its. 22:45 23:00 0.25 0 0 COMPZ RPCOh FRZP T RD Hot Oil equipment. 23:00 00:00 1.00 0 0 DEMOB MOVE RURD P Set BPV and LD lubricator. Secure well. NOTE: Rig released at 24:00 hours 11-14-07. Page 49 of 49 i • 18-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-178 L1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 8,328.73' MD Window /Kickoff Survey: 8,365.00' MD (if applicable) Projected Survey: 17,083.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 _ , _ . Date ~~ cvh~,~C~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~a?-~~~ • • o a ~ d SARAH PAUN, GOVERNOR a~a1v-7~ OIIr ~ ei417 333 W. 7th AVENUE, SUITE 100 C011T3I:RQA'1`I011T C011IDIISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-178L1 ConocoPhillips Alaska, Inc. Permit No: 207-122 Surface Location: 1647' FSL, 2452' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1855' FNL, 1507' FEL, SEC. 15, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and. Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Since , l~~ John K. Norman /~ Chairman DATED thi~d~ayrLO/f September, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~t' 0 7 2007 . .~~~ ~'~ ~~s Cons. Commission ~afiOEl~sr~ann ta. Type of Work: Drill ^/ - Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^/ - Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-178L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17068' i ND: 3212' ` 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1647' FSL, 2452' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ~, ~, ADL 25661, 25662, 25663, 385172 West Sak Oil Pool Top of Productive Horizon: 1401' FSL, 1627' FEL, Sec. 3, T10N, R10E, UM 8. Land Use Permit: ALK 471, 217, 472, 2181 13. Approximate Spud Date: 9/28/2007 Total Depth: 1855' FNL, 1507' FEL, Sec. 15, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to ~ /lt i t Nearest Property: ~ /L/2K 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558760 ' y- 5945459 Zone- 4 10. KB Elevation (Height above GL): 121' AMSL ` feet 15. Distance to Nearest p'•//•o Well within Pool: 1J-158L1 , 288' @ 122E 16. Deviated wells: Kickoff depth: 8529' ~ ft. Maximum Hole Angle: 91.6° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1391' psig " Surface: 1035 psig 18. Casing Program e if catio S Setting Depth Quantity of Cement Size i p c ns Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 78.6# H-40 Welded 80' 40' 40' 120' 120' 347 sx AS 1 16" 13-3/8" 68# L-80 BTC 3607 40' 40' 3647 < 2200' ~ 720 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9095' 40' 40' 9135' ; 3288' ~ 560 sx DeepCRETE 8.5" 4.5" 11.6# L-80 BTCM 8539' 8529' 3211' 17068' , 3212' ~ slotted liner 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) Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Drilling Team Leader Signature ~1 ~_ ~ ~ " ~ Phone '~ ~ ~~ ~. ~. S ~, Date ~~ ,l •'y lv7 h All Drak Commission Use Only Permit to Drill ~ /~ ~f Number: N./ ~ ~ /v~ API Number: 2 2 / T~ 50- ~~j9~ ~ J 7 ~Qj' (oV Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No (]' Mud log req'd: Yes ^ No [~' Other: ~~ ~ 3~~ -~-~;~.,~ H2S measures: Yes ^ o [~i' Directional svy req'd: Yes ~ No ^ ~~ Q , mod{ .G~°-'°°.~- -Y- ~, ~l~~~"'J _ /~OJ/ ~/ ~ ~~PPROVED BY THE COMMISSION DATE: C+•~ Gam- f` /V ~ ,COMMISSIONER 2i~ct Form 10-401 Revised 12/2005 ~ ~ ~ v ~ ~~ ~ L Submit in Duplicate Ap~on for Permit to Drill, Well 1 J-178 L1 Revision No.O Saved: 7-Sep-07 Permit It -West Sak Well #1J-178L1 ""d Application fog Permit to Dill Document r.w ~k r 11~i+~~c'~II • rat a x i rr, i a~ WWII Vplue Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl• ................••...,.......................................................:.................:...:........ 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .............•••••••••..........................................................................-••--•.•• 2 Requirements of 20 AAC 25.050(b)..' ........................................................................................................... 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3)........••••••• ........................................:................................................. 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests ..................:............................... 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 25.OOS(c)(6) ..............................................................,.......................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 2S. 005(c) (8) ................................................. •. •. •. •. •............................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ............................................................................... 4 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) .....................................................................................:......••-•...... 5 11. Seabed Condition Analysis .................................... ................... ... .......... ... 5 Requirements of 20 AAC 25.005 (c)(11) ....................................................................... .......................:.... 5 12. Evidence of Bonding ..............................................................................................:.... 5 1J-178 L1 PERMIT IT Page 1 of 6 O ~ ~ ~ ~ ~ ~ ~ Printed.• 7-Sep-07 • App~n for Permit to Drill, Well 1J-178 L1 Revision No.O Saved: 7-Sep-07 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ..................................................... ........... 5 Re uirements o 20 AAC 25.005 c 13 ..............................,. 5 9 f O( ) ...................................................................... 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 6 Requirements of 20 AAC 25.005 (c)(~4) ...................................................................................................... 6 15. Attachments ............................................................................................................... 6 Attachment 2 Directional Plan (6 pages) ..............................................................................._................:... 6 Attachment 3 Drilling Hazards Summary (1 page) ....................................:.......:...................;..................... 6 Attachment 4 Well Schematic (1 page) ...................................................................................:................... 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each' inell rnatst be identx~edUya unigare name des~graated lay tlae operator^ and a rcraique.4F'I nurnher• assigned lty the commission rdnder 20 AAC 25. fl4©(7a). hbr a tivell tiG~ilh multiple well branches, each branch rnrrs7 similurl} he ideratxfied t?y a unictue name andAPI number fiv adding a sarffrx to t{ze name designated f€rr thr=, x~ell by the oprratar ar~ad to the num~fieN assigned to tlae r~ell by the corrrrrrisszon. ThE well for which this Application is submitted will be designated as 1J-178 L1. - 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application jrrr is Perrnit to DrilX must be accornpunied by each of the fallowing items, except fhr un item alreucly on file wiih thc; corrunission and iderat~ied in the applicationa: (2) a plat ident~~ing tlae~pr-operiy a-ru1 the property's owners and shnwing {A)the coordinates !~f the proposed loceation of the weil at the surface, at the top of each oLjeetive.f~r»tatiort, anc7 at total depth, rzfereneed to governn~aet2tal section lines. {13} the coordinates of tlae proposed locations ~f the v~;ell at the szrr^fzce, rr~erenced to the state plane coordinate system far dais state as mairxtained try the National f,eodetic Survev in the National Oceanic. and Atmospheric, Adminirtratiart, ("C) the propasetl depth aj~the ;well at the top of r~ach o~ijeciive formation and at total depth; Location at Surface 1,647' FSL, 2,452' FEL, Secrion 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,459 Eastings: 558,760 Pad Elevation 81' AMSL Location-at Top of Productive Interval (West Sak "D" Sand 1,401' FSL, 1,627' FBL, Section 3, T10N, R10E ASP zone 4 NAD 27 Coordinates Measured Depth, RKB: 8,529 Northings: 5,939,901 Eastings: 554,355 Total Vertical Depth, RKB: 3,211 Total Vertical Depth, SS: 3,090. Location at Total De th 1,855' FNL, 1,507' FEL, Section 15, T10N,R10E ASP zone 4 NAD 27 Coordinates Measured Depth, RKB: 17,068 Northings: 5,931,367 Eastings: 554,550 Total Vertical Depth, RKB: 3,212 Total Vertical Depth, SS.• 3,091 and (D) other informuron required fiv 20 AAG 25.05~(b); Requirements of 20 AAC 25.050(b) If u well is to be intentiorrully c~levirzted, the application frar• u Permit to Drill (Form 10-4r)1} must (I) include a plat, drmvn to a suitable sr:ale, slaowirag the path of the proposed wellbore, inchrding all adjacent wellfi~rtswithin 204 feet of any portion of the proposed well; 1J-178 L1 PERMIT lT .Page 2 of 6 Printed: 7-Sep-07 ~~ ~~,, Ap~n for Permit to Drill, Well 1J-178 L1 Revision No.0 Saved: 7-Sep-07 Please see Attachment 1: Directional Plan ztrtd (2), for all wells tivithirx 200 feet of the proposed wellbore /_4,J list the names. of the operators of those wells, to the extent that those names. ar-e known or discoverable In public records, and show that , each roamed operator has been furnished a eop}~ of the application by certifted mail; or (f3) stoic that tlae applicant Is the only affected o~tmer. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requit-ements of 20 AAC 2S.OOS(c)(3) ~1n application for ca Perrttit to Drill must be accompanied by ecaeh of the following items, except for an item already on film with the corrunissir~n and ident fic:d in the appliccrtiora: (3) a diagram and description c f the blowout prei~entinn equipment (F30PE) as r~~egzaired by 2Q AAC: 2,1.1135, 2~ AQC2 5.036, or 20 rT4C 25.037; as applzcahle; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-178. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermostxam cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will-be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will betested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 9-5/8" OD. 4. Drilling Hazards Information Requi>^einents of 20 AAC 25.005 (c)(4) A.ra application_for a Per'rnit to Drill must be accompanied by each of7he following items, except for an-item already do jzletvith the cgrnmisszon and ident~ed in the application: (-t) inforrraation on drilling 6tazara's, znctuiling (A) the rnaxirnatm a'ownho7e pressure that nzay he encountered, criteria awed to determine it, and rrucrimum potenrial surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-178 L1 is 0.43 psi/ft, or 8.3 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,145 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the. deepest planned vertical depth of the West Sak D sand formation is 3,235'. The MPSP is: MPSP _ (3,235 ft)(0.43 - 0.11 psi/ft) =1,035 psi ~' (I3) data on potential gas zones; The well bore is not expected to penetrate any gas zones. .i nd (C) datrx concerning potential caustic of hole problems such as abnormally hea-pressured strata, lost circulatirin zones, cmd zones tlsat have a propensity for differential sticA~ng; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be aeaontpanied by each of the, following items, exceFtt for an item already on file. with the commission and identfed in the apFrdicatian: (5) a description of the prUCC:dztre for cgnductirag_for-rrxation integrity tests, as required under 20 ~?AC 25.03{}{f); No formation integrity test will be performed in the drilling of 1J-178 L1 1J-178 L1 PERMIT IT t ~ t ~ ~ 1. Page 3 of 6 Printed: 7-Sep-07 . App for Permit to Drill, Well 1J-178 L1 Revision No.O Saved: 7-Sep-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) .4n applicdtion for aPermit to l~rili rrzttst be accompanied &y each ot'the follotivirrg items, exceptf~r an item already on fzle 1vr.'iJa the commission atul ideratifled in the application: {6j a complete proposed caiitag and cemetzting program as required Iry 2~ AAC 25, f~30, and a descriptian of car y slotted brier, pre-perj'orated liner, or screen to be installed; Casing and Cementing Program See also Attachment 'i: Cement Snmmarv Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/7T~D OD (in) (in) (lb/ft) Grade Connection (ft) (ft) t) Cement Pro ram 20" 40" 62.5 H-40 Welded 80 40' / 40' 120' / 120' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,607 40' / 40' 3,647' / 2,200' 720 sx ArcticSet Lite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 6,046' 9-5/8" 12-1/4" 40 L-80 BTCM 9,095 40' / 40' 9,135"/ 3,288' MD / 2,708' TVD. Cemented w/ 560 sx DeepCRETE 5-1/2 slotte 8-1/2" B Sand Lateral {1J-178) 15.5 L-80 BTCM 8,443 8,629' / 3,227' 17,072' /3,281' Slotted-no cement ,__ 4-1/2 slotted 8-1/2" D Sand Lateral (1J-178 Ltd 11.6 L-80 BTCM 8,539 8529' / 3,211' 17,068' / 3,212' Slotted-no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applications for a Per~rnit to Drill must be accompanied by each aj the following items, except for an item already on jila tvitla the commission and identifzed in the application: (i j a diagram and descrilztion of the diverter s}~siern as rewired fry 2a AAC 2~. t13i, unless this re~uirenterat zs u~aiv~d by the corr~antission untlEr No diverter system will be used during operations on 1J-178 L1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Brill must fie accompaniec'1 by each of tlse following items, exceps,(or an itetra al'read'y on file with the cornrrsissdon and ideratlfled in the rxppliratton: (8) a drilling fluid program, itscluding a diagran¢ and description of tlse drilling fluid system, as required hy'1) _A,4G' 2.5.033: Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Densi (ppg) 8.4 - 8.6 Plastic Viscosti (lb/100 s 15-25 Yield Point (cP) 18-28 HTHP Fluid loss (ml/30 min 200psi & 150° <4.0 Oil /Water Ratio 80:20 Electrical Stability >600 n. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 1J-178 L1 PERMIT IT Page 4 of 6 Printed: 7-Se -07 P ~~~~.. Ap~n for Permit to Drill, Well 1J-178 L1 Revision No.0 Saved: 7-Sep-07 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) <4rt appl icatiora, for a Permit Per 1?rill tnttst be accompanied by each ot'tlae follmt~irag hems, except for• an item already on file with the commissrr~n and ident Pied isa the application; (Q) for an exploratory or•strafigraplzic test well cz tabulation setting out the depths of predicted abnormally oeo-pressured strata as required by 2D A~}C 2.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) ~n application f~r• a Permit to Drill must fie accomp~uzied by each of the following items, except for an iternaheiulyort file ~~ith the com~missiora arzd identified in the application: (I DJ b~r• an exploratory or stratigraphic test well,. a seismic refraction or reflection analysis as r•eclzzired by 20 A_AC 2~.061(a); Not applicable: Application is not for an exploratory or stratigraphic test we1L 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) Ara applicatiortfor a Permit to Drill must be accompanied by each of the following item's, except for an item already ort file witch the commission and identified irz the at•~plicafion: (11) for a tirell tlr-illed fr•arrt an offshore platform, mobile bottom-founded stt..rcture, jack-ttp rig, ru~ }lvatirig drillu~~; vessel, apt analvris of seabz=d conditior~zs as i^equirt:d b}~ 20 t1dC 25. D61(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) efn alrplicatzora for a Permit to Drill rnzrst be accorra~nartied by each Uf thefollowing ztcrras, except for an item already on ~Zle with ifae commission acrd identifi<d in the application: (12) evidence showing tTzat the requirements of 2D.4~3C 25.D2 ~ {Bondirzglhm~e been met; .Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13, Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) .4n application f rr a Permit to Drill roust be accompanied by each of the following items, except for' an iteraa already on,file with the commission and identified irz the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-178 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 8,529' MD / 3,211' TVD, the top of the "D" sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand. lateral at 17,068' MD / 3,212' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock. and POOH. 7. PU and RIH with the Baker seal bore diverter. 8. PU and run 4-1/2" slotted liner on Baker RAM hanger. 9. RIH and land RAM hanger in Baker seal bore diverter. 10. Release hanger running tool; POOH, laying down drill pipe as required. 11. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 1J-178 L1 PERMIT IT Page 5 of 6 Printed: 7-Sep-07 • Appl~ for Permit to Drill, Well 1 J-178 L1 Revision No.O Saved: 7-Sep-07 13. Freeze protect well with diesel by pumping into 4-1 /2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well postrig). 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. 16. Set gas lift valves in mandrels. Use ESP to clean up well. 17. Place well on production. ~ 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (e)(14} 11n applieution jrrr a Permit to L3rill m2rstcbe accc+mpanied Isy each ~~f"ilae €olttsv~ing %trtns; ezc;eptfor an iterrt alread}~ on frie with the conamisrion and identa aed in the ca iica~a~an: .f pp (14) a general descripiion of how the nperzatar plans to dispose of dr-i?ling rnud and cuttings and ca staterrrent of avhetker the o~aera~r intends to request authorization :,wider 2Q A.4C 2 ~. (~&0 for an ann~ttlar disposal operation in the tivell.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing-for injection down an approved disposal well, or stored; tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska.. ConocoPhillips.AIaska may in the future request authorization for the use of this well for'annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL 1J-178 L1 PERMIT IT Page 6 of 6 Printed: 7-Sep-07 • ConocoPhillips Alaska Plan: 1J-178 L1 (wp03) Sperry Drilling Services Proposal Report -Geographic 03 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 1J-178 L1 Local Coordinate Origin: entered on Well Plan 1J-178 (Q3 Phase 2) -Slot 1J Viewing Datum: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True ~ Unit System: API - US Survey Feet HALL1 URT®N Sperry Grilling ~®rvices ORIGINAL HALLIBURTON Sperry ~rilliing Services -1500 ~ -1 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-178 (Q3 Phase Wellbore: 1J-178 L1 Plan: 1J-178 L1 (wp03) WELL DETAILS: Plan I]-178 (Q3 Phase 2) NAD 1927 (NADCON CONUS) Alaska Zone 04 Gourd Level: 81 00 +N/-S +FJ-W Northing Fasting Latittude Longitude Slot 0.00 0.00 5945459.03 558760.45 70°15'4L73N 149°3l'29.97W IJ-178 FORMATION TOP DETAILS No. NDPath NDSS MDPath Formation 1 1536.20 1415.2 1747.83 Pfrost ANNOTATIONS ND MD Annotation 3211.30 8529.27 L1: 9 5/8"TOW @ 6529' MD, 3211' TVD: 1401' FSL, 1627' FEL - Sec03-T10N-R10E 3219.09 12512.57 L1: PA Boundary @ 12513' MD, 3219' TVD: 2560' FNL, 1499' FEL - Sec10-T10N-R10E 3212.40 17068.19 L1: BHL @ 17068' MD, 3212' TVD: 1855' FNL, 1507' FEL - Sec15-T10N-R10E 50D 0 c_ 1000 z n r 0 0 0 L 1500 a aI 2000 aJ ~ 2500 2 1638.99 1517.99 1953.78 T3 3 1932.85 1811.85 2827.11 K15 4 2139.62 2018.62 3462.22 T3+550 5 2810.88 2689.88 6546.57 Ugnu C 6 2874.57 2753.57 6854.92 Ugnu B 7 2936.02 2815.02 7152.42 Ugnu A 8 3078.91 2957.91 7841.46 K 13 9 3211.29 3090.29 8529.21 W Sak D CASING DETAILS No MD ND NDss Name Size 1 3647.68 2200.00 2079 13 3/8" 13-3/ 2 8529.29 3211.30 3090935/8"TOW 9-5/8 3 17068.19 3212.40 3091.4 41/2" 4-1/2 ~ ,~ i L1: 9 5/8" TOW @ 8529' MD, 3211' ND: 1401' FSL, 1627' FEL - Sec03-T10N-R10E ------- L1: PA Boundary ~ 12513' MD, 3219' ND: 2580' FNL, 1499' FEL - Sec10-T10N-R10E 0 a 3 J _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ ~ / _ .. .. _ _ _ -_ _ _ _ O . _ _ _ _ _ _ _ O - _ - _ _ _ ~~ _ _- - _ _ 0______ ~____________________~_________________ _____________________~ -_______~_-0__41/2"_ ~^____- ~ O i 0 _ _ _ _ _ _ _ _ _ _ _ _ _ ~~_ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ a0. _ _ _ _ _ _ _ _ _ _ p~ _ _ - _ _ _ ~ _ _ _ _ - _ ~ _ / C2 _ _ _ _ _ .~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ _ _ _ - _ _ _ _ __ _. _ _ _ _ _. 6i 3- _ _ _ _ - _ _ _ - _ _ _ _ _ -_ _ + _ - - i o o- o° o o ~ I M ' O 9 5/8" TOW n 3 r` 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 -10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 Vertical Section at 180.00° (1000 ft/in) ConocoPhillips Alaska HALLIBURTON ~oject: KuparukRiverUnit WELL DETAILS:P~76(03Phase®)~D1927(NADCONCONUS)AlaskaZone04 Site: Kuparuk 1J Pad Ground Level: 81.00 Spet~ry Qritling Servioels Well: Plan 1J-178 (Q3 Phase 2 +0. 0 +000 594545903 558760145 70°15'411t73N 149°312997W SJ--178 Wellbore: 1J-178 L1 Plan: 1J-178 L1 (wp03) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-178 (03 Phase 2) -Slot 1J-178, True North Vertical (rVD) Reference: Doyon 15 RKB (0 121.OOft (Doyon 15 (40+81)) Measuretl Depth Reference: Doyon 15 RKB (~ 121.OOfl (Doyon 15 (40+81)) Calculation Method: Minimum Curvature -7000 -7500 -8000 -8500 -9000 _ -9500 O N -10000 + t 7a -10500 C t ~ -11000 0 -11500 195° 190° 185° 1 I-178 'SIB D Top (OS'_ 07 - - - - - - - - - - - - - - - - - - - Ll 9 5/8" TOW @ 8529' MD, 3211' TVD: 7401' FSL, 1627 FEL - Sec03-TlON-RIDE 9 S/8" TOW I)-178 MB_D_TI (5l2?/07) - - - - I1-178 MB_D_T2 (5/22/07) - - - - I J-178 MB_D_T3 (5/22/07} - - - - 11-17,8 MB_D_T4 (5/Z?/07 f I1-178 MB_D_T5 (S/22/07r - - - - -- IJ-178 MB_D_T6 (5/22/07)- - - - - -~ ]79° 179° 179° 179° - - - - - - - - - LI: PA Boundary @ 12513' MD, 3219' TVD: 2580' FNL, 1499' FEL - Sec10-TION-RlOE 179° CASING DETAILS 179° No MD TVD TVDss Name Size 1 3647.68 2200.00 2079 13 3/6" 13-3/8 2 8529.29 3211.30 30~5A8" TOW 9-5/8 317068.19 3212.40 3091.4 4 1!2" 4-112 ANNOTATIONS TVD MD Annotation 3211.30 8529.27 L1: 9 5/B" TOW @ 8529' MD, 3211' TVD: 1401' FSL, 1827' FEL - Sec03-T10N-R10E 179° 3219.09 12512.57 L1: PA Boundary @ 12513' MD, 3219' TVD: 2580' FNL, 1499' FEL- Sec10-Ti0N-R10E 3212.40 17068.19 Lt: BHL ~ 17068' MD, 3212' TVD: 1855' FNL, 1507' FEL - Sec15-T10N-R10E -'""° I1-17S'~16_D_Toe (x__07)------3212 4 1 /2" ~ / ~i I -14500 1]-178 Ll (wp03) T M Azimuths to True North Magnetic North: 23.24° -15000 Magnetic Field Strength:57614.7nT Dip Angle: 80.79° Date: 8/2/2007 Model: BGGM2007 -15500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -;000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 West(-)/East(+) (1250 f4/in) ~~ ConocoPhillips ConocoPhillips Alaska Database: Sperry EDM .11 Local Co-ordinate Reference: 'Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: 'Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-178 L1 Design: 1J-178 L1 (wp03) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point M a p Zone: Alaska Zone 04 Using geodetic scale factor - - ~ Well Plan 1 J 1; 8 (Q3 Phase 2) -Slot 1 J-778 Well Position +N/-S 0.00 ft Northing: 5,945,459.03 ft Latitude: 70° 15' 41.730" N +E/-W 0.00 ft Easting: 558,760.45ft Longitude: 149° 31' 29.970" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-i78 L1 Magnetics Model Name...: Sample Date Declination Dip Angle Field Strength BGGM2007 8/2/2007 23.24 80.79 57,615 Design 1J-1i8 L1 (wp03) Audit Notes: Version: Phase: PLAN Tie On Depth: 8,529.27 Vertical Section: Depth From (TVD) +N!-5 +EI-W Direction lftl (ft) (ft) (o) 40.00 0.00 0.00 180.00 Halliburton Company Compass Proposal Report -Geographic HALLIBURTON Sperry Drilling S®rvicea 8/3/2007 5:02:01 PM Page 2 of 8 COMPASS 2003.11 Build 48 ~~~ Halliburton Company HALiLIBURTGIN Conoco~iilips Compass Proposal Report -Geographic Alaska Sp®rry Drilling S®rviaea Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: ~Cuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: ~Cuparuk 1J Pad North Reference: True Well: 'Ian 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-178 L1 I Design: 1J-178 L1 (wp03) Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth TVD TVDSS +N!-S +E/-W Rate Rate Rate TFO (ft) (~) (~) (ft) (ft) (ft) (ft) (°1100ft) (°I100ft) (°7100ft) (°) 8,529.27 80A0 180.00 3,211.30 3,090.30 -5,524.02 -4,449.12 0.00 0.00 OAO U.00 8,545.77 82.24 180.00 3,213.85 3,092.85 -5,540.32 -4,449.12 13.60 13.60 0.00 0.00 8,575.77 82.24 180.00 3,217.90 3,096.90 -5,570.05 -4,449.12 0.00 0.00 0.00 0.00 8,888.97 91.55 178.67 3,234.84 3,113.84 -5,882.42 -4,445.46 3.00 2.97 -0.43 -8.19 9,067.68 91.55 178.67 3,230.02 3,109.02 -6,061.01 -4,441.31 0.00 0.00 0.00 0.00 9,131.11 89.70 179.13 3,229.33 3,108.33 -6,124.42 -4,440.09 3.00 -2.91 0.73 165.90 9,831.11 89.70 179.13 3,233.00 3,112.00 -6,824.33 -4,429.46 0.00 0.00 0.00 0.00 9,911.63 90.51 179.14 3,232.86 3,111.86 -6,904.85 -4,428.24 1.00 1.00 0.01 0.44 10,530.39 90.51 179.14 3,227.40 3,106.40 -7,523.50 -4,418.91 0.00 0.00 0.00 0.00 10,607.79 89.73 179.15 3,227.24 3,106.24 -7,600.90 -4,417.75 1.00 -1.00 0.02 179.04 11,430.71 89.73 179.15 3,231.10 3,110.10 -8,423.72 -4,405.54 0.00 0.00 0.00 0.00 11,525.37 90.68 179.13 3,230.76 3,109.76 -8,518.36 -4,404.12 1.00 1.00 -0.02 -0.96 12,731.27 90.68 ~ 179.13 3,216.50 3,095.50 -9,724.04 =4,385.88 0.00 0.00 0.00 ~ 0.00 12,759.12 90.96 179.14 3,216.10 3,095.10 -9,751.89 -4,385.46 1.00 1.00 0.01 0.44 14,431.11 90.96 179.14 3,188.20 3,067.20 -11,423.45 -4,360.24 0.00 0.00 0.00 .0.00 14,614.98 89.12 179.14 3,188.08 3,067.08 -11,607.30 -4,357.47 1.00 -1.00 0.00 179.85 15,531.62 89.12 179.14 3,202.20 3,081.20 -12,523.72 -4,343.72 0.00 0.00 0.00 0.00 15,582.69 89.63 179.14 3,202.76 3,081.76 -12,574.78 -4,342.95 1.00 1.00 0.00 0.16 17,068.20 89.63 179.14 3,212.40 3,091.40 -14,060.10 -4,320.70 0.00 0.00 0.00 0.00 8/3/2007 5:02:01PM Page 3 of 8 COMPASS 2003.11 Build 48 ORIGINAL • •'~' Halliburton Company HALLiBURTON ConocoPhilli~ps Compass Proposal Report -Geographic gperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True WeII: Flan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-178 L1 ~ Design: 1J-178 L1 (wp03) Planned Survey 1J-172 L1 ~wp03) ~~~ Map Map MD Inc! Azimuth TVD (ft) TVDSS +Ni_S +E/_W Northing Easting DLSEV Vert Section (ft) (°) (') (ft) Ift) lft) (ftl (ft) (°/100ft) fftl 8,529.27 80.00 180.00 3,211.30 3090.30 -5,524.02 -4,449.12 5,939,901.00 554,355.00 0.00 5,524.02 L7: 9 518" TOW @ 8529' MD, 3211 ' ND: 1401' FSL, 1627' F EL - Sec03-T10N-R10E - W Sak D - 9 5/8" TOW -1J-178 MB_D Top (05/22!07) 8,545.77 82.24 180.00 3,213.85 3092.85 -5,540.32 -4,449.12 5,939,884.70 554,355.13 13.60 5,540.32 8,575.77 82.24 180.00 3,217.90 3096.90 -5,570.05 -4,449.12 5,939,854.97 554,355.36 0.00 5,570.05 8,600.00 82.96 179.90 3,221.01 3100.01 -5,594.07 -4,449.09 5,939,830.95 554,355.57 3.00 5,594.07 8,647.98 84.39 179.69 3,226.30 3105.30 -5,641.76 -4,448.92 5,939,783.27 554,356.11 3.00 5,641.76 1J-178 MB_ D_Heel (05/22/07) 8,700.00 85.93 179.47 3,230.69 3109.69 -5,693.59 -4,448.54 5,939,731.45 554,356.90 3.00 5,693.59 8,800.00 88.90 179.04 3,235.19 3114.19 -5,793.47 -4,447.24 5,939,631.59 554,358.98 3.00 5,793.47 8,888.97 91.55 178.67 3,234.84 3113.84 -5,882.42 -4,445.46 5,939,542.67 554,361.45 3.00 5,882.42 8,900.00 91.55 178.67 3,234.55 3113.55 -5,893.44 -4,445.21 5,939,531.65 554,361.79 0.00 5,893.44 9,000.00 91.55 178.67 3,231.85 3110.85 -5,993.37 -4,442.88 5,939,431.75 554,364.90 0.00 5,993.37 9,067.68 91.55 178.67 3,230.02 3109.02 -6,061.01 -4,441.31 5,939,364.13 554,367.00 0.00 6,061.01 9,100.00 90.61 178.90 3,229.42 3108.42 -6,093.32, -4,440.62 5,939,331.84 554,367.93 3.00 6,093.32 9,131.11 89.70 179.13 3,229.33 3108.33 -6,124.42 -4,440.09 5,939,300.74 554,368.71 3.00 6,124.42 9,200.00 89.70 179.13 3,229.70 3108.70 -6,193.30 -4,439.04 5,939,231.87 554,370.29 0.00 6,193.30 9,300.00 89.70 179.13 3,230.22 3109.22 -6,293.29 -4,437.52 5,939,131.91 554,372.59 0.00 6,293.29 9,400.00 89.70 179.13 3,230.74 3109.74 -6,393.28 -4,436.00 5,939,031.95 554,374.89 0.00 6,393.28 9,500.00 89.70 179.13 3,231.27 3110.27 -6,493.26 -4,434.49 5,938,931.99 554,377.19 0.00 6,493.26 9,600.00 89.70 179.13 3,231.79 3110.79 -6,593.25 -4,432.97 5,938,832.02 554,379.49 0.00 6,593.25 9,700.00 89.70 179.13 3,232.31 3111.31 -6,693.24 -4,431.45 5,938,732.06 554,381.79 0.00 6,693.24 9,800.00 89.70 179.13 3,232.84 3111.84 -6,793.23 -4,429.93 5,938,632.10 554,384.08 0.00 6,793.23 9,831.11 89.70 179.13 3,233.00 3112.00 -6,824.33 -4,429.46 5,938,601.00 554,384.80 0.00 6,824.33 1J-178 MB_D_T1 (5/2 2/07) 9,900.00 90.39 179.14 3,232.95 3111.95 -6,893.21 -4,428.42 5,938,532.14 554,386.38 1.00 6,893.21 9,911.63 90.51 179.14 3,232.86 3111.86 -6,904.85 -4,428.24 5,938,520.51 554,386.65 1.00 6,904.85 10,000.00 90.51 179.14 3,232.08 3111.08 -6,993.20 -4,426.91 5,938,432.18 554,388.67 0.00 6,993.20 10,100.00 90.51 179.14 3,231.19 3110.19 -7,093.18 -4,425.40 5,938,332.21 554,390.96 0.00 7,093.18 10,200.00 90.51 179.14 3,230.31 3109.31 -7,193.17 -4,423.89 5,938,232.25 554,393.24 0.00 7,193.17 10,300.00 90.51 179.14 3,229.43 3108.43 -7,293.15 -4,422.39 5,938,132.29 554,395.53 0.00 7,293.15 10,400.00 90.51 179.14 3,228.55 3107.55 -7,393.14 -4,420.88 5,938,032.33 554,397.82 0.00 7,393.14 10,500.00 90.51 179.14 3,227.67 3106.67 -7,493.12 -4,419.37 5,937,932.37 554,400.10 0.00 7,493.12 10,530.39 90.51 179.14 3,227.40 3106.40 -7,523.50 -4,418.91 5,937,902.00 554,400.80 0.00 7,523.50 1J-178 MB_D_T2 (5!22/07) 10,600.00 89.81 179.15 3,227.21 3106.21 -7,593.11 -4,417.87 5,937,832.41 554,402.39 1.00 7,593.11 10,607.79 89.73 179.15 3,227.24 3106.24 -7,600.90 -4,417.75 5,937,824.62 554,402.56 1.00 7,600.90 10,700.00 89.73 179.15 3,227.67 3106.67 -7,693.10 -4,416.39 5,937,732.45 554,404.65 0.00 7,693.10 10,800.00 89.73 179.15 3,228.14 3107.14 -7,793.08 -4,414.90 5,937,632.48 554,406.92 0.00 7,793.08 10,900.00 89.73 179.15 3,228.61 3107.61 -7,893.07 -4,413.42 5,937,532.52 554,409.18 0.00 7,893.07 11,000.00 89.73 179.15 3,229.08 3108.08 -7,993.06 -4,411.93 5,937,432.56 554,411.44 0.00 7,993.06 11,100.00 89.73 179.15 3,229.55 3108.55 -8,093.05 -4,410.45 5,937,332.59 554,413.71 0.00 8,093.05 11,200.00 89.73 179.15 3,230.02 3109.02 -8,193.04 -4,408.96 5,937,232.63 554,415.97 0.00 8,193.04 11,300.00 89.73 179.15 3,230.49 3109.49 -8,293.02 -4,407.48 5,937,132.67 554,418.24 0.00 8,293.02 11,400.00 89.73 179.15 3,230.96 3109.96 -8,393.01 -4,405.99 5,937,032.70 554,420.50 0.00 8,393.01 11,430.71 89.73 179.15 3,231.10 3110.10 -8,423.72 -4,405.54 5,937,002.00 554,421.20 0.00 8,423.72 1J-178 MB_D_T3 (5122/07) 8/3/2007 5:02:01PM Page 4 of 8 COMPASS 2003.11 Build 48 ORIGINAL CoinocoPhillips Alaska Halliburton Company Compass Proposal Report -Geographic • HALLIBURTON Sperry Drilling Services Database: Sperry EDM .11 Local Co-ordinate Reference: ---- l^Jell Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: ',linimum Curvature Wellbore: 1J-178 L1 Design: 1J-178 L1 (wp03) Planned Survey 1J-178 L1 nvp03) Map Map MD Incl Azimuth ND (ft) NDSS +N/-S +E/_yy Northing Easting DLSEV Vert Section (ftl (°) (°) (ft1 (ft) (ft) (ftl (ft) (°I100ft) (ft) 11,500.00 90.42 179.14 3,231.01 3110.01 -8,493.00 -4,404.50 5,936,932.74 554,422.78 1.00 8,493.00 11,525.37 90.68 179.13 3,230.76 3109.76 -8,518.36 -4,404.12 5,936,907.38 554,423.36 1.00 8,518.36 11,600.00 90.68 179.13 3,229.88 3108.88 -8,592.98 -4,402.99 5,936,832.78 554,425.07 0.00 8,592.98 11,700.00 90.68 179.13 3,228.70 3107.70 -8,692.96 -4,401.48 5,936,732.82 554,427.36 0.00 8,692.96 11,800.00 90.68 179.13 3,227.51 3106.51 -8,792.94 -4,399.96 5,936,632.87 554,429.65 0.00 8,792.94 11,900.00 90.68 179.13 3,226.33 3105.33 -8,892.93 -4,398.45 5,936,532.91 554,431.94 0.00 8,892.93 12,000.00 90.68 179.13 3,225.15 3104.15 -8,992.91 -4,396.94 5,936,432.95 554,434.24 0.00 8,992.91 12,100.00 90.68 179.13 3,223.97 3102.97 -9,092.89 -4,395.43 5,936,332.99 554,436.53 0.00 9,092.89 12,200.00 90.68 179.13 3,222.78 3101.78 -9,192.87 -4,393.91 5,936,233.04 554,438.82 0.00 9,192.87 12,300.00 90.68 179.13 3,221.60 3100.60 -9,292.85 -4,392.40 5,936,133.08 554,441.11 0.00 9,292.85 12,400.00 90.68 179.13 3,220.42 3099:42 -9,392.83 -4,390.89 5,936,033.12 554,443.41 0.00 9,392.83 12,500.00 90.68 179.13 3,219.24 3098.24 -9,492.82 -4,389.38 5,935,933.17 554,445.70 0.00 9,492.82 12,512.57 90.68 179.13 3,219.09 3098.09 -9,505.38 -4,389.19 5,935,920.60 554,445.99 0.00 9,505.38 L1: PA Boundary @ 1 2513' MD, 3 219' TVD: 2580' FNL, 1499' FEL - Sec10-T10N-R10E 12,600.00 90.68 ~ 179.13 3,218.05 3097.05 -9,592.80 -4,387.86 5,935,833.21 554,447.99 0.00 9,592.80 12,700.00 90.68 179.13 3,216.87 3095.87 -9,692.78 -4,386.35 5,935,733.25 554,450.28 0.00 9,692.78 12,731.27 90.68 179.13 3,216.50 3095.50 -9,724.04 -4,385.88 5,935,702.00 554,451.00 0.00 9,724.04 1J-178 MB_D_T4 (5/2 2/07) 12,759.12 90.96 179.14 3,216.10 3095:10 -9,751.89 -4,385.46 5,935,674.16 554,451.64 1.00 9,751.89 12,800.00 90.96 179.14 3,215.42 3094.42 -9,792.76 -4,384.84 5,935,633.30 554,452.57 0.00 9,792.76 12,900.00 90.96 179.14 3,213.75 3092.75 -9,892.73 -4,383.33 5,935,533.35 554,454.86 0.00 9,892.73 13,000.00 90.96 179.14 3,212.08 3091.08 -9,992.71 -4,381.82 5,935,433.40 554,457.15 0.00 9,992.71 13,100.00 90.96 179.14 3,210.41 3089.41 -10,092.68 -4,380.32 5,935,333.45 554,459.44 0.00 10,092.68 13,200.00 90.96 179.14 3,208.75 3087.75 -10,192.66 -4,378.81 5,935,233.50 554,461.73 0.00 10,192.66 13,300.00 90.96 179.14 3,207.08 3086.08 -10,292.63 -4,377.30 5,935,133.55 554,464.02 0.00 10,292.63 13,400.00 90.96 179.14 3,205.41 3084.41 -10,392.61 -4,375.79 5,935,033.60 554,466.30 0.00 10,392.61 13,500.00 90.96 179.14 3,203.74 3082.74 -10,492.58 -4,374.28 5,934,933.65 554,468.59 0.00 10,492.58 13,600.00 90.96 179.14 3,202.07 3081.07 -10,592.55 -4,372.77 5,934,833.70 554,470.88 0.00 10,592.55 13,700.00 90.96 179.14 3,200.40 3079.40 -10,692.53 -4,371.26 5,934,733.75 554,473.17 0.00 10,692.53 13,800.00 90.96 179.14 3,198.73 3077.73 -10,792.50 -4,369.76 5,934,633.80 554,475.46 0.00 10,792.50 13,900.00 90.96 179.14 3,197.06 3076.06 -10,892.48 -4,368.25 5,934,533.85 554,477.75 0.00 10,892.48 14,000.00 90.96 179.14 3,195.39 3074.39 -10,992.45 -4,366.74 5,934,433.90 554,480.03 0.00 10,992.45 14,100.00 90.96 179.14 3,193.73 3072.73 -11,092.43 -4,365.23 5,934,333.95 554,482.32 0.00 11,092.43 14,200.00 90.96 179.14 3,192.06 3071.06 -11,192.40 -4,363.72 5,934,233.99 554,484.61 0.00 11,192.40 14,300.00 90.96 179.14 3,190.39 3069.39 -11,292.38 -4,362.21 5,934,134.04 554,486.90 0.00 11,292.38 14,400.00 90.96 179.14 3,188.72 3067.72 -11,392.35 -4,360.70- 5,934,034.09 554,489.19 0.00 11,392.35 14,431.11 90.96 179.14 3,188.20 3067.20 -11,423.45 -4,360.24 5,934,003.00 554,489.90 0.00 11,423.45 1J-178 MB_D_TS (5/22/07) 14,500.00 90.27 179.14 3,187.46 3066.46 -11,492.33 -4,359.20 5,933,934.14 554,491.48 1.00 11,492.33 14,600.00 89.27 179.14 3,187.87 3066.87 -11,592.32 -4,357.69 5,933,834.18 554,493.76 1.00 11,592.32 14,614.98 89.12 179.14 3,188.08 3067.08 -11,607.30 -4,357.47 5,933,819.20 554,494.10 1.00 11,607.30 14,700.00 89.12 179.14 3,189.39 3068.39 -11,692.30 -4,356.19 5,933,734.22 554,496.04 0.00 11,692.30 14,800.00 89.12 179.14 3,190.93 3069.93 -11,792.27 -4,354.69 5,933,634.27 554,498.32 0.00 11,792.27 14,900.00 89.12 179.14 3,192.47 3071.47 -11,892.25 -4,353.19 5,933,534.32 554,500.60 0.00 11,892.25 15,000.00 89.12 179.14 3,194.01 3073.01 -11,992.23 -4,351.69 5,933,434.37 554,502.88 0.00 11,992.23 15,100.00 89.12 179.14 3,195.55 3074.55 -12,092.20 -4,350.19 5,933,334.41 554,505.16 0.00 12,092.20 15,200.00 89.12 179.14 3,197.09 3076.09 -12,192.18 -4,348.69 5,933,234.46 554,507.44 0.00 12,192.18 8/3/2007 5:02:01PM Page 5 of 8 COMPASS 2003.11 Build 48 ORIGINAL • ~•-'" Halliburton Company HALLIBURTON COt1000PI't1~~~5 Compass Proposal Report -Geographic Sperry Drilling Services Database: wN~ - .Sperry EDM .11 Local Co-ordinate Reference; Well Plan 1J-178 (Q3 Phase 2) - Stot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: 'Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Welibore: 1J-178 L1 Design: 1 J-178 L1 (wp03) Planned Survey ~ J-178 L1 i~ap031 Map Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E(_~1/ Northing Easting pLSEV Vert Section (ft) (°) (~) (ft) lft) lft) (ft) (ft) (°/100ft) Iftl 15,300.00 89.12 179.14 3,198.63 3077.63 -12,292.16 -4,347.19 5,933,134.51 554,509.72 0.00 12,292.16 15,400.00 89.12 179.14 3,200.17 3079.17 -12,392.13 -4,345.69 5,933,034.56 554,512.00 0.00 12,392.13 15,500.00 89.12 179.14 3,201.71 3080.71 -12,492.11 -4,344.19 5,932,934.60 554,514.28 0.00 12,492.11 15,531.62 89.12 179.14 3,202.20 3081.20 -12,523.72 -4,343.72 5,932,903.00 554,515.00 0.00 12,523.72 1J-178 MB_ D_T6 (5122107) 15,582.69 89.63 179.14 3,202.76 3081.76 -12,574.78 -4,342.95 5,932,851.95 554,516.16 1.00 12,574.78 15,600.00 89.63 179.14 3,202.87 3081.87 -12,592.09 -4,342.69 5,932,834.65 554,516.56 0.00 12,592.09 15,700.00 89.63 179.14 3,203.52 3082.52 -12,692.08 -4,341.20 5,932,734.68 554,518.84 0.00 12,692.08 15,800.00 89.63 179.14 3,204.17 3083.17 -12,792.07 -4,339.70 5,932,634.72 554,521.11 0.00 12,792.07 15,900.00 89.63 179.14 3,204.82 3083.82 -12,892.05 -4,338.20 5,932,534.76 554,523.39 0.00 12,892.05 16,000.00 89.63 179.14 3,205.47 3084.47 -12,992.04 -4,336.70 5,932,434.80 554,525.67 0.00 12,992.04 16,100.00 89.63 179.14 3,206.12 3085.12 -13,092.03 -4,335.20 5,932,334.83 554,527.95 0.00 13,092.03 16,200.00 89.63 179.14 3,206.77 3085.77 -13,192.01 -4,333.71 5,932,234.87 554,530.22 0.00 13,192.01 16,300.00 89.63 179.14 3,207.41 3086.41 -13,292.00 -4,332.21 5,932,134.91 554,532.50 0.00 13,292.00 16,400.00 89.63 179.14 3,208.06 3087.06 -13,391.99 -4,330.71 5,932,034.95 554,534.78 0.00 13,391.99 16,500.00 89.63 179.14 3,208.71 3087.71 -13,491.97 -4,329.21 5,931,934.99 554,537.06 0.00 13,491.97 16,600.00 89.63 179.14 3,209.36 3088.36 -13,591.96 -4,327.72 5,931,835.02 554,539.34 0.00 13,591.96 16,700.00 89.63 179.14 3,210.01 3089.01 -13,691.95 -4,326.22 5,931,735.06 554,541.61 ' 0.00 13,691.95 16,800.00 89.63 179.14 3,210.66 3089.66 -13,791.93 -4,324.72 5,931,635.10 554,543.89 0.00 13,791.93 16,900.00 89.63 179.14 3,211.31 3090.31 -13,891.92 -4,323.22 5,931,535.14 554,546.17 0.00 13,891.92 17,000.00 89.63 179.14 3,211.96 3090.96 -13,991.91 -4,321.72 5,931,435.17 554,548.45 0.00 13,991.91 17,068.20 89.63 179.14 .3,212.40 3091.40 -14,060.10 -4,320.70 5,931,367.00 554,550.00. 0.00 14,060.10 L1: BHL @ 17068' MD, 3212' TVD: 1855' FNL, 1507' FEL - Sec15-T10N-R10E - 5 1/2" -1J-178 MB_D_Toe (5/22/07) , 8/3/2007 5:02:01PM Page 6 of 8 COMPASS 2003.11 Build 48 ConocoPhillips Alaska Halliburton Company HALLIBURTON Compass Proposal Report -Geographic Sp®rry Driiiing S®rvicea Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc: ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: P.1 nimum Curvature Wellbore: IJ-178 L1 Design: IJ-178 L1 (wp03) Geologic Targets 1J-178 L1 __ ND TVDSS Target Name +N!-S +E!-W Northing Easting (ft) (ft) -Shape ft ft (ft) (ft) 3,226.30 1J-178 MB_D_Heel (05122/07) -5,524.01 -4,449.12 5,939,901.00 554,355.00 - Polygon Point 1 0.00 0.00 5,939,901.00 554,355.00 Point2 -1,300.32 19.66 5,938,601.00 554,384.80 3,212.40 1J-178 MB_D_Toe (5/22/07) -14,060.10 -4,320.70 5,931,367.00 554,550.00 - Point 3,202.20 1J-178 MB_D_T6 (5/22/07) -12,523.72 -4,343.72 5,932,903.00 554,515.00 - Polygon Point 1 0.00 0.00 5,932,903.00 554,515.00 Point 2 -1,536.37 23.02 5,931,367.00 554,550.00 3,211.30 1J-178 MB_D_Top (05122/07) -5,524.01 -4,449.12 5,939,901.00 554,355.00 - Point 3,233.00 1J-178 MB_D_T1 (5/22/07) -6,824.33 -4,429.46 5,938,601.00 554,384.80 - Polygon Point 1 0.00 0.00 5,938,601.00 554,384.80 Point 2 -699.17 10.55 5,937,902.00 554,400.80 3,216.50 1J-178 MB_D_T4 (5/22/07) -9,724.04 -4,385.88 5,935,702.00 554,451.00 - Polygon Point 1 0.00 .0.00 5,935,702.00 554,451.00 Point 2 -1,699.42 25.64 5,934,003.00 554,489.90 3;188.20 1J-178 MB_D_T5 (5/22/07) -11,423.45 -4,360.24 5,934,003.00 554,489.90 - Polygon Point 1 0.00 0.00 5,934,003.00 554,489.90 Point 2 -1,100.27 16.52 5,932,903.00 554,515.00 3,231.10 1J-178 MB_D_T3 (5/22/07) -8,423.72 -4,405.54 5,937,002.00 554,421.20 - Polygon Point 1 0.00 0.00 5,937,002.00 554,421.20 Point 2 -1,300.32 19.66 5,935,702.00 554,451.00 3,227.40 1J-178 MB_D_T2 (5/22/07) -7,523.50 -4,418.91 5,937,902.00 554,400.80 - Polygon Point 1 0.00 0.00 5,937,902.00 554,400.80 Point 2 -900.22 13.38 5,937,002.00 554,421.20 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 3,647.68 2,200.00 13-318 16 8,529.29 3,211.30 9-518 12-1/4 17,068.19 3,212.40 5-1/2 8-1/2 8/3/2007 5:02:01PM Page 7 of 8 COMPASS 2003.11 Build 48 ~ ~ ~AL Y Halliburton Company HALLIBURTON ConocoPh~~A p~ Com ass Pro osal Re ort - Geo ra hic p P P 9 P Sp®rry Dritiing Service: Database: ~o x,u~_~ Sperry EDM .11 ~ _~ Locai Co-0rdlnate Reference: __ Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: :True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-178 L1 Design: 1J-178 L1 (wp03) ~ Prognosed Formation Intersection Points Measured Depth Inclination Azimuth TVD 1ft) (°) (°l (ft) 1,747.83 55.91 222.00 1,536.20 1,953.78 64.15 222.00 1,638.99 2,827.11 71.00 222.00 1,932.85 3,462.22 71.00 222.00 2,139.62 6,546.57 78.08 222.26 2,810.88 6,854.92 78.08 222.26 2,874.57 7,152.42 78.08 222.26 2,936.02 7,841.46 78.13 204.45 3,078.91 8,529.21 80.00 180.00 3,211.29 TVDSS +N/-E (ft) +E/-W (ft) Iftl -469.83 -423.04 -602.31 -542.32 -1,213.21 -1,092.38 -1,659.47 -1,494.19 -3,887.00 -3,516.57 -4,110.29 -3,719.47 -4,325.73 -3,915.22 -4,869.31 -4,307.72 -5,523.96 -4,449.12 Name Pfrost T3 K15 T3+550 Ugnu C Ugnu B Ugnu A K13 W Sak D Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W Comment (ft) (ft) (ft) (ft) 8,529.27 3,211.30 -5,524.02 -4,449.12 L1: 9 5/8" TOW @ 8529' MD, 3211' ND: 1401' FSL, 1627' FEL - Sec03-T10~ 12,512.57 3,219.09 -9,505.38 -4,389.19 L1: PA Boundary @ 12513' MD, 3219' TVD: 2580' FNL, 1499' FEL - Sec10-T1 17,068.19 3,212.40 -14,060.09 -4,320.70 L1: BHL @ 17068' MD, 3212' TVD: 1855' FNL, 1507' FEL - Sec15-T10N-R10E 8/3/2007 5:02:01PM Page 8 of 8 COMPASS 2003.11 Build 48 1i,~~~tYe" l • ConocoPhillips Alaska Plan: 1 J-178 L1 (wp03) Sperry Drilling Services Anticollision Summary 03 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-178 (Q3 Phase 2J 1J-178 L1 Local Coordinate Origin: entered on Well Plan 1J-178 (03 Phase 2) -Slot 1J Viewing Oatum: Doyon 15 RKB Q 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet IHAL.Lt13UIF~T® Sperry Drilling Servic®~ ORIGINAL SURVEY PKOGRAM ~ ConocoPhillips Alaska, Inc. I I ANTI-COLLISION SETTINGS Dute: 2007-OS23700:00:00 Validated: Yes Version: Depth FromDepth To Survey/Plan Tool 40.00 1000.00 CB-GYRO-SS 1000.00 8529.27 111WD+1FR-AK-CA~SC 8529.2717067.93 IJ-178 Ll (wp03) b1WD+IFR-AK-CA~SC 0 Interpolation Method: MD Interval: 50Stations Depth Range From: 8529.27 To 17068.1992919622 Maximum Range:1902.81952919702 Reference: Plan: 1J-178 L1 (wp03) 90 270 180 Travelling Cylinder Azimuth (TFO+AZI) 1°] vs Centre to Centre Separafion 130 ftfinl 180 Travelling Cylinder Azimuth (TFO+AZI) (°~ vs Centre to Centre Separation [200 ft/ink NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-178 (03 Phase 2) I Ground Level: 81.00 +NI-S +EI-W Northing Fasting Latittude Longitude Slot 0.00 0.00 5945459.03 558760.45 70°15'41.73N 149°31'29.97W 1J-178 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Plan 1J-178 (03 Phase 2) -Slot 1J-178, True North Vertical (ND) Reference: Doyon 15 RKB ~ 121.OOtt (Doyon 15 (40+81)) Section (VS) Reference: Slot - 1J-178(O.OON, O.OOE) Measured Depth Reference: Doyon 15 RKB ~ 121.OOtt (Doyon 15 (40+81)) Calculation Method: Minimum Curvature Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based From Colour To MD SECTION DETAILS 5.4 MD Im Aa TvD +ws .E1-w Dip Tr.4• vs.4 T419•I 1 %29.n mro 180m 3111]0 -ssz4.n 4a49.1z om 2 8545.]7 81.10 180.00 )213.85 -5510.32 4449.12 1360 3 fisn.n az.ze 1mao 3r ].% -ss]o.os 4449.1z a.ao 9.90 551a at 0.00 5510]3 o.oo ss7oos 1 80889] 91.55 1]8.8] J234.M 5882.42 44454fi 300 6 906]88 9155 1]0.6] 3130.01 -006101 Jd11.31 800 -0.19 608243 0.00 fi061.01 6 9131.11 89.]0 1]9.13 3119.33 b12d42 4M0.09 300 ] %31.11 88.]0 1]9.13 3233.00 -602033 -0429.46 000 8 9911 63 %.51 1 ]9.14 3232 % E901.85 4428.24 1.00 16590 6114A1 °00 6814.33 1J-i]B MB D_Tt (531/07) O M 8901 B6 9 10530.)9 %.51 179.14 322]40 -]52350 441881 0.00 101060].]9 89.)3 1M.15 J32T1d -]600.90 441].]5 1.00 0.00 ]61350 1}1]8 MB D_T3 (Sr1Z07f 1]904 7600.80 1111130.]1 89.13 1M.15 3231.10 -0423.72 4405.54 0.00 1111515.3] %6B 1]9.13 3130.)6 8518% 4g4.i2 100 13 12731.17 9060 1]9.13 3116.50 -9]2404 4365.88 000 0.00 8423.]2 1J-118 MB_D T3 (5YV/OT) -0.% 851038 000 971401 1}1]8 MB D_T4 (vzvo~n id 11759.12 %.% 179.14 3216.10 -9]51 ~ 4385.4fi 1.00 161H31.11 90.% 1]9.14 318820-11423.45 -0360.14 000 014 9]5189 0001141)45 1}1]8 MB_D_TS (521/07) 1611614% 89.12 1>9.14 3108.08-1160].30 435)4] 100 1T 1553162 89.11 1]9.14 320220-12523]2 4343.)2 000 1]9651180]30 000 1251)]2 1}t]8 MB_D_TB (5'21107) 10 15582 69 89.63 119.11 3202 76 -125]4 ]8 434295 100 191]a6e.za 8863 1]x.14 3zlzeo-1ao6o.10431°]0 o.ao 0.16 11514 ]8 0.9011%0.10 1}t]e Me DT°•(5zvo]1 Halliburton Company i Anticollision Report Company: ConocoPhillips Alaska lnc. Date: 8/3/2007 Time: 19:30:40 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-178, True North Keference ~~'cll: Plan 1J-178 Vertical (T~'D) Reference: Doyon 15 (40+81) 121.0 Reference ~~'cllpath: Plan: 1J-178 L1 llb: Oracle GLOBAL SCAN APPLIED: All wellpath s within 200'+ 100/1000 of reference Reference: Plan: 1J-178 L1 (wp03) & NOT PLANNED Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8528.99 to 17067.93 ft Scan Method: Trav Cylinder North Maximum Radius: 1902.79 ft Error Surface: Ellipse + Casing Casing Points MD T~'D Diameter Hole Size Name ft ft in in 3831.60 2250.00 13.375 16.000 13 3/8" 8529.01 3211.30 9.625 12.250 9 5/8" TOW 17067.92 3212.40 5.500 8.500 5 1 /2" Plan: 1J-178 L1 (wp03) Date Composed: 5/22/2007 Version: 2 Principal: Yes Tied-to: From: Definitive Path Summary <_____________ ________ Offset Wellpath ------- -----------> Reference Offset Ctr-Ctr No-Go Allowable Site Nell ~i'ellpath i~ID SID Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-158 1J-158 V6 Out of range Kuparuk 1J Pad 1J-158 1J-158L1 V3 Out of range Kuparuk 1J Pad 1J-180 1J-180 V4 16386.90 15225.00 1384.80 344.75 1040.05 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1 V3 15727.08 14575.00 1177.49 328.58 848.92 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1PB1 V1 15727.08 14575.00 1177.49 328.79 848.70 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V3 Plan: 8549.99 8550.00 0.50 0.00 0.50 Pass: No Errors 2OGRA~ 1J-178Li~rillin Hazard~Summa (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure ~ mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip. sheets , um in out, backreamin F-(~ ~ i ~ r 1J-178L1 Drilling Hazards Summary ~•/ t ` ~•~s i 9/7/2007 9:40:00 AM O (~,~~ V ~ Wellhead I Tubing I Tree: 13-318" z 4112", 5,000 psi Insulated Conductor: 20" 941{ K-55x34" 0.312 WT +/- 80' ConocoPhil I i ps 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMTM) System Dual lateral Completion 1J-178 HB DLP WP 03 GLM, Camco, 4112" x 1" KBMG, - set ~ e67 deg, +l- 2200' MD 13-318" Casing Shce, 68q, L-80, BTC ~ 3647' MD, 2200' ND +1- 7485 MD -Bottom of Motor Centralizer Centralift 418 HP KMHFER with FC6000 Pump ramng string 41/2" 12.6k, L-80, 18TM 3.958" ID, 3.833" Drill D-Sand Casing Exit 8529' MD, az11'rvD 'D' Sand Lateral 7" X 9.619" RAM Xaneer 6.860" Lateral DrIR ID 4112" 11.G%, BTC, L-90 alerted Dner 9.898" Malnbore DrIR ID _ ~uirJment Specifications 7" X 9-518" RAM Junction Mainbore Drifl: 3.68" Lateral Drift: S.BD" RAM Hanger/Seal Bore Dlverter 00: 8.375" Overall Length of RAM Junction: 38.3 n Seal Bore Dlverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 4-112" Lateral Entry Module LEM OD: 6.99" Mainbore Drill w/o Diverlers: 3.68" Mainbore Drifl w/ Isolation Dlverter: 2.50" Lateral Oritt wl "FB" Dlverter. 3.68" OD of Diverters: 3,68" 9.662" DB Nlpple 4Y" a 9-M6" RAM Seal Bon Dlv.rter Iseol wnn s.ia'• 9-I Bora ML Protluctlon Anchor 4112' 12.6k IBTM Tudn4 9rP~~ N{IGXES Baker Oil Tools Lateral E With Dive ntrv Module ILEM) rters and Isolation Lateral A Lateral IsolriloNlnlection eeess "F B" Dlverter alaave IIOWY (In S51B" ML TorgueMater Packer stalled nLEMI Installetl'n LEMt - _ ~` Poaleve umhmg toner Inaicare. c«r«r L«rilon V ICI ~~..';. snap INSnaP om ~~ Poaikve LOOlin9 GOllet Odmnng Prokle IAUmm%k allgvnaN a LFIa F PAM Nanq-1 LarerM gverler ~' Lateral IfOla%On Ramp Upper iola Seal Borc for LaterL I ladadon DIYMH lnaP lNinaP OUt ].6!" ID Poukve Looting cone) Lateral Au<sa Nfintlow InaNMS PaaMw Lw..%a...o v. Lateral ladan« Tlwiwa,o pw.wrl lower scale Ideals inaitle RAM 4112" Gulda Sh-, G.00" OD 41/2" Casing Shoe, 11.1#, LAO BTCM ~ 17068' MD, 3212' ND \~~~ Seal Assembly 'B' Sand Lateral 7" X f-R8" MIZXP a.7G" Seal OD Liner Xanper Paobr 7.176" ID act ri+l-1,620' 61/2" 19.6%, BTC, LAO Slaned Dnar As Planned 6-112" EooenWe Gulaa ahw S-Ibon Receptaeb a.76"ID 9-518" Casing Shce, 40.Otl, L-80 BTC ~ 9135' MD, 3288' TVD, 84 deg inc 5712" Casing Shoe, 15.5#, L-80 BTCM ~ 17072' MD, 3281' ND L' • ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~2~~ ~ ~ l ~g ~' PTD# ~i D 7 ~Z~°' Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /fl-,~G~ /~--/7g -~ (If last two digits in permit No. ~7, ~ Z/ ,API No. 50- DZ~- 3 3 ~ - ~• API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /infect is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit; Non-Conventional production or production testing of coal bed methane is not allowed Well for (..name.. of well) until after (,Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 r • LI ^ ~ , ~ ~ o a~ p- , m ~ Il v: o ; I ~, ~ ~ j c, ! v, ~ m co W , co °j as 3, ° ~ a p O) N O O ~ N ~ ~ : ~ ~ ~ ~ ~ ~ ~ ~ 4 , . . ~ , W U a; cLi; ~ I ; v. ~, ao N: o m. •~ d o °. E O ~ ~ ~~ ~: ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ o: ~~ ~ r. ~' ~ m. ~ ~~ ~, ° m o' 0. ~ ~ m ; i ; ~ ; io, ~ 4 o w O' w U o. i , ~ ~ m m' L O CO ~ ~ T O: Q ~ ~, N t N. ~ ~ ~ ~ ~ ~ ~ ~ ~ , I ~ ~ ~ ~ ~~ ~ p ?~~ ~ ~ (Q: ~ N ~ C• "O. N. S. ° ~+~ ~~ . ' _, i 'D ~ 'O 'O N p Qy N ~ ~ . ~ , ~ , • X~ Y ._ ~ m. 3. 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F N O c N ~' C O «S' p~ c N' .C fl'. ~ ~ " ~ ~ v; o ° ~ - _ m' ~~ ~' m a m g ~ ~ .E; ~ o, : ~ O, N ~ m~ ~ ' c: ~ O O ' ' 3 ' o w a ' , f6 ' • ~ - ~, ~, ~ c: °i Y f6, c o~ O O O °, Z' m~ c ° m~ O ~ ~ °~ Q~ f0 ~ : m~ ~ vr, ~ a: o~ ~, O O ~ N m _ ' Y i Q a~; a ~ c, .°: m, °' o r s °: : L, o L: a~ .O c °, m °, N: i, _' a. ~: ~ o: ,~ ~. a~' ~: o: .. w, m, •- ~ ~ 3' rn o ' m. o. ~: o a 3' L 3 v a • ' • 3. 'rn ' U N. 'Q m m G 'O: ~ ~ (6. p, v' ~ ti, ~+ ~~ o: ' ' o p, , ~, 3, ~ 3, b m y ~ m, 'O. ~~ i .., a 'I N: ~ ~ ~'' '~ c ~, 3, ~; ~' M, gyp, N)~ o a. ° °~ w N, p: °* ' ~ ,~~ m o. ~ T ~ o 3 ~ L; °~ °; U °o d ~ o. v. v: > c, cc: o: m a~ ° ~ ~ v ~: ai -o ai o m ~~' o, c. I o ~ o. a ~ a o ~ N: ~ o' E' m. ~ ° a~ E , o. rn c. 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'~, E a « .~ ~ ° N~ a ~ , v >' ~ ° . v' U' o ~ ~ > o u ~ > 3 c m ~ _~ v. m °~ ~ ; ~ ~ ~ , ~ a E' W, ai , . - ~ •~' 3 ~' f4 I . . . . ~' ~ ~ ° ~ ° ~ . c, ° € , - - ~, ~ - ~ 3 I ~ ; ' i a a~ W a a i fl ~ ; c o, ui Y ~, a~, a af6i ~ .~ °~' °~' °~' 3' v ~ ~; ~; ~; c~; `_; a a a~, O; n O `m; n m U a~' 'S . a' o; i z a ~ o ~ U; U' U ~, ~ ~ U U U v Q ~ ~ v = w p`' '=-; ¢ 0 L O, m m U : ~, o' ~' °'' ~' ~ ~ . , m a o tn v~; o U p U c , - , : ., , .. , , ~ , , , . : . , , , , , , W o. O ~ N _ M ~~ CO I~ W O O) N M r I ~ cn _ (p h~ c0 O> O N _ N M N N N a N ~ O !~ O N N N N O O N M M N M V M M M ~ c0 1~ a0 M M M M_ O M O p "' {6 N ~ ap+ R N +' N R c U O w N w ~ ~ ~ O N i ~ ~~ O ._ _ n _ N J ~ H ~ y CTi O Q C Q ~ I ~ Q ~ ~ Q 0 W ~ Q ~ ~ Q FW" ~ Q~ d Q W C7 ~. • Well History File APPENDIX Information of detailed nature that is not particulariy germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and fo simplify finding information, information of this nature is accunmulaied ai the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infor~aiion. r r 1J-178Ll.tapx Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 15 09:37:39 2008 Reel Header Service name .............LISTPE Date . ...................08/02/15 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/02/15 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000516050 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services scientific Technical services 1J-178 L1 500292336860 ConocoPhillips Alaska, Inc. Sperry sun 15-FEB-08 MWD RUN 3 MWD RUN 7 Mw-000516050 Mw-000516050 R. FRENCH B. HENNINGSE F. HERBERT M. THORNTON 35 11N l0E 1647 2452 .00 122.02 81.00 Page 1 ~o~-lad ~ !S9/~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J-178Ll.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3665.0 12.250 13.375 3665.0 8.500 9.625 8365.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2, 3 & 7 COMPRISE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). THIS WELL KICKS OFF FROM 1J-178 AT 8365'MD/3190'TVD (TOP OF WHIPSTOCK). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3, &7 REPRESENT WELL 1J-178 L1 WITH API#: 50-029-23368-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17083'MD/3199'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (X- 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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLi6.000 Page 2 r: Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP 1 17-178Ll.tapx ~~ L clipped curves; all bit runs merged. .5000 START DEPTH 3631.0 3631.0 3631.0 3631.0 3631.0 3639.5 3675.0 STOP DEPTH 17038.0 17038.0 17038.0 17038.0 17038.0 17078.5 17083.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 3631.0 3 8226.0 7 8365.0 REMARKS: MERGED MAIN PASS. MERGE BASE 8226.0 8365.0 17083.0 Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .12N Max frames per record.... ..........undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD units size Nsam Rep Code offset FT 4 1 68 0 FPH 4 1 68 4 API 4 1 68 8 OHMM 4 1 68 12 OHMM 4 1 68 16 OHMM 4 1 68 20 OHMM 4 1 68 24 HR 4 1 68 28 Channel 2 4 6 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 3631 17083 10357 26905 3631 ROP MWD FPH 0 2782.97 263.004 26817 3675 Page 3 Ldst Reading 17083 17083 • 1~-178Ll.tapx GR MWD API 19.93 119.68 65.5707 26849 3639.5 17078.5 RPX MWD OHMM 3.67 2000 39.2706 26784 3631 17038 RPS MWD OHMM 0.35 2000 40.0909 26784 3631 17038 RPM MWD OHMM 0.06 1616.89 40.9615 26784 3631 17038 RPD MWD OHMM 1.97 2000 44.1103 26784 3631 17038 FET MWD HR 0.11 336.32 0.946451 26784 3631 17038 First Reading For Entire File..........3631 Last Reading For Entire File...........17083 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/15 Maximum Physical Record..65535 File Type ................L0 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.......08/02/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 3631.0 8182.5 RPM 3631.0 8182.5 RPS 3631.0 8182.5 RPx 3631.0 8182.5 FET 3631.0 8182.5 GR 3639.5 8190.0 ROP 3675.0 8226.0 LOG HEADER DATA DATE LOGGED: 13-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8226.0 TOP LOG INTERVAL (FT): 3631.0 BOTTOM LOG INTERVAL (FT): 8226.0 BIT ROTATING SPEED (RPM): Page 4 • 17-178Ll.tapx HOLE INCLINATION (DEG MINIMUM ANGLE: 73.0 MAXIMUM ANGLE: 79.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3665.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 59.0 MUD PH: 9,7 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.100 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.317 118.8 MUD FILTRATE AT MT: 2.200 72.0 MUD CAKE AT MT: 2.000 74.0 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.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MwD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Page 5 • i 17-178Ll.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3631 8226 5928.5 9191 3631 8226 ROP MWD020 FPH 0 2782.97 268.459 9103 3675 8226 GR MWD020 API 19.93 119.68 63.7827 9082 3639.5 8190 RPX MWD020 OHMM 3.67 2000 12.4057 9073 3631 8182.5 RPS MWD020 OHMM 0.35 1100.48 12.163 9073 3631 8182.5 RPM MWD020 OHMM 0.06 1187.09 13.0643 9073 3631 8182.5 RPD MWD020 OHMM 1.97 2000 18.7772 9073 3631 8182.5 FET MwD020 HR 0.11 87.4 1.2319 9073 3631 8182.5 First Reading For Entire File..........3631 Last Reading For Entire File...........8226 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8183.0 8365.0 RPD 8183.0 8365.0 RPM 8183.0 8365.0 RPS 8183.0 8365.0 RPx 8183.0 8365.0 GR 8190.5 8365.0 ROP 8227.5 8365.0 LOG HEADER DATA DATE LOGGED: 15-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8365.0 Page 6 17-178Ll.tapx TOP LOG INTERVAL (FT): 8226.0 BOTTOM LOG INTERVAL (FT): 8365.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78,2 MAXIMUM ANGLE: 86.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3665.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 48.0 MUD PH: g,2 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.600 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.156 102.3 MUD FILTRATE AT MT: 1.800 72.0 MUD CAKE AT MT: 1.900 72.0 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.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPx MWD030 oHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 Page 7 i 17-178Ll.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8183 8365 8274 365 8183 8365 ROP MWD030 FPH 4.8 274.42 146.126 276 8227.5 8365 GR MWD030 API 54.65 110.28 86.0272 350 8190.5 8365 RPX MWD030 OHMM 8.73 26.06 12.2638 365 8183 8365 RPS MWD030 OHMM 11.04 30.9 14.8684 365 8183 8365 RPM MwD030 OHMM 11.73 29.16 16.2134 365 8183 8365 RPD MwD030 OHMM 12.56 28.81 17.1957 365 8183 8365 FET MwD030 HR 0.27 39.49 9.89055 365 8183 8365 First Reading For Entire File..........8183 Last Reading For Entire File...........8365 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/15 Maximum Physical Record..65535 File Type ................L0 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.......08/02/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8335.5 17038.0 RPM 8335.5 17038.0 RPS 8335.5 17038.0 RPx 8335.5 17038.0 FET 8335.5 17038.0 GR 8343.0 17078.5 RoP 8365.5 17083.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: Page 8 header data for each bit run in separate files. 7 O1-NOV-07 Insite 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: 6.02 Memory 17083.0 8365.0 17083.0 79.6 93.7 17-178Ll.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 245697 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8365.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 69.0 MUD PH: ,0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FPH 4 1 68 4 2 GR MwD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MwD070 oHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 Page 9 • 17-178Ll.tapx RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8335.5 17083 12709.3 17496 8335.5 17083 ROP MWD070 FPH 0 836.41 262.037 17436 8365.5 17083 GR MwD070 API 39.5 92.87 66.0874 17462 8343 17078.5 RPX MWD070 OHMM 3.8 2000 55.5292 17406 8335.5 17038 RPS MWD070 OHMM 4.53 2000 57.0939 17406 8335.5 17038 RPM MWD070 OHMM 2.95 2000 57.6465 17406 8335.5 17038 RPD MWD070 OHMM 0.47 2000 61.6439 17406 8335.5 17038 FET MWD070 HR 0.11 336.61 1.76679 17406 8335.5 17038 First Reading For Entire File..........8335.5 Last Reading For Entire File...........17083 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/15 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/02/15 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF scientific Technical services Scientific Technical services Page 10 End Of LIS File 1.7-178Ll.tapx Page 11
