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Home My WebLink About205-120i ~ Image Project Well History Fite Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Sa~~ ,~~ Q Well History File Identifier Organizing (done> ^ Two-sided III 111111 II III II III ^ Rescan Needed RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. + ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other. ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ Project Proofing III II~)II IIIII II III BY: aria Date: ~ a.. ~ !s/ Scanning Preparation _~ x 30 = ~ + ~ =TOTAL PAGES BY: aria Date: (~., I 'p D ~ (Count does not include cover sheet) /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~ ~ ~ I V ~ /s/ I/~/) 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 ~) I II II I ~ III ReScanned III II'II) I I III II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III 10/6/2005 Well History File Cover Page.doc ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia"* Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia"* Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State cf Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS ~~5 _ , a o ~~ ~~ ~ __---~ '~b~'~I~~ J~~' ~~ ~~;~ i, L ~j !b o9 ~ ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051200 Well Name/No. KUPARUK RIV UNIT 1J-03L1 Operator CONOCOPHILLIPS ALASKA INC MD 13035 TVD 6529 Completion Date 9/6/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR Well Log Information: Log! Electr Data Digital Dataset Type- Med/Frmt Number Name ~,~ Asc Directional Survey Rpt ~ / ~ Directional Survey rI ~~p,? C a ~ 14206-Induction/Resistivity Log 14206 Gamma Ray Log 14206 Gamma Ray ~;~ apt ~: D C ~~ 14256'/LIS Verification Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~`-hi~-- Analysis .YLPf'" Received? Comments: Compliance Reviewed By: API No. 50-029-23002-60-00 UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 11560 13035 Open 10/4/2005 IIFR ~ 11560 13035 Open 10/4/2005 IIFR ~ 11603 13037 Open 11/8/2006 LAS w/Graphics 25 Blu 11595 13037 Open 11/8/2006 MD GR 22-Aug-2005 25 Blu 11595 13037 Open 11/8/2006 TVD GR 22-Aug-2005 11603 13037 Open 11/29/2006 LIS Veri, GR, ROP w/Graphics ! -- -- -- Sample Interval Set Start Stop Sent Received Number Comments ~N Daily History Received? Formation Tops ~j ~ N Date: 7 i • Transmittal Form ~~® BAKER NU_ GHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7t" Ave, Suite 100 Anchorage, Alaska 6.~,: '' 'i 99501 I Attention: Helen Warman i °°~•- Reference: 1J-03L1 ~ °-°~- Contains the following: RL`II~~D I 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary i LAC Job#: 958647 ,, _, ~"£ Sent By: Deepa Jo lekar Dim A~o17,'>2 .~ 4 Received By: ~~~~~/ Date: -~ - -~ - .,... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska _ ¢ 99518 b~ - j~~ I~l~$-~ Direct: (907) 267-6612 FAX: (907) 267-6623 f~ ,. ° ..i .._ . , ~~' - - ~~- ±' ~l ~-. i r,~ a~ k,T- ~_ ~i .,.. i 1 ~ __ ~~ -- --- - ~: ~. -_-- (,.- ~ • Transmittal Form r~~® BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1J-03L1 Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 958647 Sent By: Deepa Joglekar Received By: A ~ ~- :. Date =1ti~:0'1,~~06 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 26?-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska ~b ~ ~ ~2~ ~ ~~~~~ ~ Direct: (907) 267-6612 FAX: (907} 267-6623 I 1 ~~°~_;_: -.. _.__ ,; ~~ _ -- - - f~L~- ~~ ~- '~ _~-; A ' ~~ ~' --- - --- _. . _ _ '' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG f~~i~~ ~~~ ~ ~~Q~ Alaska Qil ~ Gaa ~on~. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Clas . f1C i?fa~8 ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 9/6/2005 ~ 12. Permit to Drill Number 205-120 3. Address: c/o P.O. Box 196612, Anchorage, Alaska. 99519-6612 6. Date Spudded 8/17/2005 °' 13. API Number 50-029-23002-60-00 4a. Location of Well (Governmental Section): Surface: , 2107' FSL 2419' FE S 7. Date T.D. Reached 8/22/2005 14. Well Name and Number: 1J-03L1 , L, EC. 35, T11 N, R10E, UM Top of Productive Horizon: 4067 FSL, 300' FWL, SEC. 31, T11N, R11E, UM g• KB Elevation (ft): 116.12' 15. Field /Pool(s): Kuparuk River Field /Pool Total Depth: 5268 FSL, 534' FWL, SEC. 31, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 13035 ' + 6529 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558790 ~ y- 5945920 'Zone- ASP4 10. Total Depth (MD+TVD) ~ 13035 + 6529 Ft 16. Property Designation: ADL 028248 _ TPI: x- 566771 y- 5947946 Zone- ASP4 Total Depth: x- 566994 ~ Y- 5949149 ~ Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1473' (Approx.) 21. Logs Run: MWD, GR , ."7°l~~~l~tu i/S~J'~ ~~l 4~~'7~"7V ~D fv. ~, , ~.~°` 22. ASING, LINER AND EMENTING ECORD CASING ETTING EPTF1 MD ETTINO EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 120' Surface 120' 24" 00 sx Arcticset I 9-5/$" 40# L-80 Surface 7784' Surface 4269' 12-1/4" 770 sx AS Lite, 486 sx LiteCrete 7" 26# L-80 Surface 11255' Surface 6272' 8-1/2" 170 sx Class 'G' 3-1/2" 9.3# L-80 11101' 11597' 6180' 6473' 6-1/8" 256 sx Class 'G' 2-3/8" 4.6# L-80 11590' 12921' 6469' 6512' 3" Uncemented Slotted Liner 23. Perforations open to Produc B tion (MD +TV D of Top and " " 24. ` TuelrvG.RECORD ottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 11161' 11109' MD TVD MD TVD 11842' - 12286' 6490' - 6467 12349'-12888' 6470'-6507 25. AciD, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11597' Set Whipstock 26. PRODUCTION TEST Date First Production: September 14, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test 9/15/2005 Hours Tested 8.5 PRODUCTION FOR TEST PERIOD OIL-BBL 319 GAS-McF 898 WATER-BBL 95 CHOKE $IZE 100 GAS-OIL RATIO 2815 Flow Tubing Press. 19 Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL 900 GAS-MCF 2536 WATER-BBL 267 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". !. ~~ ~~~ {)~{ p ~ 7D05 None E_~W »; . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~~ ~ I ~ f ~ A L 2$. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize. test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk B 11625' 6488' None Base C4 11848' 6489' Kuparuk B 12960' 6516' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. /, Signed Terrie Hubble Title Technical Assistant Date ~ ~ ' d ~P'dS 1J-03L1 205-120 PreparedeyName/Number: Terrie Hubble, 564-4628 Well Number Permit No. ! A royal NO. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRaL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. Irene 44: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. Irene 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • Weff: 1J-03L1 ! L2 Accept: 08/15/05 Field: Kuparuk River Field /Pool Spud: 08/17/05 API: 50-029-23002-60-00 / -61-00 Release: 09/06/05 Permit: 205-120 / 205-121 Ria: Nordic #2 PRE-RIG WORK 05/11/05 PPPOT-T & PPPOT-IC PASSED, PT & DD OF MASTER VALVE FAILED, PT & DD OF SWAB VALVE PASSED, FUNCTION TESTED LDS'S (ALL ARE GOOD). 05/13/05 TIFL -PASSED, DD MV -PASSED, PT MV -FAILED. 05/31 /05 ATTEMPTED TO RUN PPROF. UNABLE TO GET DEEPER THAN 1050'. POSSIBLE HYDRATE PROBLEM. 06/07/05 TAGGED HYDRATES AT 3540' RKB. 06/11/05 .REMOVE ICE PLUG AT 3550' W/ HOT DIESEL AND 2, 3" DOWN JET NOZZLE. RIH TO 5500'. BULLHEAD 20 BBLS DIESEL INTO FORMATION. 06/14/05 DRIFT W/2.70" CENT SB TO 11974' WLM, 131' RAT HOLE. 06/17/05 COMPLETED PRODUCTION LOG: THE MAJORITY OF THE PRODUCTION IS FROM THE C SAND. THE A SAND IS PRODUCING A SLIGHT AMOUNT, BUT UNABLE TO QUANTIFY DUE TO WATER FALLBACK EFFECTING SPINNER READINGS. RAN A GAS LIFT SURVEY: GLM #3 AT 9091' IS LIFTING. 07/11 /05 MAKE 2.7" X 9' DUMMY DRIFT RUN. TAGGED TD AT 11992' RKB (EST. 149' OF RAT HOLE). PERFORMED CALIPER SURVEY FROM 11650' SONDEX MEASUREMENT TO 10911' SDM. JOB COMPLETE. 08/07/05 SET 2.813 XN PLUG W/ FILL EXT. (OAL=51 ") AT 11187' RKB, PULLED GLV FROM, STA#4 AT 10,229' RKB, STA#3 AT 9091' RKB. SET DV IN STA#3 AND STA#4, LDFN. 08/08/05 PULL STA #'S 1 AND 2. SET 1" DV'S IN STA #'S 1 AND 2. PRESSURE TEST TBG, GOOD. PULL STA# 5, LEFT OPEN TO CIRCULATE FLUIDS. 08/09/05 ATTEMPT TO SET STA #5. TAGGED HYDRATES CAUSING VALVE TO DROP. PUMPED 20 BBLS METH DOWN TUBING, TAKING RETURN UP IA. TAGGED WHAT APPEARED TO BE THE DV IN STA #2. THIRD ATTEMPT INDICATED THAT VALVE MUST HAVE FALLEN DOWN ON TOP OF THE PLUG. 08/10/05 SET 1.5" DUMMY VALVE STA #5. MITT / MITIA, BOTH PASSED. ATTEMPT TO RETRIEVE 1.5" VALVE FROM XN PLUG. 08/11 /05 FISH 1.5" DUMMY VALVE FROM XN PLUG 11187' RKB. OBTAIN SBHPS OF 2621 PSI (160 DEG F) AT 11980' RKB AND GRADIENT STOP 2574 PSI (156 DEG F) AT 11,780' RKB. JOB COMPLETE. • BP EXPLORATION Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ,Hours Task Code NPT 8/14/2005 00:00 - 09:00 ~ 9.00 ~ MOB P 09:00 - 18:30 9.50 MOB P 18:30 - 19:00 0.50 MOB P 19:00 - 22:00 3.00 MOB P 22:00 - 23:00 1.00 MOB P 23:00 - 00:00 1.00 MOB P 8/15/2005 100:00 - 00:40 I 0.671 MOB I P 00:40 - 01:00 I 0.331 MOB I P 01:00 - 03:45 I 2.75 I MOB I P Start: 8/11 /2005 Rig Release: 9/6/2005 Rig Number: Page 1 of 19 Spud Date: 8/13/2005 End: Phase ', Description of Operations PRE Rig Maintenance finished and ready to move. Presently waiting for Doyon 141 to move onto iJ pad ahead of us. This is a planned event. Rig is on "Stand-by" until Doyon 141, including the Camp is on location at 1J pad and water is delivered to rig/camp facilities. At 09:00 hrs, Doyon rig 141 is on location. Small amount of rigging up before accepting water. PRE Setting rig mats from Spine RD thru S curves around D pad. Pulled rig off Herculite and cleaned up area. Wait. PRE PJSM with Toolpusher, SLB Team Leader, BP WSL, rig crew about rig move. PRE Move rig from Kuparuk 1 B pad to 1J pad access road turn off at the spine road. PRE Wait while the drilling tool house shuffles rig mats around for us. PRE Move rig from spine road down the 1J pad access road. On rig mats for first 1/4 mile around the S turn. PRE Continue moving down iJ pad access road. Not using rig mats except at culverts and pipeline crossings. PRE Arrive at 1J pad with the rig. Avery fast move with surprisingly little problems on the iJ pad access road. It is a much deeper road than the ones to 1 C pad and 1 F pad that gave us problems last year. Call for trucks to bring camps over. Call for pad operator to do pre rig inspection of well. PRE Move in rig camps. Position rig mats around well. 03:45 - 04:00 0.25 MOB P PRE 04:00 -04:15 0.25 MOB P PRE 04:15 -04:30 0.25 MOB P PRE 04:30 - 10:00 5.50 BOPSU P PRE 10:00 - 14:00 I 4.001 BOPSUR P I I PRE 14:00 - 16:30 2.50 RIGU P PRE 16:30 - 16:45 0.25 RIGU P PRE 16:45 - 18:00 1.25 RIGU P PRE 18:00 - 19:15 1.25 RIGU P PRE 19:15 - 19:20 0.08 RIGU P PRE 19:20 - 19:50 0.501 RIGU N RREP (PRE 19:50 - 20:50 1.00 RIGU P PRE 20:50 - 21:00 0.17 BOPSU P PRE 21:00 - 21:30 0.50 RIGU P PRE 21:30 - 21:50 0.33 RIGU P PRE 21:50 - 22:40 0.83 RIGU P PRE 22:40 - 00:00 1.33 RIGU P PRE 8/16/2005 00:00 - 01:20 1.33 RIGU P PRE 01:20-01:40 I 0.331 STWHIPIP I 1WEXIT Accept rig at 02:00. (Make up some time not counted earlier) Position rig in front of well. PJSM prior to moving over well. Position rig over well. Start rigging up and NU BOPE stack. Hoist and secure 2" coil reel. MU inner reel hardline. PT 7-1 /16" BOP stack 250psi low / 3500psi high. Test Koomey unit. AOGCC rep Chuck Sheve wavied witnessing. RU to pull coil into injector. PJSM review stabbing procedures and hazards. Stab coil into injector. Seal end of eline. Reverse circulate mud into coil to fluid pack coil. Shut down pumping to repair leak on pump #1. Repair leak on pump #1. Leak repaired. Try to come on line with pump, blew braker. Line up on different charge pump. (Using mixing pump in pits as charge pump). Reverse circulate mud into coil. Pressure test inner reel valve to 4000 psi. Passed ok. Pump mud reverse circulation to get slack in coil. Unstab injector. Cut coil to find end of wire. Cut off 25' of coil. Attach Kendel coil connector. Pull test to 35 klbs. Make up BHI UOC. Finish MU BHI UOC. PT to 3500 psi. Stab on well. Pump forward to finish slack management. PJSM. Review deployment proceedure. Assign tasks and review critical areas. Call for pad operator to pump open SSV. Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Operations Summary Report Page 2 of 19 Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: i Date ~ Fram - To Hours Task I Code NPT ', Phase ','" Description of Operations - - - ---- - -r - - - ' - __ 8/16/2005 01:40 - 05:15 3.58 STWHIP P WEXIT Pressure deploy BHA #1 to set whipstock for L1 lateral. Pressure on well = 980 psi. 05:15 - 05:20 0.08 STWHIP P WEXIT RIH with BHA #1. Have open EDC on tool. Bullheading down the backside to kill the well. 05:20 - 07:00 1.67 STWHIP P WEXIT BHI depth encoder not working. Wait at 200' until they get them sorted out. Come on line with pumps, pumping down the backside to kill the well @ 3bpm 2200psi. Pumped 150 bbls. 07:00 - 09:30 2.50 STWHIP P WEXIT RIH with open EDC pumping min rate holding 1000psi on well. (Found broken surface wire on BHI equipment. SLB depth counter working after re-booting computer.) 09:30 - 10:20 0.83 STWHIP P WEXIT Log tiein f/ 11500'. Seen good GR spike at 11450' corrected -13'. RIH log CCL to 11620'. See good collars correlations. PU to 11500'. Up weight 30k 10:20 - 10:40 0.33 STWHIP P WEXIT RIH to 11603'. Place TOWS at 11594' and TF at 30deg LOHS. Close EDC. String wt 12500. Pressure up to 3500psi Fury Tool fired. Setdown to 61001bs. WS set and in place. SLB previously placed 3 RA tags in WS. 10:40 - 12:30 1.83 STWHIP P WEXIT TOH open EDC. 12:30 - 13:00 0.50 STWHIP P WEXIT PJSM while POOH re: undeployment. 13:00 - 15:45 2.75 STWHIP P WEXIT Undeploy BHA #1, whipstock setting BHA. Note -confirmed with W F hand. The RA tag is 5.7' down from the top of whipstock. 15:45 - 17:15 1.50 STWHIP P WEXIT Deploy BHA #2 to mill window for the L1 lateral. 280 psi on wellhead during deployment. 17:15 - 19:15 2.00 STWHIP P WEXIT RIH with BHA #2, following pressure schedule. 19:15 - 19:30 0.25 STWHIP P WEXIT Log gr tie in from 11,500'. Subtract 14' correction. 19:30 - 00:00 4.50 STWHIP P WEXIT Tag ws at 11597'. Paint flag. Begin to time mill window at 1' per hour. 3990 psi fs at 1.4 in/1.22 out. DPSI: 100-200. DHWOB: 0.8 - 1.5k#. WHP/BHP/ECD: 15/4030/12.3 ppg. IA/OA/PVT: 675/408/437 bbls. Mill to 11600'. 8/17/2005 00:00 - 02:30 2.50 STWHIP P WEXIT Continue to mill window. Estimated top: 11597, estimated bottom: 11603'. 02:30 - 03:45 1.25 STWHIP P WEXIT Drill open hole to 11613'. Continue to lose +/- 6 bbls of mud per hour. 03:45 - 04:15 0.50 STWHIP P WEXIT Dress window in up and down directions. Make three complete passes. Drift dry. Appears to be smooth. 04:15 - 06:15 2.00 STWHIP P WEXIT Pull out of hole with milling assembly. Maintain BHP using choke schedule. 06:15 - 06:30 0.25 STWHIP P WEXIT PJSM re: undeployment of BHA #2, window milling BHA. 06:30 - 08:30 2.00 STWHIP P WEXIT Undeploy BHA #2. 08:30 - 09:00 0.50 DRILL P PROD1 Check MWD tool on catwalk configured for drilling the build section. 09:00 - 10:30 1.50 DRILL P PRODi Pressure deploy BHA #3 to drill Li build section. 10:30 - 12:30 2.00 DRILL P PROD1 RIH with BHA #3 following pressure schedule with the drilling choke. 12:30 - 13:00 0.50 DRILL P PRODi Log tie in pass over GR marker at 11436'. Make -14' correction. 13:00 - 13:30 0.50 DR1LL P PROD1 Begin drilling build section. Free spin 3750 psi at 1.55 bpm. ECD=12.06 ppg. BHP = 3963 psi. 1.55/1.06/3830 psi. Losing 30 bbls an hour at this time. ROP=60 fph. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Operations Summary Report Page 3 of 19 Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: II- I~ Task 'Code ~i NPT Phase Description of Operations DaDate From - To Hours ' _ _-- - - - - - ------- - - _ -- 8/17/2005 13:30 - 14:30 1.00 DRILL P PROD1 Losses slowly healing up. 1.55/1.2/4100 psi. 14:30 - 15:30 1.00 DRILL P PROD1 Losses healing, now at 1.58/1.38/3900 psi. 15:30 - 16:30 1.00 DRILL P PROD1 Losses now at 1.58/1.45/3944 psi. IAP=707 psi, OAP=495 psi. 16:30 - 18:00 1.50 DRILL P PROD1 18:00 - 20:15 2.25 DRILL P PROD1 20:15 - 20:45 0.50 DRILL P PRODi 20:45 - 00:00 3.25 DRILL P PROD1 8/18/2005 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 03:00 2.00 DRILL P PROD1 03:00 - 05:15 2.25 DRILL P PROD1 05:15 - 07:20 2.08 DRILL P PROD1 07:20 - 07:35 0.25 DRILL P PROD1 07:35 - 10:00 2.42 DRILL P PROD1 10:00 - 10:30 0.50 DRILL P PROD1 10:30 - 12:00 1.50 DRILL N HMAN PROD1 12:00 - 15:30 3.50 DRILL P PRODi 15:30 - 18:00 2.50 DRILL P PROD1 18:00 - 21:30 3.50 DRILL P PROD1 21:30 - 22:15 0.75 DRILL P PROD1 Losses pretty good now. 1.57/1.55/3770 psi. Drill ahead from 11,690'. 4000 psi fs C~ 1.67 in/1.61 out. DPSI: 100-250 DHWOB: 1.5k - 2.5k#. WHP/BHP/ECD: 22/4050/12.22 ppg. IA/OA/PVT: 730/581/480 bbls. ROP varying from 30 to 50 fph. Pull into casing. Log main wellbore tie in. Add 3' correction. Log RA tag at 11603'. Final TOW: 11,597.6', BOW: 11,603.3, RA tag: 11,603' . Test mud pump #2 while inside casing. Repair minor leak. Drill ahead to 11,855'. Directional, ROP, WOB all looking good. ~ Drill build and turn to 11864'. Have enough turn and angle. i Circulate out of hole. ~ Hold PJSM. Undeploy build BHA (3). MU and deploy L1 lateral BHA (#4). Stab coil. Test MWD. Get on well. Run in hole. Log tie in pass accross the RA tag. Make -14'. Tag bottom 11860'. Begin drilling lateral section. Free spin 3620 psi at 1.57 bpm. Drilling at 1.58/1.43/3800 psi. ECD=12.19 ppg. BHP=4036 psi. Pit vo1=410 bbls. IAP=720 psi, OAP=508 psi. ROP slow and ratty. 11889', lost some returns. 1.55/1.0/3700 psi. Little stickey for a moment. Possibly differentially stuck for a moment. Returns slowly healing up. Now at 1.55/1.32/3650 psi. Surveys are coming in 10 deg different on this run than on run #3 when we drilled the build section. This is the same DGS tool run previously. Resurvey in the build section. Confirms that we are 10 degrees different. Let MW D guys sort out the problem to see if it is on surface. They can't find anything. I,Take check shots over the entire build section. Check shots show gradually increasing divergence as we get deeper. Log tie in pass to be sure we are on depth. Make +3' correction. ', Run back to repeat a survey in the build section. Make a flow off survey this time. Found surveys to be in agreement this time. Difference appears to be flow on vs flow off surveys. DD used to working on Nordic 1. Resume drilling. Resume drilling lateral section. 1.56/1.41/3770 psi. ECD=12.15 ppg, BHP=4012 psi. IAP=730 psi, OAP=576 psi. PVT=367 bbls. Slow drilling. Geo's samples show lots of siderite and gloconite. That would explain the ROP. Hit a brick wall. ROP = 0. Sit here and grind away on it for a while. Finally chewed our way thru, and back to making 10 fph. Drill ahead from 11,951'. 3600 psi fs @ 1.6 in/1.5 out. DPSI: '200-300. DHWOB: 1k-2k# WHP/BHP/ECD: 25/4033/12.22 ppg. IA/OA/PVT: 755/634/297 bbls. INC/AZ/TF: 94.1/6.4/60L. ', ROP continues to be slow: 15-30 fpm. 'Short trip to window. Hole smooth in both directions. Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To !Hours Task Code ! NPT - ~ -- - ~- 8/18/2005 122:15 - 00:00 1.75 DRILL P 8/19/2005 ~ 00:00 - 03:00 ~ 3.00 ~ DRILL ~ P 03:00 - 05:00 I 2.001 DRILL I P 05:00 - 06:00 1.00 DRILL P 06:00 - 10:30 4.50 DRILL P 10:30 - 10:50 0.33 DRILL P 10:50 - 11:10 0.33 DRILL P 11:10 - 11:30 0.33 DRILL P 11:30 - 15:30 4.00 DRILL P 15:30 - 16:30 I 1.001 DRILL I P 16:30 - 18:00 1.50 DRILL P 15:00 - 20:30 2.50 DRILL P 20:30 - 22:00 I 1.501 DRILL I P 22:00 - 23:15 I 1.251 DRILL I P 23:15 - 00:00 I 0.751 DRILL I P 8/20/2005 00:00 - 03:00 3.00 DRILL P 03:00 - 05:00 2.00 DRILL P 05:00 - 05:50 0.83 DRILL P 05:50 - 06:10 0.33 DRILL P 06:10 - 11:00 4.83 DRILL P 11:00 - 11:40 I 0.671 DRILL I P Spud Date: 8/13/2005 Start: 8/11/2005 End: Rig Release: 9/6/2005 Rig Number: Phase I, Description of Operations PRODi Drill ahead from 12,020'. Take on additional mud into pits. Add 4 ppb klagard to new mud. Continue to lose approx 12 bbls per hour of mud. PROD1 Drill ahead from 12,050'. 3600 psi fs ~ 1.62 in/1.55 out. DPSI: 200-300. DHWOB: ik-3k# WHP/BHP/ECD: 25/3877/11.78 ppg. IA/OA/PVT: 627/181/439 bbls. INC/AZ/TF: 95.4J341.0/120R. ROP continues to be slow: 15-30 fpm. Weight transfer good. New mud added to system reduce ECD from 12.2 to 11.8 ppg. PROD1 Drill ahead from 12,115'. Fairly consistent ROP of 25 fph. Continue to lose about 10 bbls per hr of mud. PROD1 Wiper trip to window. PROD1 Resume drilling lateral section of hole. ROP=25 fph. 1.6211.5313750 psi. IAP=634 psi, OAP=215 psi. PVT=407 bbls. ECD=12.1 ppg. BHP=3990 psi. PROD1 Wiper trip to window. Clean off bottom, and clean in open hole. PRODi Log tie in pass over RA tag. Make +2' correction. PROD1 Continue back in hole. No problems. PROD1 Resume drilling. Free spin 3725 psi at 1.6 bpm. Drilling at 1.6/1.54/3900 psi. WOB=2500 psi. PVT=363 bbls. Lost 44 bbls in past 5.5 hours. IAP=640 psi, OAP=233 psi. ECD=12.2 ppg, BHP=4020 psi. ROP = 30-45 fph. PROD1 Clean pickup off bottom at 24 klbs. Clean to window and back in hole. PROD1 Resume drilling. 1.58/1.52/3904 psi. PRODi Drill ahead from 12,250'. 3999 psi fs @ 1.57 in/1.48 out. DPSI: 100-200. DHW06:1.75k#. WHP/BHP/ECD: 37/4117/12.46 ppg. IA/OA/PVT: 650/290/304 bbls. INC/AZM/TF: 86.3/0.0/85L. ROP 40-50 fph. Wt transfer good, but ECD high, probably due to mud properties. Call for trucks to swap to new mud system. PRODi Drill ahead from 12,600'. Begin new flo-pro down coil. 4000 psi C~3 1.57 bpm / 12.49 ppg ECD before displacement. 3400 psi @ 1.54 bpm / 11.8 ppg after mud swap. PRODi Wiper trip to below window. Hole smooth in both directions except for one "bounce" at 12,602' while RIH.. PROD1 Drill ahead from 12,620'. 3480 psi fs ~ 1.56 in/1.46 out. 200-400 DPSI. DHWOB as high as 3.3k#. PVT: 473 bbls. BHP/ECD: 3939/11.93 ppg. PROD1 Drill ahead from 12,637'. PVT: 475 bbls. PROD1 Drill ahead from 12,720'. 3400 psi fs C~ 1.57 in(1.55out. DPSI: 200-300. DHW0B:1.75k#. WHP/BHP/ECD: 37/3920/11.9 ppg. IA/OA/PVT: 647/278/461 bbls. INC/AZM/TF:86.5/349/90R. ROP 25 to 35 fph. PROD1 Clean to window, no problems. PROD1 Make tie in pass over RA tag. Make +6' correction. PRODi Resume drilling lateral section of hole. Free spin 3730 psi at 1.67 bpm. Drilling at 1.67!1.6313750 psi. WOB=23001bs. ECD=11.91 ppg. BHP=3940 psi. IAP=650 psi, OAP=280 psi. PVT=452 bbls. PROD1 Slow drilling. 1.60/1.55/3700 psi. PVT=440 bbls. Free spin 3670 psi at 1.6 bpm. Not getting much motor work. WOB=2300 lbs. String wt = -7000 lbs. Stacking max weight at Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: iJ-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date From - To 'Hours ';I Task '~, Code NPT ' Phase Description of Operations _-- - _ _ l _ _ _ -- -- - - 8/20/2005 11:00 - 11:40 0.67 DRILL P PROD1 surface without not much more on WOB sensor. Would like to try getting more weight on bit to see if it will drill better. Mix some Alpine beads and see if it gives us more WOB and the ,ability to drill a little better. Only averaging 10 fph so far today. 11:40 - 12:05 0.42 DRILL P PROD1 Start pumping 47 bbls of Alpine glass beads (Coarse size). Mixed at 6#/bbl. 12:05 - 12:25 0.33 DRILL N STUC PROD1 Beads to the bit. Pump 20 bbls out, got an additional 1000 Ibs WOB now at 3300 Ibs. Make a pickup to check free spin. Can't pick up, and starting to pack off. Returns getting worse the more we pump. Motor and orienter won't turn. BHP = 3418 psi. Possibly packed off below the annular pressure sensor. 65 bbls since starting to pump glass beads. 24 bbls out the bit. Pumping more beads below the packed off interval will make it worse. We are about 5' off bottom. 12:25 - 13:10 0.75 DRILL N STUC PROD1 Open EDC. PLF to get remainer of beads above BHA, and to prevent further packing off. Pumping 1.97 bpm, 3800 psi thru an open EDC. Annular pressure transducer = 4080 psi. Transducer is 32' above bit. Probably packed off below pressure transducer. Pump beads out of EDC plus 7 bbls of neat mud behind. Try to shut EDC. It won't close all the way, and is 12% open. Try pumping 2 bbls to flush it clear. Can'# pump. Still packed off. At least the EDC is holding. Cycle coil pressure up and down. Can't establish circulation. Try to open EDC. EDC is out of calibration and won't open. A downhole calibration must be done, and there is the risk of disconnecting. Need to establish circulation, so will take the chance. Recalibrate and open the EDC. 13:10 - 15:00 1.83 DRILL N STUC PROD1 EDC open. Circulate bottoms up to get the remainder of the beads OOH, and allow us to work pipe without packing off further up hole. Pumping 2.0/1.56/3900 psi. Holding pipe with maximum stack surface weight. WOB sensor is reacting to the stacked weight we have on it. WOB sensor is 31' off bottom. We are likely stuck on the bottom 31' of BHA. Got bottoms up, but are still getting lots of beads over the shaker. Continue to circulate thru an open EDC until the returns are clean. 15:00 - 15:30 0.50 DRILL N STUC PROD1 Hold PJSM to discuss plan forward. Returns have mostly cleaned up. Still getting a few beads, but not bad. Total of 230 bbls since starting to circulate. Bottoms up volume = 60 bbls. SD pumps. Shut EDC. Pressure up on the backside to 1000 psi. Drop the backside to zero thru the Baker choke while holding 4000 psi on the coil. Repeat while trying to turn the HOT. Try 3 times. No luck. Try 1500 psi on the WHP then dumping thru the Baker choke. Holding maximum stacked weight at surface. Might be making a small amount in the hole as we cycle pressure. 10 klbs on WOB sensor. Start depth 12840.1'. 15:30 - 16:00 0.50 DRILL N STUC PROD1 Continue to cycle WHP to 1500 psi, while holding maximum stacked weight, and 4000 psi on coil. Depth now 12842.4'. Possibly just helic'ing the pipe in the hole. WOB now 11400 lbs. Have cycled WHP 20 times with no improvement. Line up to use a 1/4 turn valve instead of the Baker choke. Continue to surge WHP from 1500 psi to 0. Surge it 10 more times. No Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 1 J-03 1 J-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 ~ ~ ~ ~ Hours Task Code i NPT ' Spud .Date: 8/13/2005 Start: 8/11/2005 End: Rig Release: 9/6/2005 Rig Number: Phase i Description of Operations 8/20/2005 115:30 - 16:00 16:00 - 16:45 16:45 - 19:30 2.751 FISH N 19:30 - 19:45 0.25 FISH N 19:45 - 22:00 2.25 FISH N 22:00 - 00:00 ~ 2.00 ~ FISH N 8121 /2005 100:00 - 01:00 01:00 - 01:15 01:15 - 04:15 STUC PROD1 luck. Coil pressure holding steady. Can't get flow pass the packed off interval. Still seeing pressure on BHP sensor, and WOB on DH WOB sensor. Packed off interval is below these sensors. STUC PROD1 Bleed coil and WHP off. Pull to maximum safe pull of 60 klbs. DH WOB went from 8500 Ibs compression to 5700 Ibs tension. Continue working pipe up and down to maximum overpull. Work 5 times. Slacking off quickly to maximum stacked wt. Seeing overpull and slackoff on WOB sensor. Pull to 60 klbs. Hold for 5 minutes. Unable to pull free. Consult with town. Give EDC the order to disconnect. 0.501 DRILL (N 0.751 DRILL I N Note - It may not mean anything, but the drilling choke plugged off at one point during the previous 4 hours operations. When the choke was cycled a lot of paint chips came over the shaker. The mud pits were painted during summer shutdown. STUC PROD1 PU at 30 klbs. (Pumps off). Confirmed free. Kick on pumps. POH pumping at 2 bpm. PU weight with pumps on is 24 klbs. No problems in open hole, or in the B shale interval. STUC PROD1 At surface. Close master with 650 psi on well. Flow check well. Repair loose control panel valve on Swaco choke. Get off well. Unstab coil. LD mwd tools. Check and clean high pressure filters on pumps and in reel house. STUC PROD1 ~ Hold PJSM to discuss deployment MU Fishing BHA #1 (2-1/2" GS spear w/jars etc) with. EDC & Power Comms. Deploy BHA. WHP: 615 psi. STUC PROD1 RIH maintaining BHP schedule. Circ at min rate while RIH. Full rtns. STUC PROD1 RIH with GS spear fishing assembly. Subtract 14' correction. Run in open hole at 35 fpm. 1750 psi C 0.57 in. Continue full rtns. Continue RIH. STUC PROD1 RIH thru B shale ok. Check weight above fish. Up wt =25 klbs, down wt = 8 klbs. Lost 12 bbls of mud while RIH. pumping 0.58 bpm, 1800 psi. Tagged top of fish at 12,794'. Stack 3000 Ibs down. WHP=650 psi, 0 bpm. Jar #1. Came free on first lick. POOH to 12735', pick up clean. RIH, set back down on fish. Pulled out of GS the first time. Tag again at 12,794'. PU to 35 klbs. Jar #2 35 klbs. No jar action. Set down to -2000 lbs. Jar #3 PU to 40 klbs no jar action. Set down to cock jars again. Jar #4 PU to 60 klbs. Jar lick, fish came free. Pull up hole 5-8 klbs drag, with erratic wt. Looks like pulling BHA thru fill. Run back in hole set down at 12,788'. Work fish up hole again. 39 klbs up wt. then 30 klbs up wt. 25 klbs normal up wt with 5 klbs drag. POOH to 12697' STUC PROD1 Release from fish with GS. Pump 1.1 bpm @ 2300 Ibs. 25 klbs up wt. Line up KWF in pits and trucks. Circ ~ minimum rate with 1700 psi ~ 0.36 in/0.16 out. Pump 10 bbls high vis sweep. Pump 10.3 ppg KW F at 3780 psi at 1.44 bpm. Slow rate to 1.0/0.75 as KWF comes up back side. Final rate: 0.5 in/0.3 out. 1.001 FISH I N 0.251 FISH I N 3.001 FISH I N Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date i From - To Hours Task Code NPT Start: 8/11 /2005 Rig Release: 9/6/2005 Rig Number: Phase 8/21/2005 04:15 -04:30 0.25 FISH N STUC PROD1 04:30 - 07:15 2.75 FISH N STUC PROD1 07:15 - 07:45 ~ 0.50 ~ FISH ~ N ~ STUC PRODi 07:45 - 09:50 I 2.081 FISH I N I STUC I PROD1 09:50 - 10:25 I 0.581 FISH I P I I PROD1 10:25 - 10:45 ~ 0.33 FISH N STUC PRODi 10:45 - 11:45 I 1.00 DRILL N STUC PROD1 11:45 - 12:00 ( 0.25 ~ DRILL ~ N ~ STUC ~ PROD1 12:00 - 12:15 I 0.25 DRILL I N I STUC I PROD1 12:15 - 14:25 2.17 DRILL N STUC PROD1 14:25 - 14:55 0.50 DRILL N STUC PROD1 14:55 - 15:50 0.92 DRILL N STUC PROD1 15:50 - 18:00 I 2.171 DRILL I P I I PRODi 18:00 - 23:15 I 5.251 DRILL I P I I PROD1 Page 7 of 19 Spud Date: 8/13/2005 End: Description of Operations RIH at 0.5 bpm @ 1400 psi. Tag and latch fish at 12,697'. 7200 Ibs down wt, 28 klbs up wt. Pull out of open hole and window at 30 fpm. Holding 500-600 psi on WHP pumping down the backside to keep the hole full and maintain 10.8 to 11.0 ppg BHP. PJSM Re: Laying down fishing BHA. Perform flow check while ho{ding PJSM. No flow observed. Stand back injector. Lay down BHA. Recovered fish. All recovered, nothing left in hole. Bit recovered graded 1,1. Motor locked up and won't turn. BHI MWD tools above motor full of mud with beads in suspension. After breaking MW D off of motor got 2 gallons of mud with beads out of MWD tools. Top of motor had beads. Bit had clay balls on bit. Geo examined sample from bit. See remarks section of this report for detailed analysis of sample from bit. Hold pad evacuation drill in conjunction with Doyon 141, Construction crews on pad, and with pad operator. The well was secured. All hands responded to drill including Vac truck drivers on location supporting rig. All hands accounted for. Rig evacuated, pad operator notified, and drill was concluded with no significant action items. Make up new BHI MWD tool and check on the catwalk. MU BHA. Using same bit as last run, new motor, and Agitator. Took BHI checks out of the UOC, and did not run the DFV. Using dart style check vavles from Baker TT. Stab tools, stab injector. Perform shallow hole test at surface of BHI eq. Passed ok. RIH to 500'. Kick on pumps. Pump thru the motor to test Agitator tool. Got good responce on horses head. I'm picking up good vibrations. RIH with BHA #6 to finish drilling the lateral section. Log tie in pass over RA tag. Make -17' correction. RIH to resume drilling lateral section. Pumps to full rate with the EDC closed. 1.57/1.31/4025 psi. Displacing KWF OOH and pumping 8.7 ppg mud. No problems down thru the B shale. No problems in open hole. Make frequent pickups and ease down slow the last 150' to flush debris uphole. Wt check at 12700' = 23 klbs. Free spin = 4000 psi at 1.57 bpm. Begin drilling at 12844'. 1.58/1.53/4300 psi. Good motor work. We weren't getting much motor work on the last run, thats why we pumped the glass beads. String wt = 0. We have improved 7000 Ibs over last lateral run. DH WOB is 2500 Ibs, virtually identical to the last run. Drilling at 30-50 fph. There is a definite and significant difference in our ability to drill now compared to the last lateral run. We have good and consistent motor work, and we have much better string wt. at surface. Drill ahead from 12,890'. 3800 psi fs @ 1.53 in/1.48 out. DPSI: 100-200. DHWOB: 1.5 - 2.25k#. WHP/BHP/ECD: 51/4038/12.20 ppg. IA/OA/PVT: 657/276/331 bbls. INC/AZM/TF: 83.7/27.9/1208. ROP fairly consistent at +i- 25 fph. Weight transfer adequate. Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 'From - To 8/21 /2005 23:15 - 00:00 8/22/2005 00:00 - 00:15 00:15 - 01:00 01:00 - 03:45 03:45 - 05:15 1 J-03 1 J-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task 'Code 0.751 DRILL ~P 0.25 DRILL P 0.75 DRILL P 2.75 DRILL P 1.50 DRILL P 05:15 - 05:45 0.50 DRILL P 05:45 - 08:30 2.75 DRILL P 08:30 - 08:50 I 0.331 DRILL I P 08:50 - 09:45 0.92 DRILL P 09:45 - 10:30 0.75 CASE P 10:30 - 10:50 ~ 0.33 ~ CASE ~ P 10:50 - 13:00 I 2.171 CASE I P 13:00 - 13:30 0.50 CASE P 13:30 - 16:25 2.92 CASE P Start: 8/11 /2005 Rig Release: 9/6/2005 Rig Number: Page 8 of 19 Spud Date: 8/13/2005 End: NPT , Phase ',' Description of Operations PROD1 Wiper trip to window while town evaluates logs for TD. Hole smooth except for one weight bobble and slight motor work at +/-11,705'. PROD1 Log gr tie in across RA tag. Add 1' correction. PROD1 Wiper trip back to btm. Several minor weight bobbles between 12,500' and 12,590'. Otherwise hole smooth. PROD1 Drill ahead from 13,000'. Planned TD is to drill to 13,050'. 3875 psi fs @ 1.48 in/1.38 out. DPSI: 100-200. DHWOB: 1.22k#. PVT: 297 bbls. ROP very slow from 13030'. Hole getting sticky too. Drill to 13035'. Call TD. 37k# pick up off btm. 23k# normal up wt. PROD1 Wiper trip to window. Mix 30 bbl 10.3 ppg pill with 6 ppb coarse Alpine beads while tripping. Hole smooth out. Wiper trip in hole to 12,950'. PROD1 Open EDC. Displace KWF bead pil down coil while moving pipe near btm. PRODi Pull out of hole laying in bead pill. 2450 psi @ 1.1 bpm. No weight bobbles, no problems pumping 48 bbls of bead pill thru an open EDC. PROD1 Tag up at surface. Hold PJSM prior to laying down BHA. Flow check well. No flow observed. PROD1 Lay down BHA #6. Bit recovered graded same as last run, 1,1. RUNPRD Configure BHI MWD tools for running with liner. Check out electrically. All checks ok. Rig crew performed weekly function test of BOPE. RUNPRD PJSM prior to running liner. All hands on rig in attendence. Topics discussed: Well has been flow checked and is static. Safety joint is ready. Use lifting nubbins and dog collar when making up liner with no cementralizers or upsets. Watch out for overhead loads and pinchpoints. Take your time and operate safely. Keep the hole full. RUNPRD Pick up 2-3/8" liner string as per proceedure and Geo's instructions from town. Liner run as follows; BTT deployment sleeve 2-3/8" Solid Tubing (250.97') 2-3/8" Slotted Tubing (443.68') 2-3/8" Solid Tubing (62.77') 2-3/8" Slotted Tubing (539.42') BTT O-Ring sub 2-3/8" Solid Tubing (31.23') BTT Unique Biased Edge Guide Shoe Overall Liner length = 1331.45' Top of liner to be at 11590' Bottom of liner to be at 12921.45' RUNPRD PU BHI MWD tools. Stab coil. Stab injector. RUNPRD RIH with liner on coil tubing. Wt check with bottom of liner at window. Up wt = 24500 Ibs, down wt=7500 lbs. Check window flag at 11573.3' (10200' EOP). Make -24' correction. RIH. Smooth thru the window. Smooth thru the B shale interval. Smooth in open hole. Log down from 12750' to see GR marker Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ', From - To 'Hours Task ~ Code NPT r- _ _ - 8/22/2005 13:30 - 16:25 ~ 2.921 CASE ~ P 16:25 - 16:50 I 0.421 CASE I P 16:50 - 18:30 1.67 CASE P 18:30 - 19:00 0.50 CASE P 19:00-20:301 1.501WHIP IP 20:30-22:00 ( 1.50 WHIP P 22:00.- 23:30 i 1.50 WHIP N DFAL 23:30 - 00:00 0.50 WHIP N DFAL 8!2312005 00:00 - 01:30 1.50 WHIP N DFAL 01:30 - 04:30 3.00 WHIP P 04:30 - 04:45 0.25 WHIP P 04:45 - 05:15 0.50 WHIP P 05:15 - 07:00 1.75 WHIP P 07:00 - 07:15 0.25 WHIP P 07:15 - 08:30 I 1.251 WHIP I P 08:30 - 12:00 3.50 WHIP P 12:00 - 12:25 0.42 WHIP P 12:25 - 12:45 0.33 WHIP P 12:45 - 14:30 1.75 WHIP P 14:30 - 15:15 0.75 STWHIP P 15:15 - 16:00 I 0.751 STWHIPI P 16:00-18:30 i 2.50iSTWHIP~P 18:30-18:45 ~ 0.25~STWHIP~P Spud Date: 8/13/2005 Start: 8/11 /2005 End: Rig Release: 9/612005 Rig Number: Phase Description of Operations RUNPRD on BHI GR tool. Logging down at 150 fph, 6400 Ibs string wt. Make +9' correction. Total correction now is -15', comparable to previous runs (-14' typically). RIH. Position guide shoe at 12921.45'. WOB sensor reads 3700 Ibs, String wt RIH is 6000 lbs. Bring pumps to 1.5 bpm, 4200 psi. PU at 22 klbs. Liner free. Slickest liner I have ever run in Kuparuk. We only lost 1500 Ibs of R!H wt from the window to TD. Due to Alpine beads? RUNPRD Pull back up above GR marker. Log down from 12750' to verify top of liner. Tagged top of liner at 11592'. RUNPRD POH to pick up L2 whipstock anchor. RUNPRD At surface. Hold PJSM to discuss BHA handling while flow checking well. Get off well. Unstab coil. LD liner running BHA. WEXIT MU MWD tools on catwalk. Check Weatherford tools. PU tools. Orient packer slot to 0 deg on HOT orienter. WEXIT Stab coil. Check MW D tools. Get on well. Run in hole. WEXIT MWD tools acting up. First drawing too much current, now unable to power up tools at all. Pull out of hole to check out MWD. WEXIT At surface. Get off well. Unstab coil. Begin testing MWD. WEXIT Continue to trouble shoot MWD tools at surface. Found shorts in UOC and LOC, but still experiencing problems after repaying shorts. 2nd problem found to be surface softwear. Correct same. Stab coil. Get on well. WEXIT Run in hole at reduced rate due to packer slips & element. WEXIT Log GR tie in from 11,450'. Subtract 15' correction. WEXIT RIH to setting depth. 8.5k# dn, 27.5k# up wt. Packer btm at 11,585'. Pull 20k# up wt. Close EDC. Pressure up down coil to 4400 psi. Set WS anchor. Set down on Ws with 3000 Ibs. Confirmed set. WEXIT POH with WS anchor setting BHA. WEXIT Hold PJSM while POOH with setting BHA to discuss swapping BHA's. WEXIT Tag up at surface. Lay down WF whipstock anchor setting BHA (BHA #9). Pick up hollow tray and jars, BHA #10. WEXIT RIH with WF whipstock WEXIT Tie in 11450' Correct -16' , 25,600# up wt, 6300# do wt WEXIT Tag top of WF anchor packer 11584', Set 4K dn, Pick up to 29,500#, Pick up to 33,000# Jar went off WS released, PT to 500# then 1000# hold 5 minutes WEXIT POOH Pump 1.25BPM 3200# CP run trip sheet WEXIT At surface. Get off well. Unstab coil. LD Weatherford tools. Remove orienter from MWD. WEXIT MU window milling assy (Baker motor w/ DSM and string reamer.) Stab coil. Test MWD. Get on well. WEXIT Run in hole. Load 8.7 ppg flo pro into pits to prep for mud change. Install softwear mods in SLB Ops Cab computer. WEXIT Log gr tie in from 11,450'. Subtract 16' correction. Continue displacing 10.3 to 8.7 ppg mud. Printed: 9!12/2005 10:06:03 AM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date I!, From - To Hours I, Task ~ Code ~ NPT I Phase I Description of Operations 8/23/2005 18:45 - 22:20 3.581 STWHIP ~ ~ -- P I IWEXIT 22:20 - 23:00 0.671 STWHIP P (WEXIT 23:00-00:00 ~ 1.OOSTWHIPP ~ IWEXIT 8/24/2005 ~ 00:00 - 01:40 ~ 1.67 ~ STWHIP P ~ ~ W EXIT 01:40-02:15 ~ 0.58~STWHIP~P ~ IWEXIT 02:15 - 04:10 1.92 STWHIP P WEXIT 04:10 - 05:00 0.83 STWHIP P WEXIT 05:00 - 05:30 0.50 STWHIP P WEXIT 05:30 - 07:30 2.00 DRILL P PROD2 07:30 - 10:00 2.50 DRILL P PROD2 10:00 - 10:15 0.25, DRILL P PROD2 10:15 - 10:30 0.25 DRILL P PROD2 10:30 - 15:15 4.75 DRILL P PROD2 15:15 - 17:15 2.00 DRILL N DFAL PROD2 17:15 - 19:00 1.75 DRILL N DFAL PROD2 19:00 - 20:00 1.00 DRILL P PROD2 20:00 - 21:30 I 1.501 DRILL I P I I PROD2 21:30 - 23:00 I 1.501 DRILL I P I I PROD2 23:00 - 00:00 1.00 DRILL N i DFAL PROD2 8/25/2005 00:00 - 00:40 0.67 DRILL N DFAL PROD2 00:40 - 02:40 2.00 DRILL N DFAL PROD2 02:40 - 02:55 0.25 DRILL N DFAL PROD2 02:55 - 04:00 1.08 DRILL P PROD2 04:00 -04:10 0.17 DRILL P PROD2 04:10 - 06:15 2.08 DRILL P PROD2 06:15 - 07:15 1.00 DRILL P PROD2 07:15 - 09:00 1.75 DRILL P PROD2 09:00 - 10:00 1.00 DRILL P PROD2 10:00 - 12:45 2.75 DRILL P PROD2 12:45 - 13:00 I 0.251 DRILL 1 P I I PROD2 13:00 - 16:30 I 3.501 DRILL I P I I PROD2 Tag whipstock at 11,574'. Paint flag at 11,573.8'. 3600 psi fs ~ 1.51 bpm. Begin time milling at 1.0' per hour. Finish displace 10.3 to 8.7 ppg mud. PVT: 329 bbls Mill window from 11577.7' 1.5/3450 w/ 150 psi dill, 1-2k wob, EGD 12.07 PVT 327 11578.5' had MW, then str wt incr, plus started losing fluid 1.5/1.38 Drill to 11579.5' and losses stopped PVT 323 Drill formation 11579.5' to 11590' 1.67/1.58 w/ 400# dill, 2-3k wob, 12.2 ECD PVT 316 Ream and backream window three times and clean. Dry tag, clean PVT 315 POOH following pressure schedule PVT 270 Pressure undeploy w/ 435 psi WHP LD, load out milling tools. Mills were 2.74" no-go, 2.73" go MU build assy. Pressure deploy BHA. Stab coil. Test MWD. Get on well. Run in hole following pressure schedule. Log gr tie in from 11450'. Subtract 16' correction. RIH. RIH through window ok. Close EDC. Drill ahead from 11590'. 3850 psi fs @ 1.63 in/ 1.48 out. DPSI:100-250. DHW0B:2-3k#. WHP/BHP/ECD: 25!3970112.1. 1A/OA/PVT: 634/232/309 bbls. INC/AZMlfF: 56/ /30R. ROP variable: 10 to 40 fph. Getting +/- 40 deg avg dog legs. One accelerometer has failed in DGS tool. Cannot get good surveys. POOH to change out MWD DGS tool. At surface. Hold PJSM. Undeploy BHA w/ 420 psi WHP. Cut off CTC. Stab onto lubricator. Reverse circ slack back into coil. RU cutter on rig floor. Cut off 75' to find end of wire. Cut off additional pipe for wear management (cut a total of 500'). Install Kendal connector. PUII test to 37k#. Meg test good. Head up BHI. Pressure test to 4000 psi. Pressure deploy build assembly. SIWHP: 200 psi. Continue to pressure deploy build assy (BHA #13, 2.4 mtr w/ HYC bi cent). PVT: 220 bbls Run in hole following BHP pressure schedule. Log gr tie in. Subtract 14' correction. RIH. Tag TD at 11,666'. Drill ahead f1 11,666'. 1.6/1.4/3900. 100-300 psi dill. 2-4k# WOB. 12.46 ECD. PVT: 231 bbls Wiper trip through window. Open EDC. Pull out of hole for BHA change. Follow BHP schedule. PVT: 190 bbls at surface. Hold PJSM. Undeploy build assy. LD motor and bit. Re head coil and test same. Pressure deploy BHA #14 (0.8 deg mtr w/ HCC bicent) Stab coil. Test MWD. Get on well. RIH following BHP schedule. Log gr tie in f/ 11450'. Subtract 15' correction. RIH to TD at 11,690' Drill ahead f/ 11,690'. 3800 psi fs C~3 1.56 in/1.41 out. DPSI: 100-250. DHWOB:1.5-2.5k#. WHP/BHP/ECD: 30/4132/12.5 Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8!13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date. From - To ~~ Hours ~ Task Code ~~' NPT ~' Phase ~I Description of Operations 8/25/2005 13:00 - 16:30 3.501 DRILL P PROD2 ppg. IA/OA/PVT: 640/256/252 bbls. INC/AZM/TF 16:30 - 17:55 { 1.42 {DRILL I P ~ { PROD2 17:55 - 18:20 0.42 DRILL P PROD2 18:20 - 22:10 3.83 DRILL P PROD2 22:10 - 22:40 ~ 0.50 ~ DRILL P ~ ! PROD2 22:40 - 00:00 { 1.33 {DRILL I P I PROD2 8/26/2005 100:00 - 01:40 I 1.671 DRILL I P I I PROD2 01:40 - 02:10 0.50 DRILL P PROD2 02:10 - 02:25 0.25 DRILL P PROD2 02:25 - 02:50 0.42 DRILL P PROD2 02:50 - 05:40 2.83 DRILL P PROD2 05:40 - 06:15 I 0.581 DRILL I P I I PROD2 06:15 - 07:15 1.00 DRILL P PROD2 07:15 - 08:15 1.00 DRILL P PROD2 08:15 - 15:00 6.75 DRILL P PROD2 15:00 - 16:00 ~ 1.00 ~ DRILL ~ P ~ ~ PROD2 16:00 - 17:00 1.00 DRILL P PROD2 17:00 - 20:00 3.00 DRILL P PROD2 20:00 - 23:15 I 3.251 DRILL I P I I PROD2 23:15 - 00:00 0.75 DRILL P PROD2 8/27/2005 00:00 - 00:15 0.25 DRILL P PROD2 00:15 - 01:05 0.83 DRILL P i PROD2 01:05 - 02:25 I 1.331 DRILL I P I I PROD2 93.7!137/958. ROP: 40-50 fph. PVT 231 Drill ahead f/ 11,815'. Hitting some hard spots. Drill to 11850'. PVT 215 Wiper to window PVT 209 Drill from 11850' 1.57/1.42/3830/758 w! 100-300 psi dill, 1.5-2.5k wob, 12.5 ECD with frequent sharp stalls to 12000'. Had penetration rate incr last 50'. Start new mud-recip while fin circ fresh mud to bit Wiper to window while fin displace wellbore to fresh mud w/ 12 ppb KG/3% LT Drill from 12000' 1.6/3600!908 with full returns at 11.8 ECD w/ 100-200 psi dill, 1-3k wob. Drill to 12050' and start losing 0.3 bpm w/ ECD C~ 11.53. Return rate gradually improved to 1.54/1.36 by 12078' Continue drilling from 12078' 1.52/1.40/3350/608 w/ 100-200 psi diff, 1-2k wob, ECD 11.75 @ 3876 psi DHP at 92 deg and 6365' TVD. Drill to 12150' PVT 452 Wiper thru window, clean. Wiper to 11300' Log tie-in down from 11450'. Add +3' RIH thru window, clean. Wiper to TD, clean PVT 442 Drill from 12152' 1.56/1.46/3430/708 w/ 100-250 psi diff, 1-2k wob, 11.77 ECD at 89 deg ~ 6365' TVD in 90 api rock Drill on a hard spot from 12254' and losses slowly increasing 1.56/1.3 Drill ahead from 12,268'. 3300 psi fs ~ 1.58 in/1.41 out. DPSI: 150-250. DHWOB: 0.8 - 2.Ok#. WHP/BHP/ECD: 18/3872/11.74 ppg. IA/OA/PVT: 660/360/410 bbls. INC/AZMlTF: 91.3/190.2/358. ROP continues to avg 40-50 fph. Wiper trip to window. Hole smooth. Drill ahead from 12,300'. ROP slowed to 15-20 fph. Drilling lots of hard spots. 3500 psi fs ~ 1.58 in/1.35 out PVT: 358 bbls. Drill ahead from 12,425'. 3500 psi fs @ 1.57 in/1.36 out. PVT: 295 bbls. WHP/BHP/ECD: 26/3968/12.04 ppg. Wiper trip to window. Hole smooth. Drill ahead from 12,450' 1.56/1.43/3500/160L w/ 100-200 psi diff, 1-3k wob w/ 11.6 ECD at 88 deg at 6360' TVD. Add fresh mud to system after PVT at 250 bbls Drill from 12500' 1.56/1.50/3300/708 w/ 100-200 psi diff, 2-3k wob w/ 11.33 ECD while continue adding fresh mud until PVT 477. Drill to 12600' 1.56/1.25 w/ 12.0 ECD w/ used mud PVT 446 Wiper thru window was clean Log down from 11450', add 3.0' Wiper to TD, clean except for set down and stall at 12502' w/ TF 90 deg out Drill from 12601' 1.5811.29/37501758 wl 100-200 psi diff, 1-2.5k wob w/ 11.98 ECD at 3946 psi DHP at 87 deg and 6368' TVD with slow progress due to stacking, then stalls. Numerous stalls at 12608'. Acts like rubble zone-are also near a projected fault Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: i I Date ,; From - To Hours Task I Code NPT Phase Description of Operations 8/27/2005 02:25 - 04:30 2.08 DRILL P PROD2 Drill from 12609' and back to good drilling for a while 1.57/1.3/3650/808 at 91 deg at 6368' TVD, ECD 12.0, to 12680' PVT 363 04:30 - 06:00 1.50 DRILL P PROD2 Drill from 12680' in a multiple stall area 06:00 - 07:00 1.00 DRILL P PROD2 Drill ahead f/ 12,730'. 3500 psi fs @ 1.52 in/1.25 out. DPSI: 200-350. DHWOB; 2.0 - 3.Ok#. WHP/BHP/ECD: 26/3983/12.07 ppb. IA/OA/PVT: 657/353/331 bbls. INC/AZM/TF: 91.5/189.0/958. ROP 35-55 fph. Losing +/- 15 bph mud to formation. 07:00 - 08:15 1.25 DRILL P PROD2 Wiper trip to window. Hole smooth. 08:15 - 11:00 2.75 DRILL P PROD2 Drill ahead from 12,750'. 3700 psi fs CQ? 1.57 in/1.34 out. PVT:305 bbls. Take on mud from uprights.: PVT: 460 bbls. ROP varying from 30 to 50 fph. Wt transfer good. 11:00 - 13:30 2.50 DRILL P PROD2 Drill ahead from 12,850'. PVT: 405 bbls. 13:30 - 15:00 1.50 DRILL P PROD2 Wiper trip to window. Hole smooth. 15:00 -.17:30 2.50 DRILL P PROD2 Drill ahead from 12,900'. 3600 psi fs @ 1.52 in/1.32 out. PVT: 314 bbls. 17:30 - 20:20 2.83 DRILL P PROD2 , Drill from 12955' 1.51/1.30/3850/85L w/ 50-200 psi dill, 1-2k wob, ECD 12.27 at 93 deg at 6368' TVD. Drill to 13054' PVT 262 20:20 - 21:15 0.92 DRILL P PROD2 Wiper thru window was clean 21:15 - 21:30 0.25 DRILL P PROD2 Log tie-in down from 11445', corr +3' 21:30 - 22:25 0.92 DRILL P PROD2 Wiper back to TD was clean except for wt loss at 13005' PVT 223 22:25 - 00:00 1.58 DRILL P PROD2 Drill from 13051' 1.46/1.25/3600/85L w/ 100-200 psi dill, 0.75-2k wob w/ 12.4 ECD at 92 deg at 6358' TVD. Drill to 13100' PVT 199 8/28/2005 00:00 - 00:50 0.83 DRILL P PROD2 Continue drilling from 13100' at 93 deg to right side 1.45/1.25/3650/858 w/ 100-200 psi dill, 1-2k wob w/ 12.34 ECD (4060 psi DHP) at 6351' TVD. Slow drilling due to stacking from TF change. Geo reports shale too. Drill to 13118' PVT 180 00:50 - 01:05 0.25 DRILL P PROD2 Wiper to 13000', clean 01:05 - 04:00 2.92 DRILL P PROD2 Resume drilling from 13118' w/ slow steady progress and increase angle toward 96 deg since may be scraping the B Shale. Drill to 13200' (6341' TVD) PVT 110 04:00 - 05:00 1.00 DRILL P PROD2 Wiper to window w/ 5k overpulls and MW at 12990', 12460' PVT 74 05:00 - 06:15 1.25 DRILL P PROD2 Wiper back to TD. Start 'poorboy' mud swap. Set downs at 12980-13010'. Work several times and end up drilling it. Finish wiper to TD 06:15 - 12:00 5.75 DRILL P PROD2 Drill ahead from 13,200'. New mud all the way around. Continue loading pits. 3500 psi fs @ 1.57 in/1.46 out. DPSI: 200-300. DHWOB: 1.5 - 2.5k#. WHP/BHP/ECD: 18/3980/12.12 ppg. IAlOAlPVT: 657/343/248 bbls. INC/AZM/TF: 98.6/169.1/1008. ROP avg: 30 fph. Trying to climb out of B shale as fast as possible. 12:00 - 14:00 2.00 DRILL P PROD2 Wiper trip to window. No overpulls while POH. Several set downs and motor work at 12,965'. Reduce pump rate from 1.35 to 1.0 bpm and get through. Same problem and solution at 12,990'. Rest of trip to TD fairly smooth. 14:00 - 17:30 3.50 DRILL P PROD2 Drill ahead from 13,352'. 3500 psi fs Cam? 1.50 in/1.41 out. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-03 1 J-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To ' Hours I Task Code 8/28/2005 14:00 - 17:30 3.50 DRILL P 17:30 - 20:15 I 2.751 DRILL I P 20:15 - 21:20 1.08 DRILL P 21:20 - 21:35 0.25 DRILL P 21:35 - 21:55 I 0.331 DRILL I P 21:55 - 22:40 0.75 DRILL P 22:40 - 23:05 0.42 DRILL P 23:05 - 23:35 I 0.501 DRILL I P 23:35 - 00:00 ~ 0.421 DRILL I P 8/29/2005 100:00 - 00:25 I 0.421 DRILL I P 00:25 - 00:50 I 0.421 DRILL ~ P 00:50 - 01:45 I 0.921 DRILL I P 01:45 - 02:45 I 1.001 DRILL I P 02:45 - 04:55 ~ 2.17 ~ DRILL ~ P 04:55 - 06:00 I 1.081 DRILL I P Spud Date: 8!13/2005 Start : 8/11/2005 End: Rig Release: 9/6/2005 Rig Number: NPT I Phase ' Description of Operations PROD2 Take on additional mud. PVT: 554 bbls. Having trouble building angle and drilling w/ neg surface wt PROD2 Drill from 13432' 1.58/1.49/3550/208 w/ 100-200 psi dill, 1-2.4k wob w/ 12.12 ECD at 94.5 deg at 6319' TVD. Drill to 13500' (6310' TVD) PVT 520 PROD2 Wiper thru window w/ 5k overpull at 12990' PROD2 Log tie-in down from 11445', tort +4'. Attempted to hold 200 psi WHP, but welt was flowing. SI @ choke and watch WHP build to 600 psi while logging. PUH to 11400'. Bleed off WHP to 400 psi PROD2 Monitor WHP parked at 11400' (6253' TVD SS, 6369' TVD RKB). Pressure built to 612 psi over 20 min which is 10.4 ppg EMW w/ 8.55 ppg mud. BHI showed 10.92 ppg at 3500 psi DHP due to assumed LSRV PVT 517 PROD2 Hold 700 psi WHP while RIH thru window. Wiper to TD at normal pump rate 1.55/1.47/3500 ECD 11.9 PROD2 Set down at 12876' and drill thru on third try, but set down at 12910' and spud to get thru on fourth try. RIH unfit clean to 12962'. Wiper back to 12870' to orient around, and fairly clean. All pickups were about 5k over PVT 500 PROD2 Wiper back in hole from 12870' and clean until 12958' set down. Lose ground to 12952' w/ 8k overpulls. Wiper back to 12870'. Red pump rate to 1.0 bpm and hold 600 psi whp for i2.7 ECD. RIH @ 50'/min and fairiy clean to 13050'. Open ~ choke and wiper back to 12870' 1.56!1.52/3680 w/ 5-8k overpulls. Continue wiper up hole while reboot SWS PC PROD2 Wiper back in hole and set down at 13000', then 13090'. Reapply 600 psi whp at 1.0 bpm to get thru both spots w/ 12.65 ECD at 1.0/0.25. Continue RIH. Get to 13157', but set down. Work to 13232' and set down, and 13238'. Gradually open choke and drill thru both and wiper in hole to 13391' set down. Appears B shale is falling apart PROD2 Lose ground from 13391' back to 13332' while wiper at normal conditions. Backream to 12870' to test the water. 5-Sk overpulls occasionally, but not bad PVT 460 PROD2 Apply initial 600 psi whp and red rate to 1.0 to maintain ECD at 12.7 ppg while RIH from 12870' while gradually reduce whp to 400 psi 1.0/0.5 and was clean until set down at 13439'. Work thru 10' of set downs, then RIH to TD tagged at 13502° PVT 438 PROD2 Open choke and resume drilling from 13502' 1.48/1.45/3600/258 w/ 200-300 psi dill, 1-2.5k wob, 12.6 ECD at 92 deg at 6310' TVD PVT 428 PROD2 Drilling break at 13520' 1.48/1.39/3600/158 w/ ECD 12.44 Still having trouble building angle-last survey shows 90 deg at 13508' (6312' TVD), TF has been nearly straight up. NB incl shows 92 deg at 13537' PROD2 Drill from 13550' attempting to build angle 1.47/1.31/36001108 w/ 12.47 ECD. Also, starting to run out of push. Stacking max surface wt and getting 800# wob w/ little MW. Finally showing build on surveys at 93 deg w/ NB incl at 95 deg PVT 409 PROD2 Drill from 13583' 1.45/1.32/3600 w/ 12.49 ECD and having to do mini wipers to get wt to bit to drill. Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To 'Hours Task Code 8/29/2005 06:00 - 08:15 ~ 2.25 ~ DRILL P 08:15 - 09:15 I 1.001 DRILL I P 09:15 - 11:30 2.25 DRILL P 11:30 - 13:30 2.00 DRILL P 13:30 - 18:00 ~ 4.501 BOPSUF{P 18:00 - 18:20 0.33 DRILL P 18:20 - 18:35 0.25 DRILL P 18:35 - 20:20 1.75 DRILL P 20:20 - 22:30 I 2.171 DRILL I P 22:30 - 22:45 0.25 DRILL P 22:45 - 23:25 0.67 DRILL P 23:25 - 23:55 0.50 DRILL P 23:55 - 00:00 0.08 DRILL P 8/30/2005 00:00 - 00:45 0.75 DRILL P 00:45 - 01:40 I 0.921 DRILL I P 01:40-03:50 ~ 2.17~DRILL ~C 03:50 - 04:50 I 1.001 DRILL I C 04:50 - 06:00 1.17 DRILL C 06:00 - 08:30 2.50 STKOH C Spud Date: 8/13/2005 Start: 8/11/2005 End: Rig Release: 9/6/2005 Rig Number: NPT Phase ~ Description of Operations PROD2 Drill ahead from 13,588'. 3750 psi fs C~3 1.57 in11.44 out. DPS1:50-100. DHWOB:1.0-1.75k#. WHP/BHP/ECD: 26/4100/12.54 ppg. IA/OA/PVT: 680/394/394 bbls. INC/AZM/TF: 96.7/196.3/HS. Very slow drilling, difficult to get weight to bit. Unable to make any progress. Discuss with Town team. PROD2 Wiper trip to window. Overpulls and mtr work (5k max) from 12,940' to 12,900'. Rest of open hole was smooth. PVT: 362 bbls. PROD2 Circulate out of hole. PROD2 At surface. Hold PJSM to review undeployment. Get off well. Unstab coil. Undeploy. LD BHA. PROD2 Perform bi-weekly BOP equipment test. Witness waived by AOGCC J. Jones. PROD2 MU new 1.1 deg motor and used bi bit PROD2 Safety mtg re: pressure deploy PROD2 Pressure deploy BHA #15 w/ agitator w1400 psi SIWHP. Meg test line, PT CTC @ 4000 PVT 271 FROD2 RIH w/ BHA #15 0.38/1800 following pressure schedule. Test agitator and open EDC PVT 300 PROD2 Log tie-in down from 11450', Corr -13'. Close EDC PROD2 Wiper thru window and head to TD 1.5/1.34/3800 PVT 290 PROD2 First set down at 12787'! Red rate to 1.26/1.20/3330 w/ 12.17 ECD and get to 12848'. Apply 200 psi whp at 1.0/0.65 w/ 12.2 ECD to get to 12858' after several tries. All set downs had MW and all pickups were either clean or up to 5k max overpull. Get past 12858' w/ no pump holding 400 psi whp and set down at 12900'. PUH 20k over and temporarily immobile twice while bring pump back on line and bleed off whp. PUH, sticky to 12770' and start over PROD2 Wiper back in hole 1.25/1.15/3350 PROD2 Fin ream back in hole 1.25/1.15/3450 w/ 11.9 ECD to set down at 12848' and have 15k overpull. RIH and apply 200 psi whp w/ 0.8 bpm/0.7 bpm and get to 12853' w/ 12.2 ECD. Apply 500 psi at 0.5 bpm and get to 12,848' w/ 12.6 ECD. Do various combinations of the above and work to 12892'. Start losing ground back to 12848' and becoming increasingly sticky. Wiper to clean up cuttings to 12,750' and started packing off at 12,770' and had 15k overpull. Need wiper to belly at 11,675' to check cuttings bed too. Discuss PROD2 Wiper to window 1.46/1.2/3770 12.0 ECD was clean PVT 252 Receive orders to OH sidetrack to avoid the B Shale and redrill to the targets given in the 8/29/05 Plan Forward email from Voorhees. Initial planned KO point will be at 12220' PROD2 POOH following pressure schedule for sidetrack BHA Add additional mud to pits PVT 414 Safety mtg re: undeploy PROD2 Undeploy w/ 435 psi Rehead slickline rope socket PROD2 LD agitator assy. MU sidetrack assy PROD2 Hold PJSM in dog house to review deployment procedure. Pressure deploy side track BHA. (1.9 deg mtr w/ R-60ST brass nose cone bit) Printed: 9/12/2005 10:06:03 AM BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To '~ Hours ~! Task Code'' NPT 8/30/2005. 06:00 - 08:30 2.50 STKOH ~C 08:30 - 11:15 2.75 STKOH C 11:15 - 11:30 0.25 STKOH C 11:30 - 16:00 4.50 STKOH C 16:00 - 17:00 I 1.00 I STKOH I C 17:00 - 17:40 0.67 STKOH C 17:40 - 00:00 6.33 STKOH C 8/31/2005 ~ 00:00 - 05:00 ~ 5.00 STKOH ~ C 05:00 - 06:30 I 1.501, STKOH I C 06:30 - 08:30 I 2.00 I STKOH I C 08:30 - 10:00 1.50 STKOH C 10:00 - 10:15 0.25 STKOH C 10:15 - 11:30 1.25 STKOH C 11:30 - 12:00 0.50 STKOH C 12:00 - 14:30 2.50 DRILL P 14:30 - 16:00 1.50 DRILL P 16:00 - 16:30 0.50 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 21:15 4.25 DRILL P 21:15 - 22:15 1.00 DRILL P 22:15 - 00:00 1.75 DRILL P 9/1/2005 100:00 - 03:15 I 3.251 DRILL I P 03:15 -04:30 1.25 DRILL P 04:30 - 11:15 6.75 DRILL P 11:15 - 13:00 I 1.751 DRILL I P 13:00 - 19:30 I 6.501 DRILL I P Spud Date: 8/13/2005 Start: 8/11/2005 End: Rig Release: 9/6/2005 Rig Number: Phase ' Description of Operations PROD2 Stab coil. Test MW D. Get on well. PROD2 Run in hole following pressure schedule. PROD2 Log gr tie in. Subtract 15' correction. RIH through window ok. PROD2 Trough open hole from 12,200' to 12,220'. 1 fpm in up direction. 20 fpm down. Make three passes. 3615 psi fs C~3 1.57 in/1.45 out. WHP/BHP/ECD: 18/3920/11.89 ppg. IAlOA/PVT: 614/201/432 bbls. Low side TF. PROD2 Lock brake at 12,219' for 30 minutes. Drill 1' per hour for 2' (2 hrs). Drill 2' per hour for 2' (1 hr) Drill 3' per hour for 3' (1 hr) PROD2 Set brake @ 12219' for 30 minutes PROD2 Time drill sidetrack at 1'/hr from 12219' to 12225'. No weight transfer to bit. Back ream ST to 12200' at 1'/hr. Work trough. Time drill ST at 1'/hr. PROD2 Time drill ST at 1'/hr. Work trough and ST as needed to clear hole. Stacking out on bottom, attmept to drill ahead with slow ROP. PROD2 Drill ahead with ST interval from 12219' to 12240'. 0=1.58 (1.51 out), 3650 BHP, 3K WOB, 12.1 ECD, 15'/hr. PROD2 Backream trough, ST several times. Wipe hole clean. No problems. All indications show 5 degree change from original hole. PROD2 POOH w/ ST assy and CT. PROD2 Conduct safety meeting for Undeployment. PROD2 Undeploy ST BHA. PROD2 Inspect and rebuild BHA assy. Bit looks good- 1 plugged jet, otherwise 1/1 PROD2 PU new BHA, deploy into hole. PROD2 RIH w/ Lateral assy. PROD2 Tie in. -14' correction. PROD2 Continue RIH to bot. PROD2 Drill ahead from 12240' to 12400'. 0=1.55/1.3, 3650 BHP, 2450 WOB, 11.95 ECD, 75'/hr. TF at 60L. PROD2 Conduct wiper trip to window. PROD2 Drill ahead from 12400' to 12510'. 0= 1.5/1.38, 3600 BHP, 1700 WOB, 11.93 ECD, 58'/hr, TF at 0 PROD2 Drill ahead from 12477' to 12550'. 0=1.5/1.4, 3600 BHP, 1700 WOB, 11.93 ECD, 58'/hr PROD2 Conduct wiper trip to window. Hole acting good. PROD2 Drill ahead from 12550' to. 0= 1.5/1.25 bpm, 3650 BHP, 1700-2450 WOB, 11.93 ECD, 10-58'/hr, TF at 0. Swap mud on the fly, fill pits back to full. -Intermittant siderite streaks -X0700, changed TF to 60R PROD2 Conduct wiper trip to window. Tie in. +5' Correction. RIH to bottom. No problem re-entering ST. PROD2 Drill ahead from 12700' to . 0=1.53/1.41, 3550 press (3200 FS), 1500 WOB, 12.0 ECD, 20-77'/hr, hold 90R TF to correct turning problem. -Continual stacking out starting at 12727' to 12745'. Sticky when pulling through as well- 10K overpull. Work through Printed: 9/12/2005 10:06:03 AM r~ ICJ BP EXPLORATION Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 9/1/2005 13:00 - 19:30 6.501 DRILL ~ P 19:30 - 21:00 1.50 DRILL P 21:00 - 23:30 2.50 DRILL P Start: 8/11 /2005 Rig Release: 9/6/2005 Rig Number: Page 16 of 19 Spud Date: 8/13/2005 End: Phase '! Description of Operations PROD2 PROD2 PROD2 23:30 - 00:00 0.50 DRILL P PROD2 9/2/2005 00:00 - 02:30 2.50 DRILL P PROD2 02:30 - 02:45 0.25 DRILL P PROD2 02:45 - 04:00 1.25 DRILL P PROD2 04:00 - 05:15 1.25 DRILL P PROD2 05:15 - 05:30 0.25 DRILL P PROD2 05:30 - 06:15 0.75 DRILL P PROD2 06:15 - 06:30 i 0.25 DRILL P PROD2 06:30 - 07:00 ~ 0.50 DRILL P PROD2 07:00 - 10:30 ( 3.50 DRILL P PROD2 10:30 - 17:00 I 6.501 DRILL I P I I PROD2 17:00 - 19:30 2.50 DRILL P PROD2 19:30 - 00:00 4.50 DRILL P PROD2 9!3/2005 00:00 -04:45 4.75 DRILL P PROD2 04:45 - 06:30 1.75 DRILL P PROD2 06:30 - 09:15 2.75 DRILL P PROD2 09:15 - 11:30 2.25 DRILL P PROD2 11:30 - 15:00 3.50 DRILL P PROD2 15:00 - 16:30 1.50 DRILL P PROD2 16:30 - 00:00 7.50 DRILL P PROD2 9/4/2005 100:00 - 04:30 I 4.501 DRILL I P I I PROD2 sticky spots as needed. Overall tough drilling. -031700 hrs, change TF to 150R -Continue to have stacking problems and stalling problems. Make short trip. Conduct wiper trip to window. Attempt to drill ahead from 12840'- will not drill. 0=1.52/1.42, 3500 press (3450 FS), 2500 WOB, 11.97 ECD, 8'/hr, TF at 90R. -Appx. 15%chert coming in returns POOH w/ BHA and CT POOH w/ BHA and CT Conduct safety meeting for undeployment Undeploy and LD BHA C/O new components on BHA, PU new bit. Old bit graded 2/4/RGS/XI/BU/PR Conduct safety meeting for deployment Deploy BHA Conduct new safety meeting for deployment with new crew Deploy BHA RIH w/ BHA and CT. Tagged up at 12350'. Worked through tight spot several times. RIH and tagged up at 12580'. Worked through tight spot several times. RIH and tagged again at 12750'. Worked through tight spot several times. Overpull on all tight spots around 15K. Drill ahead from 12840' to 12925'. 0=1.55/1.45, 3500 press (3350 FS), 2200 WOB, 11.75 ECD,. 10'/hr, TF at 100R. Negative coil wt. at surface. -031530, Change TF to 97. Cuttings entirely shale, no chert remaining Conduct wiper trip to window. Tie in. +4' correction Drill ahead from 12925' to . 0=1.6/1.5, 3550 press, 1500 WOB, 12.04 ECD, 25'/hr, TF at 75R. Drill ahead to 13230'. 0=1.6(1/45, 3600 press (3500 FS), 1800 WOB, 11.86 ECD, 25-50'/hr. Conduct Wiper trip to window. Conduct mud swap on the fly Drill ahead from 13230' to 13380'. 0=1.55/1.5, 3500 press, 2450 WOB, 12.21 ECD, 50-110'/hr, TF at 90L -030830, dropped TF to 120E Conduct wiper trip to window Drill ahead from 13380' to 13480'. 0=1.55/1.45, 3700 press, 1400 WOB, 12.33 ECD, 10-50'/hr. TF at 90L. -031230 hrs, ROP dropped from 100'/hr to 10'/hr, ECD at 12.64. Mud problems. Conduct wiper trip. Start diluting new mud to drop ECD. Drill ahead from 13480' to 13540'. 0=1.4/1.3, 3500 press, 1500-2400 WOB, 12.38 ECD, 10'/hr ROP. TF held at 0 deg HS -Modify pump rates (1.2-1.4 BPM) to drop ECD (lowest attained is 12.08) -10% Siderite in returns Drill ahead from 13480' to 13566'. 0=1.4/1.3, 3500 press, 1500-2400 WOB, 12.38 ECD, 10'!hr ROP. TF held at 0 deg HS -Modify pump rates (1.2-1.4 BPM) to drop ECD (lowest attained is 12.08) Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Well Name: 1J-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date 'I From - To I Hours Task 'Code ~' NPT 9/4/2005 00:00 - 04:30 4.50 DRILL P 04:30 - 07:30 3.00 DRILL P 07:30 - 11:30 4.00 DRILL P 11:30 - 12:00 0.501 DRILL P 12:00 - 18:30 I 6.50! DRILL I P 18:30 - 20:00 I 1.501 DRILL I N I FLUD 20:00 - 22:00 2.00 DRILL N FLUD 22:00 - 00:00 2.00 DRILL N ~ FLUD 00:00 - 02:15 2.25 DRILL N ~ FLUD 02:15 - 03:30 I 1.251 DRILL I N I FLUD 03:30 - 04:00 I 0.501 DRILL I N I FLUD 04:00 - 06:15 I 2.251 DRILL I N I FLUD 06:15 - 06:30 0.25 DRILL P 06:30 - 06:45 0.25 DRILL P 06:45 - 07:15 0.50 DRILL P 07:15 - 07:30 0.25 DRILL P 07:30 - 08:00 0.50 BOPSU P 08:00 - 10:00 2.00 CASE P 10:00 - 10:30 0.50 CASE P 10:30 - 13:15 2.75 CASE P 13:15 - 13:30 0.25 CASE P 13:30 - 15:15 1.75 CASE N DFAL Spud Date: 8/13/2005 Start: 8/11/2005 End: Rig Release: 9/6/2005 Rig Number: Phase ~ Description of Operations --1 _ -- PROD2 -10%Siderite in returns PROD2 Conduct wiper to window PROD2 Drill ahead from 13566' to 13577'. Q=1.35!1.25, 3400 press (3400 FS), 2700 WOB, 12.41 ECD, 5'/hr, TF at 30R -Returns: 2-3% Siderite, 15% Shale PROD2 Shale sloughed and packed around bit. Cannot turn motor, returns nil. Work pipe up and down, increase pump rate to 1.9 (max) and pull tension on pipe. Came free, PU with pipe. PROD2 TD called at 13577'. Begin final wiper and tie in at window. +9 correction. Corrected TD at 13585'. RIH to 13520'. Lay in 30 bbl 11.1 ppg liner pill (includes 20 bbls of beads). Chase liner pill with 10.7 KW F. POOH. PROD2 Check for flow at surface- well flowing. Continues to flow- put 250 psi backpressure on well, bleeds to 75 psi, order out weighting material. Start back in hole, circulating to keep gas out of mud column. KWM needed-11.3 ppg (includes 100 psi differential "safety factor"). PROD2 RIH circulating at .5 BPM to circ. out gas. RIH to window. ECD at 14.3, SD pumps. At 7200' lose returns. PROD2 Circulate mud while waiting for mud spike to arrive on location PROD2 Circulate hole to keep gas out of column while waiting on mud to arrive PROD2 Mix 100 bbls 12.4 ppg spike fluid with 300 bbl in system- puts KW at 11.3 PROD2 Fill reel volume with 11.3 mud. Start POOH when mud turns corner PROD2 Circulate 11.3 KWF at 1.25 BPM while POOH. Losing .25 BPM. Have 200 bb{s of i 1.3 KW F made at plant. ECD at 14.5 PROD2 Conduct safety meeting for liner running- hole full PROD2 Check for flow- well dead. PROD2 LD drilling assy- bit junked- 4/4/BT/WC PROD2 Conducted safety meeting for BOPE function test PROD2 Stab BOPE test joint, function test ROPE. Works fine. RUNPRD RIH w/ 60 jts 2 3/8" (4.43# L80) Liner and liner jewelry: Indexing Shoe Solid 1 Jt- 31.5' BTT O-Ring Sub Slotted 15 Jts- 475.21' Solid 8 jts- 240.96' Slotted 10 jts- 316.92' Solid 3 jts- 94.37' Slotted 17 jts- 538.47' Solid 4 jts- 125.36' Slotted 2 jts- 63.51' TOTAL LENGTH- 1896.3' RUNPRD PU liner BHA, attach coil, RU injector RUNPRD RIH w/ Liner and CT to 13450' -No problem at window (11579') -No problem at ST KOP (12219') -No problem through shales RUNPRD Log up from 13450 to 13350'. -15' correction. RUNPRD RIH w/ liner and CT to 13490' (Bottom of Liner). Total wt. at +/- 'I 32k. Bring pumps to full rate- 1.6 at 4500 psi. No returns. Work Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To 1 J-03 1 J-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task Code' NPT _- -- 9/5/2005 13:30 - 15:15 ~ 1.75 ~ CASE N ~ DFAL 15:15 - 18:30 3.25 CASE N DFAL 18:30 - 19:00 0.50 CASE N DFAL 19:00 - 20:30 1.50 CASE N DFAL 20:30 - 21:30 1.00 CASE N DFAL 21:30 - 23:30 2.00 CASE N DFAL 23:30 - 23:45 0.25 CASE N DFAL 23:45 - 00:00 0.25 CASE N DFAL 9/6/2005 00:00 - 01:45 1.75 CASE P 01:45 - 02:00 0.25 CASE P 02:00 - 02:30 0.50 CASE P 02:30 -04:30 2.00 CASE P 04:30 - 05:00 0.50 CASE P 05:00 - 05:45 0.75 CASE P 05:45 - 07:30 1.75 CASE P 07:30 - 07:45 0.25 CASE P 07:45 - 09:00 1.25 CASE P 09:00 - 11:00 2.00 CASE P 11:00 - 13:45 2.75 CASE P 13:45 - 15:45 I 2.001 CASE I P 15:45 - 18:00 2.25 CASE P 18:00 - 20:00 2.00 CASE P 20:00 - 20:30 0.50 RIGD N SFAL Page 18 of 19 Spud Date: 8/13/2005 Start: 8/11 /2005 End: Rig Release: 9/6/2005 Rig Number: Phase Description of Operations RUNPRD pipe several times- don't lose liner wt (+/- 2000 Ibs)- not disconnected. PU to 13000'- disengage from liner. Push liner to desired depth- cannot disconnect. Work liner several times at various speeds and pump rates- cannot disconnect. PU at 120 fpm and disconnect from liner (Bottom of liner at 13478'- top of liner possibly in cased hole). Short distance from landing point and window is putting a bind on the spear and liner connection (cannot disconnect). Leave liner as is and POOH to modify spear. RUNPRD POOH w/ Liner BHA and CT. Filling hole from top. RUNPRD Remove Collett sheath off of spear RUNPRD RIH to 4300'- tool shorted out. Cannot tell depth. POOH. RUNPRD Test BHA- UOC and LOC malfunctioning. Change both out. Test BHA- good. RUNPRD RIH w/ BHA and CT RUNPRD Log down from 11425' to 14450'. Tie in. -14' correction. RUNPRD RIH w/ Liner BHA and CT. Tag Liner top at 11582'. Push liner to 11590'. Liner dragging with bare spear uphole as POOH. Push liner back down to 11590'- stays. Top of liner- 11590', Bottom of liner- 13490'. POOH. RUNPRD POOH with liner BHA and CT RUNPRD Conduct safety meeting RUNPRD LD Liner BHA and PU WS Pulling BHA RUNPRD RIH w/ WS BHA to11430' RUNPRD Log down at 2.6 fpm from 11430' to .Tie in. -14' correction. RUNPRD RIH to Top of WS (11574') at 2 fpm. Engage top of WS until motor stalls. -PU to neutral wt, stall motor for maximum torque. SD pump. -String Wt. is 25K, pull 30K, jars unintentionally go off (stroked wt. 35K). Pull 30K, jars unintentionally go off (stroked wt- 35K). Pull 34K, jars went off (stroked wt. at 34K). Pull 32K, lose circ. press but no movement. Slowly pull to 36K, no movement. Re-pull 36K, jars going off. Repeat the 36K cycle 5 more times with same result- jars going off every time. Pull 38K, no movement, jars stroking. -Ramp pump to 1.5 bpm and stall motor to ensure box tap still tight. -Pull 39K, no movement, jars stroking. Repeat twice more- second time pull free. -Free weight 25K. Open EDC, POH. RUNPRD POOH w/ WS Pulling BHA and WS. Circulating at .75 bpm. RUNPRD Conduct safety meeting RUNPRD LD WS BHA and WS, PU jet to circulate well RUNPRD RIH w/jet RUNPRD POH displacing well with seawater from 11500' to 2500', diesel from 2500' to 400'. At 400', developed pinhole in coil. Finished freeze protecting to surface. RUNPRD Drain coil. Cut connector off of coif. Cut 400' of coil off reel. Re-attach connector to coil. RUNPRD RU to BD coil with N2, BD coil, RD N2 unit RUNPRD RD coil, change out. Clean pits. Rig down stack. POST During rig down of BOP stack the chains centering the stack were released. At this point the flange connection between the Printed: 9/12/2005 10:06:03 AM • BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: 1J-03 Common Weli Name: 1J-03 Spud Date: 8/13/2005 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 9/6/2005 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~I Hours ~ Task ~ Code ~~ NPT ', Phase ~ Description of Operations 9/6/2005 ~ 20:00 - 20:30 0.50 RIGD N SFAL POST tubing hanger adapter and master valve started to leak diesel. There was 500 psi on the wellhead. The chains were retightened, and the leak stopped. The bolts at this connection were checked and found to be loose. They were tightened by hand, then hammered up. Called CPAI Wells Coordination Supervisor, Mark Chaney, and discussed. The plan forward is to set a BPV, move rig off well and let CPAI resolve the issue with the rig off location. Call for BPV. 20:30 - 21:25 0.92 RIGD N SFAL POST Notify town engineer. Notify Kuparuk spill reporting hotline of leak and repair, with no diesel getting off the tree. Wait on BPV crew. 21:25 - 21:40 0.25 RIGD N SFAL POST Hold PJSM with CPAI valve crew Re: situation with tree, and setting BPV. 21:40 - 23:00 1.33 RIGD N SFAL POST Set BPV in tubing hanger profile. Bleed pressure off lubricator, BPV held. RD Valve crew equipment. 23:00 - 00:00 1.00 RIGD P POST Continue prep for rig move. Rig released at 23:45. Further telex entries carried on 1 D-34 DIMS report. Printed: 9/12/2005 10:06:03 AM ,, Conoc Phillips Baker Hughes INTEQ ~OCT ~ `~ 2~~~ Baker Hughes INTEQ Survey Rep~r~a Oil & Gas ~ti~RT~nltiisclgtt Company: ConocoPhillips Alaska, Inc Date: 9/21/2005 Time: 11:10:17 Page: I Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3, True North Site: Pad 1J Vertical (TVD) Reference: Wellhead(116') 116.0 Well: 3 Section (VS) Reference: Well (O.OON,O.OOE,I.OOAzi) Wellpath: 1J-03L1 Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 11560.55 6452.46 TIP 11597.00 6473.45 KOP 13035.00 6528.78 TD Survey: MWD Start Date: 8/18!2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Intl Azim TVD SS TVD N/S E/W MspN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11560.66 54.74 118.61 6452.52 6336.52 1983.05 7952.01 5947964.52 566725.48 2121.53 0.00 MWD 11597.00 54.92 118.58 6473.45 6357.45 1968.83 7978.09 5947950.51 566751.67 2107.77 0.50 MWD 11630.51 62.47 106.49 6490.90 6374.90 1958.01 8004.49 5947939.89 566778.15 2097.41 38.13 MWD 11666.20 75.42 95.69 6503.73 6387.73 1951.76 8037.07 5947933.90 566810.77 2091.73 45.92 MWD 11698.61 87.25 86.79 6508.61 6392.61 1951.11 8069.01 5947933.50 566842.72 2091.64 45.46 MWD 11729.21 97,81 74.75 6507.26 6391.26 1955.98 8099.09 5947938.61 566872.76 2097.04 52.27 MWD 11761.49 98.46 58.77 6502.66 6386.66 1968.55 8128.36 5947951.40 566901.92 2110.11 49.04 MWD 11793.91. 100.25 40.96 6497.35 6381.35 1989.07 8152.72 5947972.11 566926.11 2131.05 54.48 MWD ~ 11821.77 99.03 25.20 6492.66 6376.66 2012.01 8167.65 5947995.16 566940.87 2154.25 55.94 MWD 11852.15 • 95.82 6.37 6488.70 6372.70 2040.87 8175.79 5948024:08 566948.78 2183.24 62.35 MWD 11883.65 92.71 0.70 6486.35 6370.35 2072.20 8177.72 5948055.43 566950.47 2214.61 20.48 MWD Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: Pad 1 J Site Position: Northing: 5943831.65 ft Latitude: 70 15 25.530 N From: Map Easting: 561226.77 ft . Longitude: 149 30 18.584 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 3 Slot Name: Well Position: +N/-S 2107.93 ft Northing: 5945919.64 ft Latitude: 70 15 46.258 N +E/-W -2419.99 ft Easting : 558789.96 ft Longitude: 149 31 29.006 W Position Uncertainty: 0.00 ft Wellpath: 1J-03L1 Drilled From: 1J-03 50-029-23002-60 Tie-on Depth: 11560.66 ft Current Datum: Wellhead(116') Height 116.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/29!2005 Declination: 24.24 deg Field Strength: 57605 nT Mag Dip Angle: 80.73 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 1.00 Survey Program for Definitive Wellpath Date: 7/29/2005 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 201.29 11560.66 MWD w/IFR<0-12214'> (20 1.29-12214.00) (1pAND+SAG+IFR MWD+SAG+IFR (AK) 11597.00 13035.00 MWD (11597.00-13035.00) MWD MWD -Standard a ~ ~ - ~~.~ Conoco/Phillips aker Hughes INTEQ ~ SAI Baker Hughes INTEQ Survey Report i.'~`l t~~r~ Company: ConocoPhillips Alaska, Inc Dste: 9/21/2005 Time: 11:10:17 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3, True North Site: Pad 1J Vertical (TVD) Reference: Wellhead(116') 116.0 Well: 3 Section (vS) Reference: Well (O.OON,O.OOE,I.OOAzi) Wellpath: 1J-03L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SS TVD N/S E/W ft deg deg ft ft ft ft 11914.58 90.29 354.95 6485.54 6369.54 2103.08 8176.55 11943.46 91.77 349.01 6485.02 6369.02 2131.66 8172.52 11974.34 94.53 346.68 6483.32 6367.32 2161.80 8166.03 12006.43 94.34 341.42 6480.84 6364.84 2192.55 8157.24 12044.53 95.27 335.00 6477.65 6361.65 2227.79 8143.16 12079.45 93.79 340.54 6474.89 6358.89 2260.00 8130.00 12108.39 94.13 344.86 6472.89 6356.89 2287.56 8121.41 12140.14 93.64 349.76 6470.73 6354.73 2318.45 8114.46 12178.67 93.52 356.17 6468.33 6352.33 2356.60 8109.75 12211.06 91.70 0.58 6466.85 6350.85 2388.93 8108.83 12241.47 89.83 6.02 6466.44 6350.44 2419.27 8110.58 12273.54 88.42 12.62 6466.93 6350.93 2450.90 8115.77 12310.80 87.25 19.36 6468.34 6352.34 2486.67 8126.02 12342.72 87.28 24.39 6469.87 6353.87 2516.25 8137.90 12372.86 85.30 19.00 6471.82 6355.82 2544.18 8149.01 12414.76 85.89 11.48 6475.04 6359.04 2584.46 8159.99 12444.43 87.31 5.98 6476.80 6360.80 2613.72 8164.48 12476.74 86.64 0.03 6478.51 6362.51 2645.93 8166.17 12513.14 86.30 353.44 6480.75 6364.75 2682.18 8164.10 12544.03 86.24 346.84 6482.77 6366.77 2712.53 8158.83 12575.10 86.03 340.23 6484.86 6368.86 2742.24 8150.04 12605.82 86.34 337.21 6486.91 6370.91 2770.80 8138.92 12639.08 87.47 342.25 6488.70 6372.70 2801.95 8127.42 12670.58 89.10 348.88 6489.65 6373.65 2832.42 8119.58 12702.54 86.27 354.35 6490.94 6374.94 2864.00 8114.92 12734.54 87.74 0.15 6492.61 6376.61 2895.90 8113.39 12765.80 88.23 4.66 6493.71 6377.71 2927.11 8114.70 12795.02 87.37 11.50 6494.83 6378.83 2956.00 8118.80 12826.23 82.15 16.40 6497.69 6381.69 2986.14 8126.28 12856.85 80.40 21.52 6502.33 6386.33 3014.76 8136.11 12886.55 80.84 27.92 6507.18 6391.18 3041.36 8148.36 12919.12 8427 33.13 6511.40 6395.40 3069.16 8164.76 12962.63 82.57 36.67 6516.39 6400.39 3104.61 8189.48 12989.47 79.59 38.50 6520.55 6404.55 3125.62 8205.65 13035.00 79.59 38.50 6528.78 .6412.78 3160.66 8233.53 MapN MapE ft ft 5948086.29 566949.05 5948114.84 566944.81 5948144.92 566938.08 5948175.60 566929.05 5948210.72 566914.70 5946242.82 566901.28 5948270.31 566892.49 5948301.15 566885.29 5948339.25 566880.28 5948371.57 566879.12 5948401.93 566880.63 5948433.59 566885.57 5948469.44 566895.54 5948499.10 566907.18 5948527.12 566918.08 5948567.48 566928.74 5948596.77 566933.00 5948628.99 566934.44 5948665.22 566932.09 5948695.53 566926.58 5948725.17 566917.56 5948753.63 566906.22 5948784.68 566894.48 5948815.09 566886.40 5948846.63 566881.49 5948878.52 566879.71 5948909.73 566880.78 5948938.65 566884.66 5948968.85 566891.90 5948997.54 566901.50 5949024.23 566913.54 5949052.16 566929.72 5949087.79 566954.17 5949108.92 566970.17 5949144.18 566997.77 VS DLS Tool ft deg/100ft 2245.47 20.16 MWD 2273.97 21.19 MWD 2303.99 11.69 M W D 2334.58 16.35 MWD 2369.57 16.97 MWD 2401.54 16.37 MWD 2428.95 14.94 M W D 2459.71 15.47 MWD 2497.77 16.61 MWD 2530.08 14.72 MWD 2560.45 18.91 MWD 2592.16 21.04 MWD 2628.11 18.35 MWD 2657.89 15.74 MWD 2686.01 19.02 MWD 2726.48 17.95 MWD 2755.81 19.11 MWD 2788.05 18.51 MWD 2824.26 18.09 MWD 2854.51 21.32 MWD 2884.06 21.24 MWD 2912.42 9.86 MWD 2943.36 15.51 MWD 2973.70 21.66 MWD 3005.19 19.26 MWD 3037.06 18.67 MWD 3068.28 14.50 MWD 3097.24 23.58 M W D 3127.51 22.89 MWD 3156.29 17.49 MWD 3183.11 21.31 MWD 3211.19 19.04 MWD 3247.06 8.98 MWD 3268.35 12.99 MWD 3303.88 0.00 M W D • • to 0 1 L1' ;11591 OI ;1184: 1234 ColnocoPhillips Alaska, Inc. KRU 1J-03L1 1 J-03L1 API: 500292300260 Well T : PROD An le TS: d UBING 11161. :3 soo SSSV Type: NIPPLE Orig Com letion: Angle @ TD: deg @ . , :z.ssz) Annular Fluid: Last W/O: Rev Reason: NEW WELL, GLV desi n Reference L 30' RKB Ref L Date: Last U ate: 10/4/2005 Last Ta TD: 12921 ftKB Last Ta Date: Max Hole An le: 0 d 1 Casin Strin -COMMON STRI NGS Descri lion Size To Bottom TVD Wt Grade Thread PRODUCTION 7.000 0 11255 11255 26.00 L-80 BTCM CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED _ 1 .. SURFACE 9.625 0 7784 7784 40.00 L-80 BTCM 1J-03 LINER 3.500 11101 11600 11600 9.30 L-80 SLHT Casin Strin - L1 LINER Alternatin slotted tubin & blank i e 1 Descri lion Size To Bottom TVD Wt Grade Thread L1 LINER 2.375 11591 12921 12921 4.60 L-80 STL Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 11161 11161 9.30 L-80 EU MOD Perforations Summa Interval TVD Zone Status Ft SPF Date T Comment 11843 - 12286 11843 - 12286 443 40 8/22/2005 SLOTS SLOTTED LINER 12349 - 12888 12349 - 12888 539 40 8/22/2005 SLOTS SLOTTED LINER Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3534 3534 CAMCO KBUG GLV 1.0 BK 0.156 1320 9/11!2005 2 6910 6910 CAMCO KBUG GLV 1.0 BK 0.188 1350 9/11!2005 3 9091 9091 CAMCO KBUG GLV 1.0 BK 0.188 1340 9/11/2005 ~ ~. ' 4 10229 10229 CAMCO KBUG GLV 1.0 BK 0.188 1340 9/11/2005 5 11028 11028 CAMCO MMG OV 1.5 RK 0.188 0 9/11/2005 Other lu s e ui .etc. -COMMON JEWELRY De th TVD T e Descri lion ID 539 539 NIP CAMCO'DS' NIPPLE w/NO GO PROFILE 2.875 11078 11078 NIP CAMCO'DS' NIPPLE w/NO GO PROFILE 2.812 11122 11122 LOCATOR BAKER NO GO LOCATOR 3.000 11124 11124 SEAL BAKER GBH-22 35' SEAL ASSEMBLY 3.000 11161 11161 SHOE BAKER MULE SHOE 3.000 Other lu s e ui .etc. - L1 LINER JEWELRY De th TVD ~, T e Descri lion ID 11101 11101 TIE BACK TIE BACK SLEEVE 5.250 11109 11109 PACKER BAKER 5"x7" ZXP LINER TOP PACKER 4.438 11115 11115 HANGER BAKER 5" x 7" FLEX-LOCK LINER HANGER 4.250 11129 11129 SBE BAKER SBE 80-40 4.000 11187 11187 NIP HOWCO XN NIPPLE w/2.75" NO GO 2.750 11574 11574 L2 Window 2.992 11582 11582 L1 ZXP LINER TOP PACKER FOR L1 1.250 PACKER 11590 11590 L1 Deploy Sub BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE 1.920 11597 11597 L1 Window 2.992 11598 11598 Whi stock 3.5" LSX FLOW-THRU WHIPSTOCK 0.000 Nindow -11598, ):3.000) Perf - -12286) = - Perf - 12888) - I ~ ~ - I T - ~ ~ 11 /09/04 STATE O F ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .EiE~`3..f~~g~ ~t~r~i_3_s~~t f_ :~>c:u ~~.c~~.:'...I/'t~~9:~0~~ . o~:v{~~r~t1:~~:{~.:,ta:~~.ak.us ___.... n....+ .......................................... ~3~~~~..1£?u~E'ftS~£'Et~ ~~t~{T:E~3_Sfc~t~3.:~?C.~.i~i Contractor: Nordic Rig No.: 2 DATE: 8/15/25 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Feketi-Sarber E-Mail si~~c~~~~~rl~g~E~~::die"~c?~~~?us~s<~E_ ~~~?.~_~~3 Well Name: 1J-03L1 PTD # 205-120 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1!8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 15 sec P No. Valves 14 P Full Pressure Attained 84 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4@ 2050 Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~iE~3.,~E~g:~kz;~c~s~it3_sf~kf_~X ~s Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Chuck Scheve c -Database Date 8!14/05 Time 07:45 c -Trip Rpt File Witness Ron Rice c -Ins ector Test start 08:30 Finish 14:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 8-15-05p.xls m m FRANK H. MURKOWSKI, GOVERNOR ~+ n-a/o-7~ OII, A11TD ~$ 333 W. T" AVENUE, SUITE 100 CO~-7ER~~~Ols CO~TISSIO~ ' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Sean McLaughlin FAx (so7> 27sasa2 CT Drilling engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1J-03L1 ConocoPhillips Alaska Inc. Permit No: 205-120 Surface Location: 2107' FSL, 2419' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 5216' FSL, 553' FWL, SEC. 31, T 11 N, R 11 E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new well branch of existing well KRU 1J-03, Permit No. 201-024, API No.50-029-23002-00. Production should continue to be reported as a function of the original API number stated above. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocatio suspension of the permit. Please provide at least twenty-four (24) hours no ' e f a representative of the Commission to witness any required test. Contact e C mission's petroleum field inspector at (907) 659-3607 (pager). ^~ Orman DATED this day of August, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. l STATE OF ALASKA ~` ~ ~ ~~ `~ ~y ALASKA IL AND GAS CONSERVATION CO I I ~r V L.f I~ PERMIT TO DRILL ~~~ o ~ 200 20 AAC 25.005 ~,__r_ .,~, n ,.. ., 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Dev o ^ Stratigraphic Test ^ Service ^ Dev ent Oil ultip a Zone tii$~fls ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-03L1 3. Address: Go P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13050 ~ TVD 6395 ~ 12. Field /Pool(s): Kuparuk River Field /Pool 4a. Location of Well (Governmental Section): Surface: ~ 2107 FSL 2419 FEL SEC 35 T11N R10E UM 7. Property Designation: ~ ~ ~~S~~G11 drADL 028248 ~'~, ~'~~ , , . , , , Top of Productive Horizon: 4175 FSL, 1455' FWL, SEC. 36, T11 N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 20, 2005 Total Depth: 5216 FSL, 553' FW L, SEC. 31, T11 N, R11 E, UM 9. Acres in Property: 1920 14. Distance to Nearest Property: 1975' - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558790 "' - 5945920' Zone- ASP4 10. KB Elevation (Height above GL): 116.12 feet 15. Distance to Nearest Well Within Pool 1 D-34 is offset by 1020' - 16. Deviated Wells: Kickoff Depth: 11600 -~ feet Maximum Hole Angle: 100 ° de reel 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ~ Downhole: ?$~~-T}U Surface: ~69t7~ L $~ i 8 `~"' 18. as ng rogram: Size Specifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 1455' 11595' 6356' 13050' 6395' Uncemented Slotted Liner 19. PRESENT W ELL CONDITION. SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 12214 Total Depth TVD (ft): 6816 Plugs (measured): None Effective Depth MD (ft): 12146 Effective Depth TVD (ft): 6778 Junk (measured): None Casin Len th Size Cement Volume MD TVD n r 120' 16" 00 sx Arcticset I 120' 120' 7784' 9-518" 70 sx AS Lite, 486 sx Lite Crete 7784' 4269' 11255' 7" 170 sx Class 'G' 11255' 6272' Pro i ' r 1113' 3-1/2" 56 sx Class 'G' 11101' - 12214' 6180' - 6816' Perforation Depth MD (ft): 11606' - 11843' Perforation Depth TVD (ft): 6479' - 6612' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By NameMumber. Si nature ~-~ ~ Phone 564-4387 Date ~ 3 O Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~-G~~~ API Number: 50- 029-23002-60-00 Permit A I Date: See cover letter for other requirements Conditions of Approval: Sam s R quired i i Yes ~No Mud Log Re uir ^ Yes ~,No Hy ogen ulfide Measures ~ Yes ~`_; No \ Directional Survey Required Yes ^ No Other: ~~ `~ ~ v +-~ ~Q ~s~" ccs p~.t~,~~~r~;,~ gOp ~yc,, ~ c~c~ ~ ~- ~ S . 03 to ~~ 1 Cpl ~c a-.e~'tcc~ •40~~ co J~~ ~,.c~ ~tw~, coMQwrc+~:.g~~ APPROVED BY /~ A roved B, ~"`+ 3 3 THE COMMISSION Date V Form 10-401 I~vised 004 ' ~) ~ ~ ~, ~ ',,~„ , , t ubm' In Duplicate KR~J-03L1 and 1J-03L2 Sidetracks -Co'n'ed Tubing Drilling Summary of Operations: A coiled tubing drilling unit will drill 2 laterals in producer KRU 1J-03 using the managed pressure drilling technique (MPD, see description below). These horizontal laterals will target Kuparuk C sand reserves for production. CTD Drill and Complete 1 T-03L1 & 1 T-03L2 program: Planned for August 20, 2005 Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV 2. Test Packoffs - T&IC 3. Dummy GLV's 4. MIT-IA, MIT-OA 5. Caliper 3-l/2" liner, memory GR/CCL log b. Drift tubing/liner with dummy whipstock Rig Work 7. MIRU Nordic 2. NU 7-1/16" BOPE, test. 8. Set 3-112" LSX whipstock @ 11600' md. T~~`> Pti-f~~~- ads " ~ c7 9. Mill 2.74" window and 10' of open hole. 10. Drill 3" bicenter hole horizontal lateral from window to 13050' TD targeting Kuparuk C sands. j ll. Kill well w/ brine & Complete with 2 3/8" slotted liner from TD up into the 3-1/2" liner to 11595' md. 12. Set Weatherford SS-WSRBB packer at 11582' md. 13. Stab into packer with retrievable 3-1/2" hollow whipstock, targeting top of whipstock at 11572 md. 14. Mi112.74" window and 10' of open hole. 15. Dri113" bicenter hole horizontal lateral from window to 13625' TD targeting Kuparuk C sands. 16. Kill well w/ brine & Complete with 2 3/8"slotted liner fromTD, to 5'-10' outside the 3-1/2."casing exit. 17. Retrieve hollow whipstock from L2. 18. ND BOPE. RDMO Nordic 2. Post Rig work 19. Post CTD rig -Run GLVs. Mud Program: • Step 9: chloride-based biozan brine (8.6 ppg) • Steps 10, 12-15: chloride-based Flo-Pro (8.6 ppg) • Steps 11 & 16: Potasium Formate KWF (10.8 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1J-03L1: 2 3/8", 4.6#, L-80, STL slotted liner from 11,595' and to 13,050' and • 1J-03L2: 2 3/8", 4.6#, L-80, STL slotted liner from 11,577' and to 13,625' and Casing/Liner Information 9 5/8", L-80, 40#, Burst 5750; collapse 3090 psi. 7", L-80, 26#, Burst 7240; collapse 5410 psi 3'/i", L-80, 9.3#, Burst 10159; collapse 10533 psi Well Control: • Two well bore volumes 0238 bbls) of KWF will be location during drilling operations. KR~J-03L1 and 1J-03L2 Sidetracks - C~d Tubing Drilling BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1J-03L1 & 1J-03L2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1J-03L1 is 1D-34 which is offset by 1020'. KPA boundary is 1975' away. • The nearest well to 1J-03L2 is 1D-34 which is offset by 1225'. KPA boundary is 2060' away. Logging • MWD directional and Gamma Ray will be run over all of the open hole section Hazards • L1 & L2 will both cross one mapped fault. Lost circulation risk is moderate. • Expect to encounter increasing pressure as lateral is drilled away from the mother well. • Well 1J-03 has a H25 reading of 58 ppm. Well 1D-39 has a close BHL to 1J-03 and has recorded 110 ppm H2S. All H2S monitoring equipment will be operational. Reservoir Pressure • The most recent SBHP survey (Feb 2004) was gauged at 2,976 psi after having been SI for 9 days. Expect to encounter increasing pressure as lateral is drilled away from mother well. Max. expected pressure of 3500 psi. The EMW is 10.6 ppg at 6343' TVD (L2 KOP). Max. surface pressure with gas (0.1 psi/ft) to surface is 2839 psi. Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1J-03 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). This well does not have a tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3500 psi at 6343' TVD, 10.6 ppg EMW. • Expected annular friction losses while circulating: 1090 psi (based on 80 psi/100 ft) • Planned mud density: 8.6 ppg equates to 2837 psi hydrostatic bottom hole pressure. KR~J-03L1 and 1J-03L2 Sidetracks - C~d Tubing Drilling • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3927 psi or 11.9 ppg ECD • When circulation is stopped, a minimum of 663 psi surface pressure will be applied to maintain constant BHP. ' ~ ConocoPh~il~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ^ iuTEQ ~ Company: ConocoPhillipSAlaska, Inc Date: 8/1/2005 Time: 14:29:20 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3, True North j Site: Pad 1J Vertical (TVD) Reference: Wellhead(116') 116.0 I Weil: 3 Section (VS) Reference: Wei{ (O.OON,O.OOE,I.OOAzi) Wellpath: PIan4, 1J-03L1 Survev Cakuladoo Method: Minimum Curvature Db: Qracle Field: Kuparuk River Unit North Slope, Alaska USA Map 5ystem:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 J Site Position: Northing: 5943831.65 ft Latitude: 70 15 25.530 N From: Map Fasting: 561226.77 ft Longitude: 149 30 18.584 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 3 Slot Name: Well Position: +N/-S 2107.93 ft Northing: 5945919.64 ft Latitude: 70 15 46.258 N +E/-W -2419.99 ft Fasting : 558789.96 ft Longitude: 149 31 29.006 W Position Uncertainty: 0.00 ft Wellpath: Plano, 1J-03L1 Drilled From: 1J-03 Tie-oa Depth: 11560.66 ft Current Datum: Wellhead(116') Height 116.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7!29/2005 Declination: 24.24 deg Field Strength: 57605 nT Mag Dip Angle: 80.73 deg Vertical Section: Depth From (TVD) +Ni-S +E/-W Direction ft ft ft deg I 0.00 0.00 0.00 1.00 ~I Plan: Plan #4 Date Composed: 7!29/2005 copy Lamar's plan 1J-03 N piano Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Name J-03L1 Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 1J-03L1 Target 2 1J-03L1 Target 3 J-03L1 Target 1 1J-03L1 Target 4 Annotation MD TVD ft ft 11560.55 6452.46 11600.00 6475.18 11620.00 6486.42 Description TVD Dip. Dir. ft 116.00 116.00 116.00 116.00 116.00 116.00 116.00 116.00 116.00 116.00 116.00 6460.00 _ - - - -_ Map Map +N!-S +E/-W ft ft 1951.15 8002.28 1951.15 8002.28 1845.88 8290.49 2164.86 8298.99 2751.75 8194.55 3069.82 8318.05 3347.12 8284.21 3318.77 8072.97 3029.79 8064.71 2711.44 7977.21 2088.45 8093.36 Northing Fasting ft ft 5947933.01 566775.99 5947933.01 566775.99 5947830.01 567064.99 5948149.01 567070.99 5948735.01 566961.99 5949054.01 567082.99 5949331.01 567046.99 5949301.01 566835.99 5949012.01 566$29.99 5948693.01 566744.99 5948071.01 566865.99 2621.43 8104.52 5948604.01 566872.99 6483.00 2179.01 8151.08 5948162.01 566922.99 ~--- Latitude --> <- Longitude -> Deg Min Sec Deg Min Sec 70 16 5.405 N 149 27 36.077 W 70 16 5.405 N 149 27 36.077 W 70 16 4.367 N 149 27 27.691 W 70 16 7.504 N 149 27 27.434 W 70 16 13.277 N 149 27 30.455 W 70 16 16.404 N 149 27 26.850 W 70 16 19.132 N 149 27 27.826 W 70 16 18.855 N 149 27 33.977 W 70 16 16.013 N 149 27 34.226 W 70 16 12.883 N 149 27 36.783 W 70 16 6.755 N 149 27 33.422 W 70 16 11.996 N 149 27 33.080 W 70 16 7.645 N 149 27 31.739 W 6492.00 2302.96 8032.03 5948285.01 566802.99 70 16 8.865 N 149 27 35.200 W 6510.00 3117.46 8236.41 5949101.01 567000.99 70 16 16.874 N 149 27 29.225 W TIP KOP End of 9°/100' DLS ~ ~ ~ ~ • ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INT~(1 Company: ConocoPhillip s Alaska, InC Date: 8/1/2005 Time: 14:29:20 Page: 2 Field: Kuparuk Rive r Unit Co-ordinate(NE) Reference: Welt: 3, True North ' Site: Pad 1J Vertical (TVD) Re ference: Wellttead(116') 116.0 Well: 3 Section (VS) Reference: Well (O.OON,O.OOE,1.OOAzi) ~~Welipath: PIan4, 1J-03L1 - ----- - - - Survey Calculation Method: Minimum Curvature - Db: Oracle J Annotation - --- MD TVD ft - ft - ~ 11727.26 6507.89 4 -- - - 11827,26 6490.33 5 11877.26 6485.85 6 11977.26 6484.24 End of 45°/100' DLS 12077.26 6482.99 8 12352.26 6468.36 9 12527.26 6460.11 10 12777.26 6479.83 11 12877.26 6492.93 12 13050.00 6510.53 TD Plan Section ~ Information ' MD Incl Azim TVD +N/-S +E!-W DLS Bnfld Turn TFO Target ~ ft deg deg ft ft ft deg/100ft deyl100ft deg/100ft deg 11560.66 54.74 118.61 6452.52 1983.05 7952.01 0.00 0.00 0.00 0.00 11600.00 54.94 118.57 6475.18 1967.66 7980.25 0.52 0.51 -0.10 350.70 11620.00 56.63 117.83 6486.42 1959.84 7994.83 9.00 8.47 -3.69 340.00 11727.26 100.00 95.57 6507.89 1932.15 8092.87 45.00 40.43 -20.76 330.00 11827.26 99.16 49.90 6490.33 1960.64 8184.39 45.00 -0.84 -45.66 273.00 11877.26 91.03 28.82 6485.85 1998.93 8215.72 45.00 -1 6.27 -42.16 250.00 11977.26 90.73 343.82 6484.24 2095.78 8226.45 45.00 -0.30 -45.00 270.00 12077.26 90.70 328.82 6482.99 2187.09 8186.41 15.00 -0.02 -15.00 270.00 12352.26 95.14 9.90 6468.36 2451.13 8136.58 15.00 1.61 14.94 83.00 12527.26 90.17 344.08 6460.11 2624.16 8127.40 15.00 -2.84 -14.75 259.90 12777.26 81.08 20.61 6479.83 2668.75 8136.93 15.00 -3.64 14.61 105.00 12877.26 83.95 35.46 6492.93 2955.98 8183.43 15.00 2.87 14.85 80.00 13050.00 84.56 9.43 6510.53 3113.44 8248.45 15.00 0.35 -15.07 270.00 Survey MD [ncl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11560.66 54.74 118.61 6336.52 1983.05 7952.01 5947964.52 566725.48 0.00 2121.53 0.00 MWD 11573.62 54.81 118.60 6344.00 1977.98 7961.31 5947959.52 566734.82 0.52 2116.62 350.70 1J-03L1 11575.00 54.81 118.60 6344.79 1977.44 7962.29 5947958.99 566735.81 0.52 2116.10 350.71 MWD 11600.00 54.94 118.57 6359.18 1967.66 7980.25 5947949.35 566753.84 0.52 2106.63 350.71 MWD 11613.82 56.11 118.06 6367.00 1962.25 7990.28 5947944.03 566763.91 9.00 2101.41 340.00 1J-03L1 11620.00 56.63 117.83 6370.42 1959.84 7994.83 5947941.65 566768.47 9.00 2099.07 340.29 MWD 11625.00 58.59 116.52 6373.10 1957.92 7998.58 5947939.75 566772.24 45.00 2097.21 330.00 MWD 11630.75 60.85 115.07 6376.00 1955.76 8003.05 5947937.63 566776.73 45.00 2095.13 330.71 J-03L1 T 11650.00 68.53 110.63 6384.23 1949.03 8019.08 5947931.03 566792.81 45.00 2088.68 331.44 MWD 11675.00 78.66 105.51 6391.28 1941.63 8041.85 5947923.81 566815.63 45.00 2081.68 333.34 MWD 11700.00 88.86 100.74 6394.00 1936.00 8066.02 5947918.37 566839.84 45.00 2076.48 334.79 MWD 11725.00 99.08 96.01 6392.27 1932.37 8090.65 5947914.93 566864.50 45.00 2073.28 335.31 MWD 11727.26 100.00 95.57 6391.89 1932.15 8092.87 5947914.73 566866.72 45.00 2073.09 334.98 M W D 11750.00 100.37 85.18 6387.86 1932.00 8115.22 5947914.75 566889.07 45.00 2073.34 273.00 MWD 11775.00 100.40 73.74 6383.34 1936.49 8139.35 5947919.43 566913.16 45.00 2078.25 271.16 M W D 11800.00 100.02 62.32 6378.89 1945.68 8162.13 5947928.80 566935.86 45.00 2087.84 269.09 M W D 11825.00 99.25 50.93 6374.70 1959.22 8182.67 5947942.50 566956.30 45.00 2101.73 267.06 MWD 11827.26 99.16 49.90 6374.33 1960.64 8184.39 5947943.93 566958.01 45.00 2103.18 265.15 MWD 11650.00 95.55 40.25 6371.42 1976.55 8200.33 5947959.96 566973.82 45.00 2119.37 250.00 MWD 11875.00 91.40 29.77 6369.90 1996.96 8214.62 5947980.48 566987.95 45.00 2140.02 248.76 M W D 11877.26 91.03 28.82 6369.85 1998.93 8215.72 5947982.46 566989.04 45.00 2142.01 248.12 MWD 11900.00 91.01 18.59 6369.44 2019.72 8224.85 5948003.32 566998.00 45.00 2162.96 270.00 MWD 11925.00 90.95 7.34 6369.01 2044.04 8230.45 5948027.68 567003.41 45.00 2187.37 269.82 MWD 11950.00 90.86 356.09 6368.62 2068.99 8231.20 5948052.63 567003.96 45.00 2212.33 269.62 MWD 11975.00 90.74 344.84 6368.27 2093.60 8227.06 5948077.20 566999.64 45.00 2236.86 269.45 MWD 11977.26 90.73 343.82 6368.24 2095.78 8226.45 5948079.38 566999.01 45.00 2239.03 269.29 M W D / ~ • Conoc~h~llips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report L `ITE(1 Company: ConocoPhillips Alaska, Inc Date: 8/1/2005 Time: 14:29:20 Page: 3 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well: 3, Tru e North Site: Pad 1J Vertical (TVD) Reference: Wellhead{1 16') 116.0 Well: 3 Secti on {VS) Refere nce: Welt (O.OON ,O.OOE,1.OOAzi) l Wellpath: Plano, iJ-03~1 Survey Calculation Method: Minimum Curvature Db: Oracle s Survey _ ` MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ~ I ft deg deg ft ft ft ft ft deg/100ft ft deg I 12000.00 90.72 340.41 6367.95 2117.41 8219.47 5948100.95 566991.86 15.00 2260.54 270.00 MWD 12025.00 90.72 336.66 6367.63 2140.67 8210.32 5948124.14 566982.53 15.00 2283.64 269.96 MWD 12050.00 90.71 332.91 6367.32 2163.28 8199,67 5948146.67 566971.71 15.00 2306.06 269.91 MWD 12075.00 90.70 329.16 6367.01 2185.15 8187.57 5948168.43 566959.43 15.00 2327.71 269.86 MWD 12077.26 90.70 328.82 6366.99 2187.09 8186.41 5948170.36 566958.25 15.00 2329.63 269.82 MWD 12100.00 91.11 332.20 6366.63 2206.88 8175.21 5948190.06 566946.91 15.00 2349.22 83.00 MWD 12125.00 91.57 335.93 6366.04 2229.35 8164.29 5948212.45 566935.81 15.00 2371.49 83.05 MWD 12150.00 92.01 339.65 6365.26 2252.48 8154.84 5948235.50 566926.19 15.00 2394.46 83.14 M W D 12175.00 92.45 343.38 6364.29 2276.17 8146.92 5948259.12 566918.08 15.00 2418.00 83.26 MWD 12200.00 92.87 347.11 6363.13 2300.31 8140.57 5948283.21 566911.54 15.00 2442.03 83.40 MWD 12225.00 93.28 350.84 6361.79 2324.81 8135.79 5948307.67 566906.57 15.00 2466.45 83.57 MWD 12250.00 93.68 354.58 6360.27 2349.56 8132.63 5948332.39 566903.22 15.00 2491.13 83.78 MWD 12275.00 94.07 358.32 6358.58 2374.45 8131.08 5948357.27 566901.48 15.00 2515.99 84.00 MWD 12300.00 94.43 2.06 6356.72 2399.37 8131.16 5948382.19 566901.36 15.00 2540.92 84.26 MWD 12325.00 94,78 5.81 6354.71 2424.23 8132.87 5948407.06 566902.88 15.00 2565.80 84.53 MWD 12350.00 95.11 9.56 6352.56 2448.91 8136.20 5948431.76 566906.01 15.00 2590.53 84.83 M W D 12352.26 95.14 9.90 6352.36 2451.13 8136.58 5948433.98 566906.38 15.00 2592.76 85.16 MWD 12375.00 94.53 6.53 6350.44 2473.55 8139.82 5948456.43 566909.44 15.00 2615.23 259.90 MWD 12400.00 93.85 2.83 6348.61 2498.40 8141.85 5948481.29 566911.27 15.00 2640.11 259.62 MWD 12425.00 93.14 359.14 6347.09 2523.34 8142.28 5948506.23 566911.51 15.00 2665.06 259.35 MWD 12450.00 92.43 355.45 6345.87 2548.28 8141.10 5948531.16 566910.14 15.00 2689.97 259.12 MWD 12475.00 91.71 351.77 6344.97 2573.11 8138.32 5948555.96 566907.16 15.00 2714.75 258.94 MWD 12500.00 90.98 348.09 6344.38 2597.71 8133.95 5948580.52 566902.60 15.00 2739.27 258.81 MWD 12525.00 90.24 344.41 6344.12 2621.99 8128.01 5948604.75 566896.47 15.00 2763.44 258.72 MWD 12527.26 90.17 344.08 6344.11 2624.16 8127.40 5948606.92 566895.84 15.00 2765.61 258.68 MWD 12550.00 89.29 347.38 6344.22 2646.20 8121.80 5948628.91 566890.07 15.00 2787.54 105.00 MWD 12575.00 88.32 351.00 6344.74 2670.74 8117.11 5948653.42 566885.19 15.00 2812.00 104.98 MWD 12600.00 87.36 354.63 6345.68 2695.53 8113.98 5948678.17 566881.87 15.00 2836.72 104.91 MWD 12625.00 86.41 358.26 6347.03 2720.44 8112.43 5948703.07 566880.13 15.00 2861.60 104.77 MWD 12650.00 85.48 1.90 6348.80 2745.37 8112.47 5948728.00 566879.97 15.00 2886.53 104.58 MWD 12675.00 84.56 5.55 6350.97 2770.22 8114.09 5948752.85 566881.39 15.00 2911.41 104.32 MWD 12700.00 83.66 9.21 6353.54 2794.87 8117.28 5948777.53 566884.39 15.00 2936.12 104.00 MWD 12725.00 82.79 12.89 6356.49 2819.24 8122.04 5948801.93 566888.96 15.00 2960.56 103.63 MWD 12750.00 81.95 16.57 6359.81 2843.20 8128.34 5948825.94 566$95.07 15.00 2984.62 103.19 MWD 12775.00 81.15 20.28 6363.48 2866.65 8136.15 594$849.45 566902.70 15.00 3008.21 102.70 MWD 12777.26 81.08 20.61 6363.83 2868.75 8136.93 5948851.55 566903.46 15.00 3010.32 102.16 MWD 12800.00 81.68 24.01 6367.24 2889.54 8145.46 5948872.41 566911.83 15.00 3031.26 80.00 MWD 12825.00 82.38 27.73 6370.71 2911.82 8156.26 5948894.76 566922.46 15.00 3053.72 79.49 MWD 12850.00 83.12 31.43 6373.86 2933.38 8168.50 5948916.42 566934.53 15.00 3075.49 78.98 MWD 12875.00 83.88 35.13 6376.69 2954.14 8182.13 5948937.29 566947.99 15.00 3096.49 78.51 MWD 12877.26 83.95 35.46 6376.93 2955.98 8183.43 5948939.13 566949.28 15.00 3098.35 78.09 MWD 12900.00 83.96 32.03 6379.33 2974.78 8195.99 5948958.03 566961.69 15.00 3117.36 270.00 MWD 12925.00 83.99 28.26 6381.96 2996.27 8208.47 5948979.62 566974.00 15.00 3139.07 270.36 MWD 12950.00 84.06 24.49 6384.56 3018.54 8219.52 5949001.97 566984.87 15.00 3161,53 270.76 MWD 12975.00 84.14 20.72 6387.13 3041.49 8229.08 5949025.00 566994.25 15.00 3184,65 271.15 MWD 13000.00 84.26 16.96 6389.66 3065.03 8237.11 5949048.59 567002.09 15.00 3208.32 271.54 MWD 13025.00 84.40 13.19 6392.13 3089.05 8243.57 5949072.66 567008.37 15.00 3232.45 271.92 M W D 13050.00 84.56 9.43 6394.53 311344 8248.45 5949097.09 567013.06 15.00 3256.92 272.29 MWD BP Amoco weur~re oeruu 1YM, 1J0]L~ ~~nnl~ReMq~ 1Na rr en roe ~tsw.se e.r. o.ma~.~ ~In».al~~s0 ~~amn LEGEND T azimuths to True North Plan. Ran #4 (31PIana, iao3rt) - -- - s ((Plaes, a-oaCZ~ M Ma netic North: 24.24° Geatea B Biq Michaelson Dale: ~ino05 3 (PIenS, iJ-03L2 Bt) 9 Y BAKER - PIen4. "°'t' IILiGHES by Pin wt Magnetic Field Contact Information Strength: 57605nT Bdl Michaelson Dip Angle: 80.73° rnrea: (9o~>?s~-s024 `~(] Dale:7l29/2005 Cell: (907)301-73570 ~•C Model: bggm2004 E-mail: hilLmichaelsonQinteq.com • d N 7 N C7 • • /`~} KRU 1J-03 (,~~ ConocoPhillips Alaska, Inc. 1J-03 API: 500292300200 Well T : PROD An le TS: 55 d 11569 TUBING )0-11161, SSSV Type: Nipple Orig Com letion: 3/7/2001 Angle @ TD: 57 deg @ 12214 OD:3.500, iD:z.ssz) Annular Fluid: Last W/O: Rev Reason: Adjust TBG top to 0' Reference L Ref Lo Date: Last U ate: 9/5/2004 Last Ta : 12005 TD: 12214 ftK6 Last Ta Date: 2/4/2004 Max Hole An le: 67 d 5088 ,,, Casin Strin -ALL STRING S Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED PRODUCTION 7.000 32 11255 6272 26.00 L-80 BTCM s SURFACE 9.625 35 7784 4269 40.00 L-80 BTCM LINER 3.500 11101 12214 12214 9.30 L-80 SLHT Tubin Strin -ALL Size To Bottom TVD Wt Grade Thread 3.500 0 11161 6216 9.30 EU-MOD Perforations Summa Interval TVD Zone Status Ft SPF Date T Comment J 11606 - 11616 6478 -6484 C-4 10 6 6/27/2001 APERF 2.5" HSD 60 deg BH-DP ch s 11833 - 11843 6606 - 6612 A-5 10 6 5/23/2001 IPERF 2.5" HSD, 60 deg ph, BH-DP char es Stimulations & Treatments Interval Date T Comment 11606 - 11616 6/28/2001 ,FRAC C- SAND FRAC, 58,000#, 16/20 CARBOLITE, 7 ppa ON PERFS Gas Llft Mandrel sNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3534 250 9 CAMCO KBUG CAMCO GLV 1.0 BK 0.156 1270 7/2/2001 2 6910 390 9 CAMCO KBUG CAMCO GLV 1.0 BK 0.188 1303 7/2/2001 3 9091 496 0 CAMCO KBUG CAMCO GLV 1.0 BK 0.188 1298 7/2/2001 nE BACK 4 10229 565 2 CAMCO KBUG CAMCO GLV 1.0 BK 0.250 1394 7/2/2001 ;11101-11102, 5 11028 613 6 CAMCO MMG CAMCO OV 1.5 RK 0.250 0 7/2/2001 OD:5.750) Oth er lu s ui .etc. -LINER De th TVD T e Descri lion ID 11101 6180 ~ TIE BACK TIE BACK SLEEVE 5.250 11109 6184 PKR BAKER 5"X7" ZXP LINER TOP PACKER TKC COUPLING 4.438 11115 6188 HANGER BAKER 5" X 7" FLEX-LOCK LINER HANGER W/RS NIPPLE &TKC COUPLING 4.250 11129 6196 SBE BAKER SBE 80-40 w/TCK cou lin s & XO 4.000 11187 6231 NIP HOWCO XN NIIPLE WITH 2.75" NO GO SLHT BOX X PIN 2.750 11650 6504 PLUG SAND PLUG 0.000 12146 6778 ! COLLAR BAKER LANDING COLLAR SLHT 0.000 12179 6796 COLLAR BAKER FLOAT COLLAR SLHT 0.000 12214 12214 SHOE BAKER FLOAT SHOE SLHT 0.000 SEAL Other lu s e ui .etc. -JEWELRY ;11124-11125, OD:4 000) De th TVD T e Descri lion ID . 539 538 NIP CAMCO 'DS' ni le with NO GO rofile 2.875 11078 6166 NIP CAMCO 'DS' ni le w/NO GO rofile 2.812 11122 6192 LOCATOR BAKER NO GO LOCATOR 3.000 11124 6193 SEAL BAKER GBH-22 35' Seal Assembl 3.000 11161 6216 SHOE BAKER mule shoe 3.000 General Notes Date Note 5/23/2001 30 min. of SIBHP of 3486 PSI at mid rf. I FRAC ;11606-11616) Perf ;11606-11616) ~, PLUG ;11650-12214, OD:2.992) Perf -- ;11833-'11843) _ 3 KRU 1 J-03L1 & L2 Producer -Proposed Completion 3-1/2" Camco DS nipple, 2.875" min ID at 538' MD 9.5/8" 40# L-80 @ 7784' 3-1 /2" 9.3# L-80 EUE 8rd Mod Tubing 3 '/2' Camco KBUG GLM @ 3534', 6910', 9091', & 10229' MD 3-%" Camco MMG GLM @ 11028' MD Baker ZXP Packer w/SBE @ 11109' MD 7" 26# J-55 @ 11255' MD 3-'/Z' Halliburton XN nipple, 2.75" min ID @ 11187' MD 2-3/8" liner top @ +/-11577' MD ~ / 3" openhole L2 KOP 11572' MD Window in 3-1/2" ~. -~- -+ - ~1 Weatherford retrievable hollow whipstock @ 11572' and (with plug) ~~' SS-WSRBB Packer, 1.25" ID +/-11582' MD t~~~oPhi~~ s Alaska, InC. • ~~ 2-3/8" slotted liner ~. 7 1 J-03 L2, 2-3/8" Baker deployment sub @ 11595' and a~5 "~ ~~ 630' and L1 P 11600' MD endow in 3-1/2" 3" openhole C4 San pe s 3-/z" Lsx ws otted liner 1 J-03 L1, TD @ 13050' and @ 12146' PBTD 05-24-05 Kuparuk DOBCTD BOP configurati~ I ~~ 2 CT Well 1J-03~ L1,L~ Rig Floor a ~~ [ Tree Size 7.~ ~'J.~i",SldQ _pst~;~3)E;45.;;_ ~ t116°'50CXI ps€ (t3X-4€j' or ~' i~ k176"<~000~s'{RX39}< Swab Valve SSV Master Valve Base Flan e Page 1 FW: [Fwd: Re: [Fwd: 1J-03 lateral nomenclature]] Subject: FW: [Fwd: Re: [Fwd: 1J-03 lateral nomenclature]] From: "McLaughlin, Sean M" <Sean.McLaughlin@bp.com> Date: Tue, 09 Aug 2005 01:07:27 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> Tom, Be{ow is some correspondence from Dan Venhaus regarding a tai{ that will be dri{led on 1J-03L2. From this e-mail I understand that a separate permit is not required for the short tail section of the well. l wanted to confirm this with you and let you know we are still planning on drilling the tail 0300') on the L2 Also: prep problems on other we(I has caused the 1 J-03 well to be accelerated in the schedule. The rig wi{l ready to move to 1 J-03 on Friday. What is the chance the drilling permit will be approved by then? {s there anything I can do to exiled{te the process? Thanks, Sean -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, May 24, 2005 11:05 AM To: Venhaus, Dan E Subject: [Fwd: Re: [Fwd: 1J-03 lateral nomenclature]] Dan, Here is the answer to your question. Bottomline, no permit needed but make sure the PB 1 and -70 suffix are used. Good luck drilling the well. Is this a Kuparuk well on old WS pad??? Tom Maunder, PE AOGCC -------- Original Message -------- Subject:Re: [Fwd: 1J-03 lateral nomenclature] Date:Tue, 24 May 2005 10:52:25 -0800 From:Stephen Davies <steve davies~;adin.state.ak.us> Organization:State of Alaska To:Thomas Maunder <tom. maunder(dadmin.state.ak.us> References:<42,8CAfi7B.3090004(c~~.admin. state.ak.us> Tom, Since the "old hole" may collapse and will likely not contribute much production, I agree that the "plugback" naming convention is the appropriate one to use. A separate permit for this relatively short, abandoned section of the hole is not warranted. We will however require all information from the abandoned section of hole to be labeled with the name L2PBland be assigned the -70 suffix to the API number. Thanks, Steve D. 1 of 2 8/9/2005 11:29 AM FW: [Fwd: Re: [Fwd: 1J-03 lateral nomenclature]] Thomas Maunder wrote: > Steve, > What are your thoughts. I haven't looked at the document. I am > leaning to PB1 for the "lost" portion. > Tom > -------- Original Message -------- > Subject: 1J-03 lateral nomenclature > Date: Wed, 18 May 2005 17:53:49 -0800 > From: Venhaus, Dan E <Dan.E.Venhaus:~conocophil.li~s._com> > To: tom maunder:~admin.state.ak.us > CC: Gantt, Lamar L <GanttlaLr~BP.com>, Little, Laird D. > <Laird.D.Lit,LieCt~,COi"IOCCJphll~1~75.COm>, Johnstone, Sam > <Sam.Jol~nstoneC?conacophiliips.com> > Tom, > We are planning a CTD multilateral on the 1J-03 Kuparuk producer. It > will have two main laterals, one to the north (1J-03L1) and one to the > south (1J-03L2). The existing well bore will not be P&A'd but will > continue producing via a flow-thru whipstock. I have attached a > schematic of the proposed completion. > The question I have is how to handle an "exploratory tail" near the > end of the L2 lateral to determine the C-sand thickness of this > peripheral play. We propose drilling L2 to TD tagging the top of the > C-sand, pulling uphole - 300', perform an OH sidetrack, then drilling > down to tag the bottom of the C-Sand, and completing the exploratory > tail with 2-3/8" slotted liner. The TD of the L2 and the exploratory > tail will lay over the top of each other allowing to accurately > determine sand thickness without having to account for dip and other > stratigraphic variations. Normally we would name this tail L2-Ol, but > we are not performing the sidetrack for production or reserves > purposes but for information. Oddly this exploratory tail will get > lined since we will not be able to enter the old hole or really don't > care if it collapses. Should we permit the upper lateral as L2 & > L2-O1 (2 separate permits) or L2PB1 & L2 (only 1 permit)? > Give me a call to discuss. Thanks, > «1J-03L1&L2. expl.proposed completion.doc » > Dan Venhaus > Wells/CTD Engineer > ConocoPhillips AK, Inc. > 907-263-4372 office > 907-230-0188 cell 2 of 2 8/9/2005 11:29 AM IC 1h - ~S~ ` ~ I f, ;f ~,' ~I, ~ ~,~~, y<~~. F~ a, ~ _ ,~ , ~F 1 %~ '~ ~~~~ x ~` ; , _. ,~ Proposed 1-Oil r;( 1 ~ ' ~ '~ ' 'P l Kuparuk Oil Pool _ J ' °-' ~~" `~' `~ 2051210 ,. .~ ~• ~~t~~ ~~ ~ ~~ ~'. ' ~ " ~ Confidential wells shown as red x 10-127.., Iii -,I i ~ ~ C.~ .a n .-n a '. e j ' -~ ' SFD 8/4/2005 '=-1QSA3' ~ I ~ ~~ , _, ._ ~ - _ - ,[-- a --- _-_-~ r- -t- ~I "i ~ 1D-42Lf `i g~ ., tl~-I tl~lfll lE-~ EE 2266 ~-! 10-3RL1 y 1 I ~E-~Z61•PI ~ ~} _ r 1J-168L1 i 1, :.. Jd-F6aB2 I t i Ii ---~ lC1-YR1 ~ I - _- e ID-4 } t .~. ! o w ID',1i, p C~, ~ o o_~~i ~~ 35 ~' o o ~ ~ ~~. 1a~~~ Slotted Liner o , ~' ~_ ~._ j ~~ - I o ~•., ~~ ~; ~~ , ~I-o ~t~ ~: o o . , a , f E-t 17L2 ~' ~ E~ 'b~ q~ N FPAt 4 1 ,444 2,444 3,v44 4,444 • • PERMIT TO DRILL 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~~'~ ~`~ v ~~ ~- PTD# ZU~~ J~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well I~~'~ ~~ 03 Permit No, ~i ~ ~ 2-{API No. Sz' (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pig records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECf~LIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL-490100 Well Name: KUPARUK RIV UNIT 1J-03L1 Program DEV Well bore seg ^ PTD#: 205120D Company CONOCOPHILLIPS ALASKA INC Initial Classll-ype DEV / PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached___________ _____-__--__,__-__--____--__-. NA_- _____-Multilatecalwellbore;feevraived-per20AAC25.005(e)---___-___--___--___-___-___-___--_ 2 Lease number appropriate- _ - _ - Yes _ - - Addition to_10.401:- Surf Loc _&_Top Prod Interval in-ADL_025661; TD in ADL 028248._ 3 Unique well-name andnumbe[_ __________ ________ ________- ___ YeS- --_ _ --_ -__-______ _ 4 Welllocat_edina-defnedpool___________________--_____-__--______- Yes- ___---KuparukRive[Oil Pool, governed byCon_servationOrderNo.432C_--______--__--______ 5 Well located proper distance-from drilling unit_b-oundary_ - _ - _ - Yes - Conservation Order No. 4320 contains no spacing restrictions with respe~ to drilling unit boundaries. - 6 Well located proper distance_from other wells_ _ _ _ _ _ - Yes _ Conservation Order No. 4320 has no in_terwell_spacing_restrictions_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage ayail_able in-dolling unit_ _ - - _ Yes _ - - -Conservation Order No. 4320 has_no interweltspacing_restrictions, Wellbo[e will be-more than 500' from _ . - 8 If deviated, js_wellbore plat_included _ _ - Yes _ - an external property line where-ownership or_landownership changes. - - - - ---------------------- 9 Operator only affected party Yes - - - - - - - - - 10 Operatorhas_appropriate-bond in force- ------ --- ------------ ---- - Yes- ---- -- - -----_.--------------------- -- ---- - -- ------ ---- - 11 Permit can be issued without conservation order - - Yes - Appr Date 12 Permit_can be issued without administrative_approval _ - - _ - _ - _ - - Yes _ _ - _ - . - _ - - - - - SFD 81412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put1O# in-comments)-(For- NA_ _ _ - _ _ - - -- 15 All vaells within 114-mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ - _ _ _ - - _ _ - _ - _ - - _ 16 Pre-produced injector_durat_ionofpreproductionl_essthan_3months_(Forservicewellonly)__ NA-_ __--______________________________________________________________ 17 ACMP_FindingofConsistency_hasbeenissued-fo[thisproject___--_______---__-. NA__ __________________-,___________--__-__--___-_- Engineering 18 Condu_ckorstriny_provided___--____--__--___-___--____-___.-___. NA__ _____-Con_ductorset_in mot_herbore,_1J-03_(201-024)________________-___--____--__--_ 19 Surface casing_p_rotectsall_knownUSDWs____________ _____________ ____ NA_- _____-All aquifers exempted, 40CFR-147.102_(b)_(3)._--__-__--__-_-___.-__--_.__-____-_-__ 20 CMT-voladequate_tocircul_ate-onconductor_&surf_csg________________________ NA__ -___--Surf_acesetin-Motherbore_._-____-___-_-__--__--____-___---_-.___---_-.- 21 CMT.vol_ adequate_to tie-in long string to surf csg- - NA_ - _ Production-casin se_t in_motherbore. All h drocarbon zones covered._ 9- y - - - 22 CMT_will coverall know_n_productive horizons- - - _ - No_ _ Slotted liner completion pl_anned._ - _ - _ 23 Casing designs adequate for C, T, B &-permafr-ost_ - _ _ - . - - - NA- Motherbore meets design requirements. NA-forslotted liner. - - _ _ - _ _ 24 Adequate tankage_or reserve pit - _ _ Yes - . Rig is_equippetl with steelpits.-NO resen!e_pitplanned. All waste to_approved annulus ordisposal wel_L, - 25 If a_re-dill, has-a 10-403 for abandonment been approved - - - NA_ - - - - - - 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ . -Proximity analysis performed.- Nearest well segment is Motherbore with lateral Mgving away.- _ _ - _ _ - - _ - _ - 27 Ifdiverterrequi_red, does it meet regulations___________________________ ___ NA__ ___-._BOPStack_willalready-b_einplace,__--__-___-_-___-___-___-________-_____.__- Appr Date 28 Drilling fluid-program schematic & equip list adequate_ - _ - _ _ - - Yes - - - _ _ - -Maximum expected formation pressure 10.6 EMW._ Plan to drill with_t3.6 ppg fluid and frictionlappliedpressvre. - TE 8/5!2005 29 BOPEs,,do they meet_ regulation - _ _ - _ - Yes _ . - - _ - - 2 volumes of kill weight fluid will be kept at locakion as contingency. - - - - - - . - 30 BOPE_press rating appropriate; test to-(put psig in comments)- - - - - - -- - - - - - - Yes - - . - - . MA$P calculated at 2839psi 3500_psi BOP testproposed._ 31 Choke_manifold cQmp_lies wlAPl_ RP-53 (M_ay 84)_ _ - Yes _ _ BHA will be deployed under-pressure using pipelshp rams, Well does_not have $$SV. _ _ _ - _ - _ 32 Work will occur without operation shutdown_ - _ _ _ . _ - - Yes - - - Variance requested to 20 AAC 25.036_ (d)(4) regarding routine use of BOP not compromising integrity.- - 33 Is presence-of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ H2$ has been reported in_1 J-03._ Mud should p[eclude H2S on_rig, Rig_has sensors and alarms.- _ _ _ . _ _ _ - _ - 34 Mechanical condition of wells wiihin AOR verified (Far service well only) - _ NA_ _ - ------------------------------------------------------------------- Geology 35 Permitcan be issued wlo hydrogen-sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ - _ _ _ - - KRU 1J-03 hasp[oduced 58 ppm of H2_S, H2Smonitoring-equipment wiltbe used. - - - _ _ - _ _ _ _ _ _ - _ - _ _ _ , 36 _D_ata.presented on potential overpressure zones- . . . . . . .. . .. . . . . . . Yes _ - Expected r_eseruoirpressure is 3500_psi (10.6 ppg EMW). _Well will be drilled with coiled tubing and pressure- - - Appr Date 37 Seismic analysis ofshallow gas_zones- - - - - - - - - - - _ ---- ---- KA- drilling techniques. _Th_is_will be a multilateral branch drilled from an existing well. _ - -------- SFD 8!4!2005 38 Seabed condition survey_(ifoff-shore) - - - - NA- _ _ - - - -- - - - - ~ 39 -Contact name/phone for weekly progress-reports[exploratoryonly]_-_-__-_-__.- -- NA_ _-__-__-__.__-___-__-______--___-__-__ __-__-__--_---_--. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner to ~~~ ~ J g/s ~~,~t ~.s -~s ~9 ~- • :~ ., Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~~~is~~ • ~;~~ti~ **** REEL HEADER **** MWD 06/11/17 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/08/22 958647 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11603.0000: Starting Depth STOP.FT 13037.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, .Inc. WELL. WELL: 1J-03L1 FLD FIELD: Kuparuk River Unit LOC.. LOCATION: 70 deg 15' 46.258"N 149 deg 31' 29.006"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 22-Aug-05 API API NYUMBER: 500292300260 Parameter Information Block #MNEM.UNIT Value Description SECT. 35 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~-W ~ ~~d ~ ~L~c7Jr~o (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1J-03 through a milled window in 3 1/2" liner. Top of Window 11599.0 ft.MD (6358.6 ft.SSTVD) Bottom of Window 11603.3 ft.MD (6361.0 ft.SSTVD) (8) The interval from 13007 ft.to 13037 ft.MD (6408 ft.to 6415 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1J-03 at 11433 ft.MD (6262.5 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MVJD . 0 01 1024 63 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU WDFN 1J-03L1 5.Xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1J-03L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP • GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing:. 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 35 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 44 Minimum record length: 54 Maximum record length: 4124 11603.000000 13037.000000 0.500000 feet records... bytes bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1J-03L1.xtf LCC 150 CN ConocoPhillips Alaska In wN 1J-03L1 FN Kuparuk River Unit ~J COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log. Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 70 Tape File Start Depth = 11587.000000 Tape File End Depth = 13037.750000 Tape File Level Spacing = 0.250000 Tape .File Depth Units = feet **** FILE TRAILER **** Tape 5ubfile: 3 79 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/08/22 958647 01 • • **** REEL TRAILER **** MWD 06/11/17 BHI O1 Tape Subfile: 4 2 records... Minimum record. length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP 11603.0000 97.3300 1.5800 11603.5000 99.9600 3.3300 11700.0000 117.3100 39.1900 11800.0000 112...8400 42.4100 11900.0000 127.8300 31.2900 12000.0000 132.3000 40.7500 12100.0000 109.6900 24.0000 12200.0000 120.9900 22.6300 12300.0000 120.4700 38.1300 12400.0000 111.5300 42.7500 12500.0000 112.8400 27.1200 12600.0000 140.0600 9.7100 12700.0000 98.1100 32.9800 12800.0000 102.0600 50.0700 12900.0000 81.5500 6.4800 13000.0000 113.8900 21.6100 13037.0000 -999.2500 10.6800 Tape File Start Depth = 11603.000000 Tape File End Depth = 13037.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 11587.0000 70.5000 -999.2500 11587.2500 65.2400 -999.2500 11600.0000 74.4500 138.0000 11700.0000 117.3100 39.1900 11800.0000 112.8400 42.4100 11900.0000 127.8300 31.2900 12000.0000 132.3000 40.7500 12100.0000 109.6900 24.0000 12200.0000 120.9900 22.6300 12300.0000 120.4700 38.1300 12400.0000 111.5300 42.7500 12500.0000 112.8400 27.1200 12600.0000 140.0600 9.7100 12700.0000 98.1100 32.9800 12800.0000 102.0600 50.0700 12900.0000 81.5500 6.4800 13000.0000 113.8900 21.6100 13037.7500 -999.2500 -999.2500 Tape File Start Depth = 11587.000000 Tape File End Depth = 13037.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape Subfile 4 is type: LIS ^; • • **** REEL HEADER **** MWD 06/10/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/08/22 958647 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!! !!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 11603.0000: Starting Depth STOP.FT 13037.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1J-03L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 15' 46.258"N 149 deg 31' 29.006"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 22-Aug-05 API API NYUMBER: 500292300260 Parameter Information Block #MNEM.UNIT Value Description SECT. 35 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks yes - r~ ~ ~~Iao~ • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit) , a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC {Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1J-03 through a milled window in 3 1/2" liner. Top of Window 11599.0 ft.MD (6358.6 ft.SSTVD) Bottom of Window 11603.3 ft.MD (6361.0 ft.SSTVD) (8) The interval from 13007 ft.to 13037 ft.MD (6408 ft.to 6415 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1J-03 at 11433 ft.MD (6262.5 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 63 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1J-03L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1J-03L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP • • ---------------------------------------------------- GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 4 Total Data Records: 23 Tape File Start Depth = 11603.000000 Tape File End Depth = 13037.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 31 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1J-03L1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1J-03L1 FN Kuparuk River Unit COUN North Slope STAT Alaska • • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 4 Total Data Records: 46 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 54 Minimum record length: 54 Maximum record length: 4124 11587.000000 13037.750000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD 05/08/22 958647 01 • • **** REEL TRAILER **** MWD 06/10/14 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS r~ Tape Subfile 2 is type: LIS DEPTH GR 11603.0000 97.3300 11603.5000 99.9600 11700.0000 117.3100 11800.0000 112.8400 11900.0000 127.8300 12000.0000 132.3000 12100.0000 109.6900 12200.0000 120.9900 12300.0000 120.4700 12400.0000 111.5300 12500.0000 112.8400 12600.0000 140.0600 12700.0000 98.1100 12800.0000 102.0600 12900.0000 81.5500 13000.0000 113.8900 13037.0000 -999.2500 Tape File Start Depth = 11603.000000 Tape File End Depth = 13037.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GRAX 11587.0000 70.5000 11587.2500 65.2400 11600.0000 74.4500 11700.0000 117.3100 11800.0000 112.8400 11900.0000 127.8300 12000.0000 132.3000 12100.0000 109.6900 12200.0000 120.9900 12300.0000 120.4700 12400.0000 111.5300 12500.0000 112.8400 12600.0000 140.0600 12700.0000 98.1100 12800.0000 102.0600 12900.0000 81.5500 13000.0000 113.8900 13037.7500 -999.2500 Tape File Start Depth = 11587.000000 Tape File End Depth = 13037.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • Tape Subfile 4 is type: LIS