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Home My WebLink About205-047 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aOS - 0 If 7 Well History File Identifier D Two-sided 11111111111111 11111 Production Scanning Stage 1 Page Count from Scanned File: .!J-!l-- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY CMar;0 Date1h-/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) RES CAN ~olor Items: ~reYSCale Items: l ~ DIGITAL DATA D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: NOTES: Date q Ilf/O 7 Date? t l/-jo7 d- foo BY: ~ Project Proofing BY: r:- Mari~ Scanning Preparation BY: Date: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: m£ ,;"111111111111111 mP 151 + ~ = TOTAL PAGES 76 (Count does not include cover sheet) 151 1111111111111111111 NO ,~ r11P NO 151 11111111111111 11111 ReScanned BY: Date: 151 Maria Comments about this file: 11/1111111111111111 Quality Checked 11111111111I111111I 10/6/2005 Well History File Cover Page.doc Company Well Name Date ConocoPhillips, Alaska, Inc. 1D-37L2P61 f t~~~ ~~:.~ , `':~,1. ~`~ ~ ~vi7J s~~~ 12/8/2009 rev- ~~ _ ~:~ 2.()69 ~~ Cpl . ~ ., ~. C~>r1 " ~` ~~~ BAKER MY~HES INTEL • Page 1 of 4 Company ConocoPhillips, Alaska, Inc. ~_,~, -_ Well Name 1D-37L2 &; ~;;.. ;: •. Y 7~~;_:~a Date 1218/2009 ~~ ~%~~~~`"~' ~` rrs~ BAKER N~IGHES INTEQ n u Page 1 of 4 ~`R`~a` .+ .._ ~,~; DAD NOT PLACE .ANY NEW MATERIAL UNDER THIS- GAGE F:\L.aserFiche\CWrPgs_Inserts\Microfilm Marker.doc Permit to Drill 2050470 MD 13087 02 Æl~ DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 ~/J.. Â Å J.l¡ ~7 API No. 50-029-22992-61-00 Well Name/No. KUPARUK RIV UNIT 1D-37L2 Operator CONOCOPHILLlPS ALASKA INC TVD 6496 Completion Date 7/2/2005 /' UIC N Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Mud Log No Directional Survey ~ ------ (data taken from Logs Portion of Master Well Data Maint Interval - OH/ Start Stop CH Received Comments 0 13087 Open 7/14/2005 I 0 11546 Open 7/14/2005 PB1 10600 13086 Open 8/30/2006 GR w/Graphics 10594 13087 Open 8/30/2006 GR MD 1-Jul-2005 10594 13087 Open 8/30/2006 GR TVD 1-Jul-2005 10594 11546 Open 8/30/2006 PB1 GR MD 10594 11546 Open 8/30/2006 PBI GRND j 10600 13086 Open 11/29/2006 GR, ROP, w/Graphics 10600 11546 Open 11/29/2006 PB1 , ROP, GR w/Graphics 10594 11546 Open 8/30/2006 PB1 GR Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD / GR Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc D Asc C Lis C Lis C Lis C Lis v44093 14093 14093 14092 14092 {)A258 ~59 ./14.092 Name Directional Survey Directional Survey Gamma Ray Gamma Ray Gamma Ray Gamma Ray Gamma Ray Gamma Ray Gamma Ray Gamma Ray Log Log Scale Media Run No 25 Blu 25 Blu Well Cores/Samples Information: Name - Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMA1{0N Well Cored? Y /~ Chips Received? ...:i.1.J>I.-" Analysis ~ Received? Daily History Received? (jYN ~/N Formation Tops Comments: DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050470 Well Name/No. KUPARUK RIV UNIT 1D-37L2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-22992-61-00 MD 13087 TVD 6496 Completion Date 7/2/2005 Completion Status 1-01L Current Status 1-01L UIC N Compliance Reviewed By: )L Date: 11 ~ ~') e -- . Transmittal Form . r&11I BAKER HUGHES [I ...,,,"·,....n..',,,, I -<'.-- I "'''"- ....,'~");:. ."n.'''.. ; :;,~ ::.:;:' ~ ... ,..,.: ...., I~'-'~~'~:~:";-~"I I:::':::" R~_," r ...., I ¡ i ~ I : I ¡ I ¡ I ¡ j INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: ID-37L2 Anchorage GEOScience Center 11 Contains the following: REVISED 1 LDWG Compact Disc (Includes Graphic Image files) II 1 LDWG lister summary ! , , LAC Job#: 919593 ,¡ ij ,¡ II ¡¡ ~ ¡ II II :1 ¡ ;¡ ¡I 11 II II H II ¡¡ !I Sent By: Deepa Joglekar Received By: C' lJJ'-- t<Ëð~f\}~ ,~~l~$~~tjC1~ ,~ -3:]$ Gvn~;3. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING &áQI2'JÈURNING OR FAXING YOUR COPY FAX: (907) 267-6623 9ó6-- 0'11 1"'-( g.S- 'ß' Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 : ì ! ¡ I I' ..- , E:::JS i.....'" ~:J7,~~'.;:'J~ -"1 _ ",0Il'": i I:'· ~;'~~:~':. ~,,"I _n,. .:.~::: '. ., . .,¡ I'" ." -,-".,-" ,----,---.. __H_ -"-~ ¡';f:ê~Y::~ -'''-''''''~ {.'i i ._,.. ¡- --, l:~-~-:: I ~_.. nm I-jt'.---" I; [';;:------' ,:.---- , ;! ¡.k. .:~ì¿_7___ ::":',----- t :~_ . Transmittal Form . r&11I BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1D-37L2PB1 Contains the following: REVISED ,; n II II II I¡ II it 11 ¡! ¡¡ 11 ¡¡ !! !í Ii i¡ I! 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 'I I. LAC Job#: 919593 Sent By: Deepa JO,lekar Received By: (! .1JI'''--- n i! ii n ¡¡ II ¡¡ ¡¡ ;¡ DateRt!C~IE Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RtTtmNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 gos--D41- I Lf 9:)4 II _..,.~mm.. I ,~",,"'-'" """<..,.",."':''';::--.",,",,. I' :~: ::;., . ,. I~····, .;",;:~~,.......:,.~"I ." "" .... -"- - '.. ., .~. .-,...., ::"~._,' .,.....' ::-~:::::=: !~:~. ~;;:~:::: ~:::: I ¡'Ú:~.~-i:;·ii i ~',~,<-,-,:~ I·······,·, L__'~~_".!._-'- ~---,.,,- I i f:,~· I I! 1:,::----- ~, 1:1£ If [_\"'~''--c'-',~ '" ' I _ ¡ ,. ., I~ n(~' RiF r- 1-:'i:'F':(,}, .):-- ·'.IOJ'_ I·: ~ j. ------------------- . Transmittal Form . '&ill BAKER HUGHES I ...,.........,... YOU ',J\)' F'"'---'[7''''' g~:_,_.~...!l~;·~ .. ....( ....., -,~ _.. _ u. on .'W.-- :f'" '·~-¿;---"-~~·-·:----."'õ·a· INTEQ '-'ot'r'~"""', _~ - .... -I ''', :':::.< F~«,~ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 ~;~~~rage, Alaska RE C E \ VE 0 AUG 3 0 [006 C mmission >\1a$ka Oil & Gas Cons. 0 Anchorage Attention: Helen Warman Reference: ID-37L2 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary I blueline - GR Measured Depth Log 1 blueline - GR TVD Log II LAC Job#: 919593 Sent By: Deepa Joglekar Received By: ~ Date: Aug.23, 2006 Date: &-'/801 (]h PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 é)O~ - o~/'?- It{ o£:}3 ..~... ~~-~-- ",..,.... ~ ;,>:" _~. _ oz "1 m._,· ....." ........ ... h "~";""""""'" _..; _ u .., ....'. -.... :~::" ': ~ jí~~l'~-·'"~·- t')·; ." Ur1Hnmu, 1 i::ì¡;;: !. fW¡¡::rn : ;: ;::¡.::: ~i ! I ~;r:'¡¡" i ~c~ Hlij\~ I···n :+['11#;;-'; I . 1.[ \, ;fI~j I".., ....... ·.·iW'i1t-: ~-- '-+-H~±t:;~~~n~ ~~¡'i!åû ¡ ~ >~m_ :iÜt:~.j : .....,- : ,';""'1, "'I'" a STATE OF ALASKA . ALASKA'" AND GAS CONSERVATION COM 'ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission A h RECEIVED AUG 0 4 2005 nc orage 1a. Well Status: Da Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 Da Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 7/2/2005 .- 205-047 3. Address: 6. Date Spudded 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6/22/2005 .... 50- 029-22992-61-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ,¿ 6/30/2005 - KUP 1D-37L2 492' FNL, 421' FEL, SEC. 23, T11 N, R1OE, UM -'b 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: ~ ~ 5268' FNL, 4090' FWL, SEC. 24, T11 N, E, UM 104.9' Kuparuk River Unit Total Depth: 9. Plug Back Depth (MD+ TVD) 5203' FNL, 1199' FWL, SEC. 19, T11N, R11E, UM 13087 + 6496 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 560670 -- y- 5959174 - Zone- ASP4 , 13087 + 6496 .- Ft ADL 028243 TPI: x- 565223 y- 5954436 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 567611 - y- 5954522- Zone- ASP4 (Nipple) 522' MD -- --~+ ----~-- - -- ---. ------ 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey Da Yes DNo NI A MSL 1418' 21. Logs Run: ~ t.J w...L.w IO,,>t7¥"rnÞ I "'.,ýß' TV£> MWD I GR .."I/) SJ·S· ) 22. CASING, LINER AND CEMENTING RECORD CASING SETTING LJEPTH MD ~ETTING DEPTH TVO HoLE , AMOUN't SIZE WT. PEA FT. GRADE ToP BOTTOM TOP BOTTOM SIZE PULLED 20" 91.5# H-40 Surface 121' Surface 121' 24" 460 sx Arcticset I 9-5/8" 40# L-80 Surface 5081' Surface 4380' 12-1/4" 612 sx AS III LW, 403 sx LiteCrete 7" 26# J-55 Surface 10093' Surface 6262' 8-1/2" 170 sx Class 'G' 3-1/2" 9.3# L-80 9920' 10594' 6199' 6448' 6-1/8" 243 sx Class 'G' 2-3/8" 4.4# L-80 10611' 12988' 6454' 6504' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. 1 JBING Bottom 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 9961' 9927' MD TVD MD TVD 10611' -10928' 6454' - 6485' 25. iACro,J ""v, C+I" 11054' - 12037' 6481' - 6519' 12163' - 12955' 6526' - 6505' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with 22 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 7, 2005 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO 7/19/2005 24 TEST PERIOD .. 3,929 5,084 1,380 176 1,232 Flow Tubing Casing Pressure CALCULATED + Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 353 24-HoUR RATE 3,929 5,084 1,380 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". r- COMPLETION None RBDMS BFl AUG 0 8 2005 DATE ...:z. 2 '0> VERI;tD ('i[)!r:~i!\! l\ f L I. Form 10-407 Revised 12/2003 " ' t ' f SIDE ¡ \: r.c, ! CONTINUED ON 'REVEFlSE ~ I·~ i- ~ 2,8. GEOLOGIC MARKERS 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Kuparuk C (From 1 D-37) 10573' 6440' None Kuparuk C4 13057' 6499' 30. List of Attachments: Summary of 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 0 .-Dl{ "'OS KUP 1 D-37L2 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Aras Worthington, 240-5780 205-047 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only BP Operations Summary Report Page 1 of21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/212005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/11/2005 11:00 - 20:15 9.25 MOB P PRE Move from 1 F-01 to 1 D-37 20:15 - 20:30 0.25 MOB P PRE PJSM: Hold Pad inspection with DSO. Review procedures and job assignments for moving over well. 20:30 - 21 :00 0.50 MOB P PRE Spot rig over well and level up. Rig Accepted at 2100 hrs 6-11-2005 21 :00 - 00:00 3.00 BOPSU PRE Remove tree cap and install BOP stack. Change out BOP rams to 2". (annular, B/S, 2" Combi's, 2-3/8" Combi's, 2" Combi's) Lift and pin 2" coil reel # 12073 6/12/2005 00:00 - 03:00 3.00 BOPSU PRE Continue NU BOPE. Secure 2" coil reel. MU inner reel hardline, e-line connection. 03:00 - 1 0:30 7.50 BOPSU PRE Test BOPE. 250psi low /3500psi high for 5 min each. Witnessing by AOGCC waived. MU pull cable for stabbing coil to injector. Change out rollers on gooseneck to 2". 10:30 - 13:30 3.00 RIGU P PRE Fin prep injector and gooseneck for 2" CT 13:30 - 15:00 1.50 RIGU P PRE Pull CT over pipeshed and stab into injector. Stab onto well 15:00 - 20:00 5.00 RIGU P PRE Fill CT w/ rig water, then pump slack forward. Then reverse slack back. Cut off 40' of CT before finding wire. Headup with BHi upper quick connector. PT to 4K. Meg test. 20:00 - 20:15 0.25 WHIP P WEXIT PJSM: Review Pressure Deployment procedures and hazards. 20:15 - 23:00 2.75 WHIP P WEXIT Check WHP 1175psi. PU BHA #1 following P. Deply procedures. PT lubricator to 1300psi. RIH wI BHA and close 2-3/8" combi's. Setback lubricator. PU stab injector and PT to 1300psi. Open combi's. 1088psi on SLB gauge. 23:00 - 00:00 1.00 WHIP ip WEXIT RIH pumping min rate. Maintaining 1200psi on well. No returns 6/13/2005 00:00 - 01 :00 1.00 WHIP Ip WEXIT RIH to 10900'. I 01 :00 - 03:00 2.00 WHIP P WEXIT Displace tbg with 9.1 ppg used Flo-Pro. q=1.8bpm initial ann 3535psi + holding 600psi at surface. Gas cut mud to surface. Ann slowly increasing after 3 hole volumes annular at 3900psi 11.82 ECD + holding 400psi at surface MMout 5.2ppg. After 5 hole vol slow rate to 1 bpm increase whp to 700psi order additional mud. 03:00 - 03:35 0.58 WHIP P WEXIT Circulate with bit at 10500' @ 1 bpm in / .5bpm out annular 3900psi holding 700psi at surface 12.0 ECD returns 6.8ppg gas cut mud. Total volume pumped @ 0300hrs 265bbls. 03:35 - 04:50 1.25 WHIP P WEXIT Take returns back into rig tanks 9.2ppg gas cut. In/Out 1.01.6 whp=400 ann=3900. Dropping WHP in stages to 250psi .63/.49 ECD 11.18 ann=3670. Taking on more mud. 04:50 - 06:45 1.92 WHIP P WEXIT TOH following pressure schedule. 06:45 - 07:00 0.25 WHIP P WEXIT Tag up holding 700 psi. Final 'out' density was 7.3 ppg and slightly gassy. WHP fell to 350 psi while conducting safety mtg on pressure undeploy 07:00 - 08:45 1.75 WHIP P WEXIT Pressure undeploy wI 340 psi whp 08:45 - 09:00 0.25 WHIP P WEXIT MU WIS LSX WS assy. Install 3 RA tags 09:00 - 10:30 1.50 WHIP P WEXIT Pressure deploy WS assy w/180 psi PVT 134 10:30 - 13:00 2.50 WHIP P WEXIT RIH wI BHA #2 circ thru open EDC 0.311200 wI 200 psi bp PVT 132 13:00 - 14:45 1.75 WHIP P WEXIT Log tie-in down 0.3/1400/200 from 10500' to 10650', corr -15.9' to GR at 10575'. Switch to CCL mode and log down from 10650' to 10800'. See collars/centralizers at 1 0733' and 10749.5' Also see 10705'-720' perfs off depth by 3' high PVT 103 14:45 - 15:15 0.50 WHIP P WEXIT Park at 10747.3' bottom of tool. Close EDC. Pressure up to 4255 psi and set WS at 5A. Printed: 7/1112005 10:20:33 AM BP Ope~ationsSummary Report Page 2 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/13/2005 14:45 - 15:15 0.50 WHIP P WEXIT Preliminary depths of WS are TOWS 10738', BOWS 10743', RA marker 10743.7' 15:15 - 17:30 2.25 WHIP P WEXIT POOH wi setting assy w/ choke closed filling CT at 0.3-0.5 bpm to maintain 200-500 psi WHP 17:30 - 18:00 0.50 WHIP P WEXIT Trap 350 psi. Pressure undeploy. LD WS setting assy 18:00 -18:15 0.25 WHIP P WEXIT PJSM with relief crews. Review Undeployment procedures. 18:15 - 19:45 1.50 WHIP P WEXIT Finish undeploying whipstock setting BHA. 19:45 - 20:15 0.50 WHIP P WEXIT Prep to P/U BHA. 20:15 - 20:25 0.17 WHIP P WEXIT PJSM: review pressure deployment steps. 20:25 - 21 :40 1.25 WHIP P WEXIT Pressure deploy BHA #2 21:40 - 00:00 2.33 WHIP P WEXIT RIH min rate with open EDC. WHP at start was 160psi. I ' Returns are gas cut mud. Slowly returning to 9.1 Tagged WS lat 10757' make -19' correction. 6/14/2005 00:00 - 06:00 6.00 STWHIP P IWEXIT Tag WS. Paint flag on coil. 0=1.70 outmm=.96 FS=3700psi I Ann= 3750psi ECD= 11.34 Swaco choke fully open. Start I milling window f/1 0738' 100-250psi motorwork. I Swapping hole over to new 8.6ppg Flo-Pro. With new mud to I Isuriace 0= 1.7/1.2 Ann= 3774 ECD 11.39 250-350psi motorwork ¡At 0500 still having losses +1- 25bbls/hr to formation. 1.7/1.4 At 10743.5' taking 100psi less differential pressure to drill same rate so this could be bottom of window and starting to drill formation. 06:00 - 08: 15 2.25 STWHIP P WEXIT Drill formation 1.7/1.3/3650 w/1-3k wob, 50-100 psi diff, 3790 DHP, 11.44 ECD. Drilled to 10753' 08: 15 - 09:00 0.75 STWHIP P WEXIT Ream and back ream window area 3 times, then drift dry, clean PVT 379 09:00 - 11 :00 2.00 STWHIP P WEXIT POOH circ thru mill at 1.5/2800 following pressure schedule and tag up at 400 psi. Hold PJSM concurrent on undeploy PVT 333 11 :00 - 12:15 1.25 STWHIP P WEXIT Pressure undeploy wI 380 psi whp. LD MWD assy and WIS window milling tools Rig evacuation drill 12:15 - 14:30 2.25 DRILL P PROD1 Reconfigue MWD for drilling. MU HCC bi bit on 1.6 deg motor. Pressure deploy wI 320 psi WHP PVT 333 14:30 - 16:15 1.75 DRILL P PROD1 RIH w/ BHA #4 circ 0.3/1300 holding 350 psi bp 16:15 - 16:40 0.42 DRILL P PROD1 Log tie-in at 10570'. -13' 16:40 - 16:45 0.08 DRILL P PROD1 RIH tag bottom at 10757'. 16:45 - 19:10 2.42 DRILL P PROD1 Bring on pump to 1.70 open Swaco choke. 0= 1.62 initial returns 1.06 freespin= 3260psi ann= 3712 EDC= 11.22 Directionally drill f/1 0757' 2-300psi motorwork 2k wob. Returns slowty increasing 2 10772' 1.61/1.21 Ann=3744 EDC= 11.30 19:10 - 20:55 1.75 DRILL P PROD1 Well landed. 84 degs Inc. Doglegs are higher than we desire with this 1.6 deg motor. (20 deg +). POOH to pick up 1.1 deg motor. SD pumps thru window. Open EDC. POOH pumping at full rate and following pressure schedule. IAP=315 psi, OAP=O psi. Electronic and mechanical gauges confirm the same pressure. 20:55 - 21:15 0.33 DRILL P PROD1 PJSM re: undeployand redeploying BHA. 21:15-22:15 1.00 DRILL P PROD1 Undeploy drilling BHA #4. 22:15 - 22:45 0.50 DRILL P PROD1 Adjust motor AKO to 1.1 deg from 1.6 deg. Check bit. Bit graded 0,0. Change O-rings in lower quick connect. 22:45 - 23:45 1.00 DRILL P PROD1 Redeploy drilling BHA #5. Printed: 7/1112005 10:20:33 AM BP Operations Summary Report Page 3 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/14/2005 23:45 - 0.00 DRILL P PROD1 Rlh with BHA #5. 6/15/2005 00:00 - 02:15 2.25 DRILL P PROD1 Continue RIH with drilling BHA #5 to drill lateral section of hole. 02: 15 - 02:30 0.25 DRILL P PROD1 Log tie in pass. Make -13' correction. Tied in depth of RA tag is 10746.5'. 02:30 - 05:30 3.00 I DRILL P PROD1 Resume drilling. Pit vol=437 bbls. 1.61/1.16/3280 psi free spin. IAP=310 psi, OAP=O psi. ROP 80 fph. Ann Pressure is 3770 psi, ECD=11.34 psi. 05:30 - 06:25 0.92 DRILL P PROD1 Continue to drill lateral section as per geo's plan. 1.62/1.27/3500 psi. Pit vol=365 bbls. 06:25 - 06:45 0.33 DRILL P PROD1 Wiper trip to window. 06:45 - 10:00 3.25 DRILL P PROD1 Directionally drill ahead f/11 000' 1.63/1.35 3500psi. At 11085' returns dropped to .80 slowly climbing back then further losses at 11110' returns now at .57 10:00 - 10:30 0.50 DRILL P PROD1 Wiper trip to window. 10:30 - 13:25 2.92 DRILL P PROD1 Directionally drill ahead f/ 11150' retums continue to be 50% Q= 1.50 3040psi Ann=3677 EDC= 11.07 13:25 - 14:00 0.58 DRILL P PROD1 Wiper trip to window. Clean hole 14:00 - 16:151 2.25 ¡DRILL P PROD1 I Drill ahead f/ 11300'. Q= 1.531 .84 31 OOpsi 2-300psi MW I 1 WOB= 2-4k Ann= 3710 ECD=11.17 returns slowly increasing 16:15 - 17:10 0.92 DRILL P PROD1 Wiper trip PU wt 22.7k to 10760' Tie-in to RA tag correct -1.5' 17:10 - 18:00 0.83 DRILL P PROD1 Drill ahead f/11450' Q= 1.5 out rate .753100 free-spin Ann= 3734 EDC= 11.27 2-3k wob 80-100'/hr 18:00 - 19:10 1.17 DRILL P PROD1 Drilling ahead. 1.5/0.8/3290 psi. ROP=80 fph. EDC=11.2 ppg. CT string weight=4500 Ibs. WOB=700 Ibs. Pit vol=390 bbls. IAP=220 psi, OAP=O psi. 19:10 - 20:25 1.25 DRILL P PROD1 Drilled into a loss zone at 11599'. 1.6/0.2/3100 psi. Make a long wiper trip up inside the tubing to give this zone a chance to heal up, and to get above the cuttings uphole from us now. Clean PU off bottom at 25 klbs. Clean in open hole. SD pumps thru window. Open EDC. Pump at full rate while PUH in tubing to 9700'. 1.97/0.64/3200 psi. ECD=10.63 ppg, Annular pressure = 3475 psi. Call for a 2nd vac truck to shuttle mud. Run back to window clean, 1.9/0.6/3400 psi. 20:25 - 20:40 0.25 DRILL P PROD1 Log tie in pass over RA tag. Make +2.5' correction. 20:40 - 22:30 1.83 DRILL P PROD1 Resume drilling. Free spin 3050 psi at 1.55 bpm. Drilling ahead at 1.55/0.49/3180 psi. Pit vol = 294 bbls. 2 vac trucks supporting the rig. One hauling fluid from Deadhorse, 1 shuttling fluid from the upright tanks. Losing about 60 bbls/hr. ROP 85-100 fph. 22:30 - 23:10 0.67 DRILL P PROD1 Retums have dropped back off a bit. Drilling at 1.54/0.35/3150 psi. Pit volume=206 bbls. Lost 88 bbls in last 65 minutes. 23:10 - 00:00 0.83 DRILL P PROD1 Conservative wiper trip to window. Nothing seen to indicate need for one, but going to do one anyway to check hole conditions, and to give Geo's a chance to sort our our plan forward. They need to talk to town to discuss. Clean PU off bottom at 24 klbs. Clean to the window. 6/16/2005 00:00 - 00:25 0.42 DRILL P PROD1 Continue wiper trip back in hole from window. Smooth, no problems. 00:25 - 03:30 3.08 DRILL P PROD1 Resume drilling. Free spin = 3000 psi at 1.5 bpm. Drilling at 1.54/0.47/3170 psi. 40 fph. IAP=180 psi, OAP=O psi. ECD=10.82 ppg, Annular pressure = 3587 psi. 03:30 - 05:50 2.33 DRILL P PROD1 Continue drilling. In some high gamma rock with slow drilling. Current pit volume = 440 bbls. Drilling at 1.53/0.55/3500 psi. Printed: 7/1112005 10:20:33 AM BP Operations Summary Report Page 4 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/16/2005 03:30 - 05:50 2.33 DRILL P PROD1 ROP=35 fph. IAP=177 psi, OAP=O psi. ECD=10.88 ppg, Annular pressure = 3612 psi. INC = 87.5 deg. 05:50 - 07:25 1.58 DRILL P PROD1 Wiper trip to window. No problems. 07:25 - 09:20 1.92 DRILL P PROD1 Drill ahead f/1 0840' Q+ 1.53 / .35 3100 free-spin 200-300psi motorwork. 2-3k wob 60-80'/hr. 09:20 - 11 :25 2.08 DRILL P PROD1 Wiper trip to 10700' RIH tie-in at RA tag 11 :25 - 15:00 3.58 DRILL P PROD1 Drilling ahead f/11997' Q= 1.50/ .25 3100psi FS Ann= 3577 ECD= 10.76 WOB= 2-3k ROP 80-90'lhr 15:00 - 15:45 0.75 DRILL P PROD1 Wiper trip to 10700'. 15:45-16:15 0.50 DRILL P PROD1 At 10700' shut down pump. Ann 3300 (after 5 min 3228) (after 10min 3207) (after 15min 3189) (after 20 min 3184) re-set out MM. Bring on pump. See returns after 5.5 bbls pumped. 16:15-17:05 0.83 DRILL P PROD1 Wiper trip to bottom. 17:05 - 18:00 0.92 DRILL P PROD1 Drill ahead f/12154'. Q= 1.5 in 0.20 out 3100psi freespin 300psi MW Ann 3602 EDC 10.78 2-3k wob 20-30'/hr 18:00 - 19:00 1.00 DRILL IP PROD1 Drilling ahead. 1.5/0.14/3130 psi. IAP=157 psi, OAP=O psi. I ROP = 70 fph. ECD=10.6 ppg, Annular pressure = 3599 psi. 19:00 - 19:45 0.75 DRILL P I PROD1 , Continue drilling. Hold safety stand down while we continue to I drill. Discuss the BP report on the Texas City Refinary explosion with all hands on the rig for night tour. Discuss the simularities to our operation, and the lessons learned. Several good engineering safety improvements were suggested for this rig, and will be implimented. 19:45 - 21 :00 1.25 DRILL P PROD1 Continue drilling ahead. 1.50/0.15/3300 psi. ROP=65 fph. Pit vol = 327 bbls. A loaded vac truck is backed up to the rig, and an additional one is in route from Deadhorse. 21 :00 - 22:20 1.33 DRILL P PROD1 Wiper trip to window. Clean PU off bottom at 24klbs. Clean to window. 22:20 - 22:30 0.17 DRILL P PROD1 Log tie in pass over RA tag. Make +3' correction. 22:30 - 23: 15 0.75 DRILL P PROD1 Continue wiper trip back in hole. Clean to bottom, no motor work or set downs. 23:15 - 00:00 0.75 DRILL P PROD1 Resume drilling. 1.5/0.213120 psi. 60 fpm. 6/17/2005 00:00 - 03:20 3.33 DRILL P PROD1 Continue drilling ahead. 1.50/0.25/3073 psi. Pit volume = 290 bbls. IAP=150 psi. OAP = 0 psi. ECD = 10.83 ppg. Annular Pressure = 3633 psi. 03:20 - 04:45 1.42 DRILL P PROD1 Well TD'd. Make long wiper up to 4500'. Clean PU off bottom at 25 klbs, and clean in open hole to the window. 04:45 - 06:15 1.50 DRILL P PROD1 SD pumps, pull thru the window, open EDC, pump at 2.0 bpm while PUH inside tubing. Inital return rate at the window while pulling up hole was 2.0/0.9 bpm. 06:15 - 07:00 0.75 DRILL P PROD1 Increase rate to 2.5in 2.0 out at 1800' tag at surface. RIH to 500' then back to surface. No increase in cuttings seen which there wasn't much to begin with anyway. 07:00 - 08:45 1.75 DRILL P PROD1 TIH to 10760' 08:45 - 09:00 0.25 DRILL P PROD1 Tie-in at RA tag corrected -15.5' 09:00 - 09:55 0.92 DRILL P PROD1 RIH setdowns at 12299', 12345', 12392', 12401', PU at each spot and went 1 st try except at 12401' worked this area but starting to pull tight 50k. Decide to forget trying to get in trouble. Liner will be landed at 12250'. Upper hole looked very good. 09:55 - 12:40 2.75 DRILL P PROD1 TOH. Loading coil with 9.5 KWM. Stop at 10670' paint flag and swap valves to bullhead 9.5ppg mud while TOH. 12:40 - 13:00 0.33 DRILL P PROD1 Monitor well - dead. No vac no blow Printed: 7/11/2005 10:20:33 AM Page 5 of 21 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/17/2005 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 13:00 - 13:30 0.50 DRILL P PROD1 13:30 - 13:15 23.75 CASE P RUNPRD 13:15 - 13:30 0.25 CASE P RUNPRD 13:30 - 15:50 2.33 CASE P RUNPRD 15:50 - 16:50 1.00 CASE P RUNPRD 16:50 - 18:30 1.67 CASE P RUNPRD 18:30 - 19:40 1.17 CASE P RUNPRD Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Description of Operations Blowdown stack. Setback injector. UD BHA #5. (monitor well fluid level +1-50') RU to run 2-3/8" liner. PJSM review possible well control issues and liner running order. PU 2-3/8" 4.43# slotted liner and BHi tools. MU BHi tools. PU injector. PT CTC to 3100psi. Stab injector surface test BHi tools. RIH with liner. EDC open. Pump min rate. Weight check at window = 23500 Ibs. RIH at 40 fpm, pumping at 0.2 bpm. Went thru window slick. RIH thru build section slick. RIH weight is +9000 Ibs, -3500 Ibs WOB. RIH thru loss zone at 11100' slick. RIH in open hole smooth thru loss zone at 11599'. RIH to 12100'. Log down and tie in liner to GR marker at 10575'. RIH weight is +5800 Ibs, WOB=+800 Ibs. ¡Make -13' correction. RIH smooth to liner bottom set depth of 12256.7'. Double check all our numbers. Everything looks I good. Shut EDC Last WOB=+ 1000 Ibs, RIH wieght = +5000 [lbS. Bring on pumps to 1.5 bpm, 4200 psi to release GS. PU lat 21000 Ibs. PU 50'. RIH with pumps at 1.5 bpm, RIH weight = +8000 Ibs tagged top of liner with odometer reading 12256.9'. I Pick up with pumps on at 1.5 bpm. Same PU weight of 21 klbs. Confirmed release of liner. This is the smoothest liner job I have ever seen in Kuparuk! RUNPRD Take out liner BHA length. Log tie in pass over GR charecter at 10575' with pumps on at 1.5 bpm. WOB while logging down is -2700 psi. Make +2' correction. Drop pumps to 0 psi. WOB went from -2770 Ibs, to -3000 Ibs. 19:40 - 20:05 0.42 CASE P Lesson learned. When WOB is calibrated with liner hanging, then liner is dropped off, expect an offset corresponding to liner weight. Also note, WOB is effecting in a minor way by pump rate. RIH, tag top of liner with pumps on at 1.5 bpm. Found top of liner at 10735' on both string weight and WOB sensor. Requested liner top from proceedure was 10734'. PU at 20 klbs. Confirmed liner on depth and still in place. RUNPRD POOH replacing pipe voidage by pumping down the coil. Pit volume = 303 bbls. Tag up at surface. Pit volume = 250 bbls. RBIH to 200'. RUNPRD Monitor well for flow while holding PJSM prior to laying down liner running BHA. RUNPRD Confirmed no flow from well. Tag up with injector again with pumps off. Break injector. Lay down BHA. Install night cap and circulate accross the top of the hole to keep the well full. WEXIT Make up BHA to set TIW whipstock anchor. WEXIT RIH with BHA to set TIW whipstock anchor. EDC confirmed open. RIH at 70 fpm. WEXIT Continue RIH with L2 whipstock anchor. WEXIT Log tie in pass down over GR marker at 10575'. Make a -13' correction. Pick back up and log eeL down from 20:05 - 21 :50 1.75 CASE P 21:50 - 22:10 0.33 CASE P 22:10 - 22:30 0.33 CASE P 22:30 - 23:30 1.00 STWHIP P 23:30 - 00:00 0.50 STWHIP P 6/18/2005 00:00 - 02:15 2.25 STWHIP P 02:15 - 03:10 0.92 STWHIP P Printed: 7/1112005 10:20:33 AM BP Operations Summary Report Page 6 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/18/2005 02:15 - 03:10 0.92 STWHIP P WEXIT 10575'-10640'. Discuss eeL log with geo and DD. Come up with plan. Log from 10570', down into position. We are still on depth with GR charecter at 10575'. 03: 1 0 - 03:25 0.25 STWHIP P WEXIT Position bottom of packer at 10629', mid element at 10627', top of packer at 10624'. Orient lug profile to 15 deg left of high side. (As per reccommendation from WF hand). Shut EDC. Bring on pumps to 4000 psi. PU, got 20 klbs overpull to get off of packer. Saw 15 klbs on BHI WOB sensor. Set back down on top of packer. Tagged top of packer on depth. 03:25 - 05:15 1.83 STWHIP P WEXIT POH. Call for WF to bring out whipstock tray, 21' spacer, and Schlumberger to come out with RA pip tags to install in WS tray. 05:15 - 07:00 1.75 STWHIP P WEXIT Lay down WF Fury setting tool. Make up whipstock tray BHA. 07:00 - 09:30 2.50 STWHIP P WEXIT TIH to 10600' check up weights 23300k 09:30 - 09:45 0.25 STWHIP P WEXIT Orient 15deg LOHS RIH tag anchor, set down 4k PU not set. Setdown 8k PU pins sheared at 34000k good indication of latch and shear. Setdown 5k PU 22400k. Looks good 09:45 - 11 :30 1.75 STWHIP P WEXIT !TOH pumping .5 bpm At surface observe well - dead. 128bbls mud in pits (2,3,4,5) 11 :30 - 12:00 0.50 STWHIP P WEXIT Set back injector UD BH and WF tools. Whipstock left in hole. TOWS: 10594.3' RA Tags 10596.3' BOW (tray) 10600' 112:00 - 15:00 3.00 STWHIPI P WEXIT Cut-off BHI connector. Do Slack Management. Cut-off 5' coil. Rehead BHI upper quick connect and test. Change injector pack-off element. Same time perform weekly BOPE function test. Hole has been staying full. 15:00 - 16:05 1.08 STWHIP P WEXIT PU window milling BHA. MU CTC surface test - ok. 16:05 - 18:25 2.33 STWHIP P WEXIT TIH start filling coil wI new 8.6ppg Flo-Pro at 8000' 18:25 - 19:00 0.58 STWHIP P WEXIT Pumps at 0.3 bpm, 1670 psi. Tag top of whipstock at 10609.6'. Make -15' correction. PU at 23klbs, kick on pumps to full rate. Free spin is 3850 psi at 1.5 bpm. Note, 8.6 ppg mud in coil, 9.5 ppg mud in backside. Tag top of WS again at 10594'. Begin milling. 19:00 - 21 :00 2.00 STWHIP P WEXIT 10594.3', Milling ahead. 1.5/1.5/3520 psi. 21 :00 . 22:00 1.00 STWHIP P WEXIT 10595.7'. Milling ahead. Lots of metal on ditch magnets. 1.5/1.5/3650 psi. 22:00 . 23:00 1.00 STWHIP P WEXIT 10596.7'. Milling ahead. 1.5/1.5/3750. WOB=2890 Ibs, String wt=2500 Ibs, pit vol=480 bbls. 23:00 - 23:30 0.50 STWHIP P WEXIT 10597.5', Milling ahead. 1.5/1.5/3530 psi. WOB=2570 Ibs, String wt=1300 Ibs, pit vol=480 bbls. IAP=350 psi, OAP=O psi. 23:30 - 00:00 0.50 STWHIP P WEXIT Weight check. PU at 19 klbs. Free spin 3300 psi at 1.5 bpm. Resume milling. 6/19/2005 00:00 - 01 :00 1.00 STWHIP P WEXIT 10588.6' Continuing to mill ahead. 1.5/1.5/3540 psi. 5500 Ibs WOB, 0 Ibs string weight. IAP=360 psi, OAP=O psi. Pit vol = 478 bbls. Stacking weight? 01 :00 - 01 :30 0.50 STWHIP P WEXIT 10599.1'. We definately appear to be stacking weight. WOB=5700 Ibs, String weight = 0 Ibs. Stop injector to look for drill off. 1.5/1.05/3550 psi 01 :30 - 01 :40 0.17 STWHIP P WEXIT No drilloff. PU at 18700 Ibs. Free spin 3200 psi at 1.5 bpm. Ease back down and resume milling. 01:40-02:10 0.50 STWHIP P WEXIT RIH, tag at 10596.7'. Got 1400 Ibs of WOB, and a ton of motor Printed: 7/1112005 10:20:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 7 of 21 BP Operations Summary Report 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 6/19/2005 01:40 - 02:10 From - To Hours Task Code NPT Phase Description of Operations 0.50 STWHIP P WEXIT work. 5600 Ibs string weight. Stalled. Attempt to mill again, and getting stalls every time we try to mill. Repeat multiple times. Something is not right. Discuss with WF tool hand and DD. The motor is not drilling properly. We get stalls every time we attempt to drill, with even the slightest amount of WOB. We either have a weak motor, a damaged mill, or a washout in the BHA. Pressure information indicates no washout. 10S96.5', POOH for new motor, and to examine mills. Follow pressure schedule while POH. Hold PJSM re: undeployment of BHA. Tag up, trap 4S0 psi on well. Pressure undeploy BHA #8. IWF motor's output shaft parted at the base of threads. Fish left ¡in hole: 4-1/4" length of 1.49" OD 1/2" ID output shaft w/1-1/2" MT box connection on bottom 2.73" OD String Reamer 1.12" length 2.74" Window Mill .29" length I RU Howco wireline unit. PSJM review PU lubricator, Job assignments, Tool running order with all crews. I MU LIB. Stab lubricator, pressure test to 1000psi - ok leave 400psi on and open well. WHP 310psi. RIH w/LlB. Results showed shaft centered across WS tray Good impression of .500" ID of shaft but not the 1.49" OD. Shaft most likely has a convex profile break. Run 2.313" OD overshot dressed with 1.50" short catch spiral grapple, baited w/2-1/2"GR. PU weight at 10S00' 4251bs. Work over fish no problem. Work spans gradually work PU wt to 700lbs then appeared to let go. Continue working over fish for 30 min with max PU wt of only 5S01bs. Working in 60+deg hole that started at 3S00'md so spans are not very effective. Decide to POH. Temporally stuck at 8904' where there is no jewelry. Didn't see any problem here on previous run. Continue POH. At surface. No fish. Inspect grapple. We can see on the inside rim of grapple where is was setting down on fish but not enough energy remaining after contact to force grapple over fish. May have caught the one time on the first catch but no indication of further penetration. Add another centralizer closer to overshot, paint the inside of grapple and change from 10' of 1-7/8" roller stem to 5' of 1-7/8" and 11' of 2-1/8"" roller stem. Also WF is making an 1.S" ID burn-over mill to run if it becomes necessary to "rough up" the output shaft to afford the grapple a better bite. Also checking on feasibility of catching the 2-3/8" bit box on motor. PU tools as above. PT lubricator to 1000psi. RIH WHP 227psi. Work fishing BHA on bottom. Normal pickup weight is 450 Ibs. Set down at 10606' SLM. Spang down to set grapple. PU and got a bite on fish. PU to 9S0 Ibs, and grapple slipped off of fish. Repeat. Slipped off again. Repeat several more times, and slipped off each time. The slickline operator is confident that the grapple is over the fish, but keeps slipping off. Possibly due to the hardened and polished nature of the output 02:10 - 04:00 1.83 STWHIP N DFAL WEXIT 04:00 - 04:15 0.25 STWHIP N DFAL WEXIT 04:15 - 06:00 1.75 STWHIP N DFAL WEXIT 06:00 - 07:00 1.00 FISH N DFAL WEXIT 07:00 - 10:10 10:10 - 12:30 12:30 - 16:00 16:00 - 17:00 17:00 - 18:10 18:10 - 19:05 3.171 FISH 2.33 FISH 3.S0 FISH 1.00 FISH 1.17 FISH 0.92 FISH N DFAL WEXIT N DFAL WEXIT N DFAL WEXIT N WEXIT N N WEXIT DFAL WEXIT Printed: 7/1112005 10:20:33 AM BP Operations Summary Report Page 80f21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/212005 Date From - To Hours Task Code NPT Phase Description of Operations 6/19/2005 18:10 - 19:05 0.92 FISH N DFAL WEXIT shaft. 19:05 - 19:25 0.33 FISH N DFAL WEXIT POOH with slickline fishing BHA to examine overshot for signs that we had engaged the fish. 19:25 - 19:45 0.33 FISH N IDFAL WEXIT Lay down slickline fishing BHA. Inspect overshot and grapple. Paint is missing from the teeth of the grapple. The slickline operator concludes that the grapple was engaged on the fish, but was slipping off. Discuss with town, slickline supervisor, and Jason at Weatherford. WF is dressing a grapple with a different configuration. It is made with harder material, and will grab the fish in 2 different locations. It will take 3+ hours to have it on location. Standby while waiting on new grapple. WF is also building a burnover shoe to scar up the OD of the fish if their grapple will not bite. This will need to be run on coil with a motor. 19:45 - 21 :00 1.25 FISH N DFAL WEXIT Wait on new overshot from Weatherford. 21 :00 - 21 :45 0.75 FISH P WEXIT Hold Safety stand down with new Nordic crew that came up today. Discuss the accident that happened in March at the I Texas City refinery. The findings of the accident investigation i' were reviewed, and emphasis was placed on following proceedures, writing good handover notes, and notification to all individuals on location in the event of an unusual event on the rig. Good participation by all hands. 21 :45 - 23:30 1.75 FISH N DFAL .WEXIT Continue to wait for WF grapple. 23:30 - 23:45 0.25 FISH N DFAL WEXIT WF overshot on location. Make up to HES fishing BHA baited with a GR (Shear up) release tool. 23:45 - 00:00 0.25 FISH N DFAL WEXIT RIH with slicklline to attempt to fishlbait WF motor parts again. 6/20/2005 00:00 - 00:40 0.67 FISH N DFAL WEXIT Continue RIH with fishing BHA with WF overshot. 00:40 - 01 :30 0.83 FISH N DFAL WEXIT Weight check at 10920' = 450 Ibs. Set down at 10606' SLM, same depth as previous runs. Spang down to engage overshot. PU in incriments to 1000 Ibs, better than we have done so far. Spang down a few more times to set grapple. PU injncriments to 1500 Ibs. Got a good bite on the fish this time. Work up and down 6 times to 1500 Ibs. Fish latched and stuck. Pull up and get 1 hydraulic jar lick. Sheared the GR release tool. (Up shear). Looks like we have the fish baited good now. 01 :30 - 02:00 0.50 FISH N DFAL WEXIT POOH with fishing BHA. 02:00 - 02:15 0.25 FISH N DFAL IWEXIT Tag up, confirmed the GR did shear, and the fish is baited with the WF overshot and a G profile looking up. Make up 2nd fishing tool string, and PT lubricator to 1000 psi. 02:15 - 03:05 0.83 FISH N DFAL ¡WEXIT RIH with fishing BHA again on 0.108 wire. 03:05 - 03:20 0.25 FISH N DFAL WEXIT Check weight at 10550', = 450 Ibs. Set down on fish at same I depth 10606' SLM. Latch into G profile. Jar up at 1500 Ibs, and looks like grapple slipped off of fish. Spang down. PU to 15OOlbs, set off jar lick, and grapple popped off of fish again. I Repeat again. Not able to jar up without the grapple slipping IWEXIT off. 03:20 - 04:00 0.67 FISH N DFAL POH to inspect grapple. 04:00 - 04:30 0.50 FISH N DFAL IWEXIT Tag up at surface. Recovered baited grapple. Inspect grapple I in SL unit. Paint marks confirm that grapple was over fish completely, but slipped off. Call town engineer and discuss. Plan to run a motor with a buming shoe to rough up the exterior of the fish so that the grapple will bite better. Printed: 7/1112005 10:20:33 AM BP Page 9 of 21 OperatlonsSummaryReport Legal Well Name: 1 0-37 Common Well Name: 1 0-37 Spud Date: 1/15/2001 Event Name: REENTER+COMPLETE Start: 6/12/2005 End: 7/2/2005 Contractor Name: NORDIC CALISTA Rig Release: 7/2/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/20/2005 04:30 - 05:00 0.50 FISH N DFAL WEXIT Rig down slickline lubricator on rig floor, and lay it down in the pipe shed. 05:00 - 06:00 1.00 FISH N DFAL WEXIT Get ready to rig up burning shoe to motor. The burning shoe is here, but WF doesn't have the correct crossover on location to rig it up to their motor. Wait on WF to bring a crossover from Deadhorse. 06:00 - 09:20 3.33 FISH N WEXIT Dress down burnover shoe to allow 2.74" gauge ring to pass over. MU BHA. Pressure deploy. 09:20 - 12:00 2.67 FISH N WEXIT RIH tie-in at GR 10530-40' -13' correction. Q= 1.56 3245psi FS. Took weight at 10594.3' 12:00 - 13:05 1.08 FISH N WEXIT Milled down with 1.50"1 D burnover shoe to rough up the 1.490" output shaft to 10596.4' then seen 2-300psi motor work. This we suspect being the bit box connection below th shaft. Quit milling. Slickliners on location. Rigging up to use .125" wireline 13:05 - 14:55 1.83 FISH N WEXIT TOH maintaining 400psi on well. 14:55 - 16:00 1.08 FISH N WEXIT Pressure undeploy BHA. 16:00 - 17:15 1.25 FISH N WEXIT PJSM. RU Slickliners. PU overshot dressed with Bowen 1-7/16" grapple. Stab lubricator. PT to 1000psi. Ok. Open well. WHP 400psi on well 17:15 - 18:00 0.75 FISH N WEXIT RIH 18:00 - 19:00 1.00 FISH N DFAL WEXIT Weight check at 10520'=545Ibs (0.125" wire). Tag top of fish at 10593' SLM. Spang down to set overshot 10 times. PU to 900#, PU to 1500# and overshot held fine. Give 1 spang jar up lick, and overshot popped off grapple. Spang down 20 times. PU to 2000#, and grapple slipped off of fish. Spang down for 15 minutes. PU, and finally able to get 1 good up jar lick. That sheared the GR release tool. No gaurentees that the grapple with stay on the fish, but POH to pick up a GS. 19:00 - 19:45 0.75 FISH N DFAL WEXIT POOH with slickline BHA with sheared GR tool. 19:45 - 20:00 0.25 FISH N DFAL WEXIT Tag up at surface. Discuss plan forward with town and with WF. WF will not have buming shoe ready for at least 4 hours. Probably longer. Since we have the time, slickline operator recommends making another GR run to beat down on overshot to make sure that it is on the fish as good as possible. We will make 1 more GR run, then make a GS run. 20:00 - 20:50 0.83 FISH N DFAL WEXIT RIH with GR tool to jar down on overshot some more. 20:50-21:10 0.33 FISH N DFAL WEXIT Weight check at 10520' = 490 #. Latch Gr into G profile on bait sub. Pick up to 1500 Ibs, latched ok. Spang down for 10 minutes. PU, and give an oil jar lick at 1500#. Good lick, and overshot stayed on fish. Spang down for 10 minutes. PU and give an oil jar lick at 2000#. Sheared GR. Everything appears to be ok. 21:10-21:40 0.50 FISH N DFAL WEXIT POH with GR assembly. 21 :40 - 21 :55 0.25 FISH N DFAL WEXIT Tag up. Lay down GR tool. Pick up GS (Down Shear Release) tool. MU lubricator. PT to 1000 psi. 21 :55 - 22:40 0.75 FISH N DFAL WEXIT RIH with GS fishing string to commence up jarring on baited fish. 22:40 - 22:45 0.08 FISH N DFAL WEXIT Weight check at 10550' = 480 Ibs. Set down on G profile on bait sub. PU to 1500 Ibs. Latched into bait sub ok. Jar up at 2000# pulled overshot off of fish. 22:45 - 23:30 0.75 FISH N DFAL WEXIT POH with grapple to inspect. 23:30 - 23:45 0.25 FISH N DFAL WEXIT Tag up at surface, rig down 1-7/16" overshot and bait sub. Printed: 7/11/2005 10:20:33 AM BP Operations Summary Report Page 10 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/20/2005 23:30 - 23:45 0.25 FISH N DFAL WEXIT Examine in SL unit. Paint marks indicate that the overshot was only engaged over the fish 1". It was not fully engaged dispite the down jarring that was done. Call WF and ask for the 1.5" overshot to be brought back out. It was taken to Deadhorse to be redressed. Also note, ETA of 2" burnover shoe is 03:00 AM. It is still in fabrication. 23:45 - 00:00 0.25 FISH N DFAL WEXIT Wait on 1-1/2" overshot. 6/21/2005 00:00 - 01 :30 1.50 FISH N DFAL WEXIT Continue to wait on WF to bring out overshot. 01 :30 - 02:30 1.00 FISH N DFAL WEXIT RIH with 1-1/2" overshot on Slickline GR tool. 02:30 - 02:55 0.42 FISH N DFAL WEXIT Weight check at 10550' = 550#. Set down at same SLM depth I as previous 0.125" wire runs of 10593'. Spang down for 15 minutes. Slingshot down several times from 1000#, 1500#, 2000#. PU and take a jar lick at 2000#. Sheared GR running 0.421 FISH tools. Weight up = 480#. Appear to have left fish baited with 1.5" grapple in overshot with G bait sub. 02:55 - 03:20 N DFAL WEXIT POH with sheared GR to pick up GS fishing tool. 03:20 - 03:30 0.17 FISH N DFAL WEXIT Lay down GR, pick up GS. 03:30 - 04:25 0.92 FISH N DFAL WEXIT RIH with fishing BHA with GS release tool. 04:25 - 04:35 0.17 FISH N DFAL WEXIT Check weight at 10520', 500#. Latch into G profile of bait sub. Got good pickup to 900 Ibs. Set down to cock oil jars, pickup to 1200 Ibs for a jar lick and pulled free. Probably jarred the overshot oft of the fish. 04:35 - 05:00 0.42 FISH N DFAL WEXIT POH. 05:00 - 05:30 0.50 FISH N DFAL WEXIT Tag up at surface. Recovered fish!!!! Rig down slick line operations. Release unit. 05:30 - 07:30 2.00 STWHIP N DFAL WEXIT Call Baker to come mill window. PU BHI tools and load into lubricator. 07:30 - 07:45 0.25 STWHIP N DFAL WEXIT PJSM review pressure deployment procedures. 07:45 - 09:15 1.50 STWHIP N DFAL WEXIT Pressure deploy BHA #11 09:15 - 11 :25 2.17 STWHIP N DFAL WEXIT TIH to 10530' tie in -13' correction TIH to 10594'. 11 :25 - 13:25 2.00 STWHIP N DFAL WEXIT Paint flag at 10594'. Start time milling window f/10594' (top of whipstock, did not tag) Q=1.50 3100psi free-spin Ann= 3719psi EDC= 11.34 Starting to some MW at 10597.5' 1oo-200psi 13:25 - 17:00 3.58 STWHIP P WEXIT 10596.5'. Continue milling. Started to get motor work at 10597.5',100-200 psi 17:00 - 20:15 3.25 STWHIP P WEXIT 10599.2', Milling ahead. Expect bottom of window at any time. 1.5/1.513530 psi. WOB=1oo0 Ibs. String weight = 3600 Ibs. IAP=450 psi, OAP=O psi. Pit vol=489 bbls. Estimate drilling formation at +1-10,600'. Formation sand noted in rtns. 20: 15 - 22:30 2.25 STWHIP P WEXIT Make four passes up and down to dress window. Some mtr work noted at 10600' (btm of window). Dry drift window with 450 psi WHP. Window looks smooth. Will determine window top & btm after tying RA tag in to main well bore on next run. 22:30 - 00:00 1.50 STWHIP P WEXIT Pull out hole. Paint EOP flag at 10300'. Continue to POOH following pressure schedule 6/22/2005 00:00 . 00:45 0.75 STWHIP P WEXIT Continue to pull out of hole. Tag up and RIH 1.8'. Hold PJSM in ops cab to review un-deployment proc. 00:45 - 01 :45 1.00 STWHIP P WEXIT Undeploy milling assy wI 450 psi WHP. 01 :45 . 03:45 2.00 DRILL P PROD2 MU and deploy lateral drilling assy (#12) 03:45 - 06:00 2.25 DRILL P PROD2 Run in hole. Tie in to flag, -14 correction. Log tie in pass over GR marker. 0 correction. SD pumps thru window, no drag Printed: 7/1112005 10:20:33 AM BP Operations Summary<Report Page 11 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/12/2005 7/2/2005 Spud Date: 1/15/2001 End: 7/212005 Date From - To Hours Task Code NPT Phase Description of Operations 6/22/2005 03:45 - 06:00 2.25 DRILL P PROD2 seen. 06:00 - 09:00 3.00 DRILL P PROD2 Free spin 3350 psi at 1.65 bpm. Tag bottom at 10611', and begin drilling lateral section of hole. 1.65/1.65/3470 psi. Pit volume = 490 bbls. IAP=450 psi, OAP=O psi. ECD=11.8 ppg. Annular BHP=3850 psi. 09:00 - 10:00 1.00 DRILL P PROD2 10684', Started having losses. Drilling ahead at 1.63/0.9/3450 psi. 10:00 - 10:40 0.67 DRILL P PROD2 10710', Continuing to drill with losses. 1.63/0.83/3400 psi. Pit vol = 405 bbls. 10:40 - 10:55 0.25 DRILL iP PROD2 Wiper trip to window for Geo tie in log. No problems. 10:55 - 11 :05 0.17 DRILL P PROD2 Log tie in pass down from 1 0540'. Make + 1 correction. 111 :05 - 11 :20 0.25 DRILL P PROD2 Continue back to bottom on wiper. Slick. 11 :20 - 13:50 2.50 DRILL P PROD2 Resume drilling with losses. Loss rate is not improving. Drilling at 1.66/0.84/3460 psi. Pit volume = 350 bbls. 2 vac trucks supporting rig. 1 hauling mud from MI plant in Deadhorse, 1 shuttling mud from upright tanks. Keeping 580 bbls of mud on reserve at all times. 13:50 - 14:10 0.33 DRILL P PROD2 Wiper trip to the window. Clean PU off bottom. Clean to [14:10 - 15:20 I window. 1.17 DRILL P PROD2 Resume drilling. Free spin 3350 psi at 1.6 bpm. Drilling at 1.6/0.8/3530 psi. IAP=310 psi, OAP=O psi. Pit volume = 220 bbls. Fresh vac truck backed up to rig and ready to unload. 15:20 - 16:20 1.00 DRILL P PROD2 10985', Total loss of returns. 1.58/0.0/3000 psi. ECD=10.11 ppg, BHP=3330 psi. Make long wiper up above window to 9600' pumping at full rate with EDC open. 16:20 - 18:45 2.42 DRILL P PROD2 Resume drilling. Returns have healed up slightly. 1.6/0.35/3360 psi. ECD=10.83 ppg, BHP=3670 psi. Pit volume=362 bbls. 18:45 - 19:15 0.50 DRILL P PROD2 Drill ahead from 11,120'. 3300 psi fs at 1.6 in/0.6 out. DPSI: 200-400 DHWOB: 2.5-3.5k#. INC/AZlTF: 91.0/67.5175R. WHP/BHPIECD: 0/3645/11.0 ppg. IAlOAlPVT: 225/0/195 bbls. ROP varyiable from 40 to 60 fph. Continue to lose +/- 60% rtns to formation. 19:15 - 20:00 0.75 DRILL P PROD2 Wiper trip to 10610'. Hole smooth in and out. 20:00 - 00:00 4.00 DRILL P PROD2 Drill ahead from 11,135'. Apparently drilled into some siderite. ROP has slowed to 10 to 20 fph. Losses have slowly healed with rtns at 0.7 bpm, up from 0.6 bpm at a circ rate of 1.6 bpm. 6/23/2005 00:00 - 03:00 3.00 DRILL P PROD2 Drill ahead from 11,220'. 3350 psi fs at 1.6 in/0.7 out. DPSI: 200-400 DHWOB: 3.0-4.0k#. I NC/AZlTF: 90.3/66.1/65R. WHP/BHP/ECD: 0/3677/11.12 ppg. IAlOAlPVT: 225/0/458 bbls. ROP 10-25 fph. Still seeing a lot of siderite in formation samples. 03:00 - 04:00 1.00 DRILL P PROD2 Short trip to window. Hole smooth. 04:00 - 06:00 2.00 DRILL P PROD2 Drill ahead from 11,285'. 06:00 - 10:00 4.00 DRILL P PROD2 Drilling ahead. Getting 15% siderite cementation in cuttings. 1.610.86/3450 psi. Pit volume = 180 bbls, bringing on another vac truck of new mud. ROP=25 fph. IAP=220 psi, OAP=O psi. ECD=11.12 ppg, BHP=3677 psi. 10:00 - 10:32 0.53 DRILL P PROD2 Wiper trip to window. Clean PU at 22 klbs. Slightly draggy at 11030'-11000'. 10:32 - 10:40 0.13 DRILL P PROD2 Log tie in pass over RA tag in WS. Make +2' correction. 10:40-11:15 0.58 DRILL P PROD2 RIH, set down at 10985'. This is 2nd loss zone at a fault encountered yesterday. Tool face is the correct oriention. Printed: 7/1112005 10:20:33 AM BP QperationsSummary Report Page 12 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/23/2005 10:40 - 11 :15 0.58 DRILL P PROD2 Work thru it at 3 fpm. Made it thru easily on 2nd attempt. Continue in to bottom. No problems at 11030'. 11:15-11:55 0.67 DRILL P PROD2 Free spin 3380 psi at 1.6 bpm. Resume drilling at 1.6/0.7/3650 psi. ROP took off after wiper trip. Making 75 fph now. Formation lithology change on GR at depth where we started wiper. 11 :55 - 12:45 0.83 DRILL P PROD2 Losses increased. Drilling at 1.61/0.21/3200 psi. Called for trucks with 3% KCL at 11 :30. 12:45 - 14:15 1.50 DRILL P PROD2 Losses have recovered slightly. Drilling at 1.6/0.4/3440 psi. ROP slowed back down again. 20 fph again. Make 300' wiper trip. Sticky pickup at 31 klbs. Pull up hole and overpulls cleaned up after 50'. 14:15 - 15:00 0.75 DRILL P PROD2 Resume drilling. Very slow ROP. 15:00 - 17:20 2.33 DRILL P PROD2 Geo thinks we crossed a fault at 11435', and are possibly in the Kalubik shale now. Continue drilling ahead to see on GR sensor. Call town to discuss. 17:20 - 18:30 1.17 DRILL P PROD2 1.64/0.87/3732 psi. ECD=11.3 ppg, BHP=3729 psi. IAP=210 I I psi, OAP=O psi. 310 bbls in pits. Make 500' wiper to see if it 118:30 - 21 :30 I helps ROP. 3.00 DRILL P PROD2 Drill ahead from 11,520'. 3650 psi fs at 1.6 in/O.4 out. DPSI: 200-400 DHWOB: 1.5-3.0k#. I NC/AZlTF: 89/100/180R. WHP/BHPIECD: 0/3789/11.7 ppg. IAlOAlPVT: 192/0/315 bbls. ROP 10-15 fph. GR indicates Kalubik Shale at 11480'. Hole getting sticky due to loss zone at 11480'. Discuss with geo. Decide to POOH. 21 :30 - 00:00 2.50 DRILL C PROD2 POOH for side track assembly. Rtns improved to 1.6 in/0.72 out once past 11480'. Pull heavy and trying to packoff from 11 040' to 10990'. Had to reciprocate pipe and take small 'bites' upwards to keep from packing off. Max overpull was 39k# (normal up wt: 26k#) Circulate out of hole at 1.5 in/0.94 out at 50 fpm up to 4500'. 6/24/2005 00:00 - 01 :45 1.75 DRILL C PROD2 Continue to POOH at 80% to ensure good hole cleaning. Hold PJSM with crews to discuss un-deploy. At surface. RIH 500' to boost any excess cutttings out. Minimal cuttings noted over shaker. Tag up and RIH 2'. 01 :45 - 02:45 1.00 DRILL C PROD2 Undeploy BHA #11 with 450 psi whp. HCC bi-center in excellent condition. 02:45 - 03:30 0.75 STKOH C PROD2 Adjust BHI motor to 1.9 deg. MU HCC R60 ST bit with round brass nose cone. 03:30 - 04:30 1.00 STKOH N RREP PROD2 Problems with power pack blower unit. Call for rig electrician. Found a loose wire in SCR room panel. Repaired same. 04:30 - 06:00 1.50 STKOH C PROD2 Continue to deploy BHA #12 (1.9 deg mtr w/ R60 ST bit). 06:00 - 07:45 1.75 STKOH C PROD2 RIH with the sidetrack BHA. 07:45 - 08:00 0.25 STKOH C PROD2 RIH thru window slick, log tie in pass over RA tag. Make -14' correction. 08:00 - 09:00 1.00 STKOH C PROD2 Rlh to sidetrack depth pumping at minimum rate thru an open EDC. Slick to 10985', then set down. PU and set down 3 times easy. PU, kick shut the EDC, and ease down pumping thru the motor at 0.5 bpm. Set down 3 times. Try 'drilling' thru at 3 fpm. Set down with motor work at 10988'. PU, and try it Printed: 7/1112005 10:20:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page<13 of 21 BP Operations Summary Report 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 6/24/2005 08:00 - 09:00 From - To Hours Task Code NPT Phase PROD2 09:00 - 10:50 10:50 - 11 :25 11 :25 - 12:15 12:15 - 14:20 1.00 STKOH C 1.83 STKOH C PROD2 0.58 STKOH C PROD2 0.83 STKOH C 2.08 STKOH C I PROD2 ! PROD2 14:20 - 15:20 1.00 STKOH C PROD2 15:20 - 16:20 1.00 STKOH C PROD2 116:20 - 16:55 I 0.58 STKOH C PROD2 16:55 - 17:20 0.42 STKOH C PROD2 17:20 - 19:30 2.17 STKOH C PROD2 19:30 - 20:30 1.00 STKOH C PROD2 20:30 - 21 :30 1.00 DRILL C PROD2 21 :30 - 22:30 1.00 DRILL C PROD2 22:30 - 00:00 1.50 DRILL C PROD2 6/25/2005 00:00 - 00:30 0.50 DRILL C PROD2 00:30 - 01 :00 0.50 DRILL C PROD2 01 :00 - 05:50 4.83 DRILL C PROD2 05:50 - 06:35 0.75 DRILL C PROD2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Description of Operations again. Still can't get thru. Try it a third time, still set down at 10988'. PU, kick pumps on to full rate. TF at "as drilled tool face". Run in hole at 3 fpm. 1.52/0.6/3100 psi. Made it to 10992', set down, worked thru it. RIH at 20 fpm. no more set downs. Stop at 11100'. Paint flag on coil. Back ream to 11070' at 1 fpm. WOB= -250 Ibs. RIH smooth, WOB=40 Ibs. Back ream again at 1 fpm. It took 2.5' to PU and get full weight. WOB while backreaming 2nd pass = -270 Ibs. 1.53/0.8/3182 psi. RIH WOB = 60 Ibs. Back reaming pass #3. WOB = -130 Ibs. RBIH. Stop at flag, 11100'. WOB= -20 Ibs. Stop for 30 minutes with pumps at full rate to help start lip. 1.53/0.79/3150 psi. Time drill at 1 '/hr. New guy on the stick. Meant to give it 0.1', and gave it 1'. Pick up above stop depth. Run back down to 11099'. Begin drilling at 1.0'/hr all over again l' above last stop depth. 1.54/0.78/3180 psi. WOB at start of milling is -20 Ibs. Begin drilling at 2'/hr. WOB= +40 Ibs. 1.53/0.79/3130 psi Started getting a small amount of WOB as soon as we started at 2'/hr. 60-1 00 Ibs. Begin drilling at 3'/hr. WOB= + 10 Ibs. 1.53/0.82/3100 psi. Started taking WOB at 11103.5'. Good indication that we have a lip. Continue at 3'/hr to 11106'. Attempt control drilling at 20 fph. Got good weight on bit (1500 Ibs), and good moter work +100 Ibs. Drill ahead until confirmed that we are sidetracked on INC. 1.54/0.83/3250 psi. WOB=1350 Ibs. Getting motor work, and have positive WOB. Definitely making new hole. Near bit INC sensor reading 85 deg. (Original WB = 89 deg) Confirmed sidetracked. Sidetrack confirmed. POOH to pick up lateral section BHA. Clean in OH. Open EDC above window, and POH at full rate. Hold PJSM to discuss undeployment ops. At surface. Space out BHA. Close rams and undeploy BHA. LD same. Re-head coil e-line head. Test same. Pressure deploy BHA #12 Run hole holding WHP as per schedule. Log gr tie in across RA tag. -14' correction. Wiper trip to 11130'. Motor work and weight at 10988'. PU twice and work through (cuttings build up at loss zone ?). Tag btm at 11130'. Drill ahead from 11,130'. 3200 psi fs at 1.6 in/0.85 out. DPSI: 150-300 DHWOB: 2.0 - 3.0k#. INC/AZ!TF: 88.0/89/65R. WHP/BHP/ECD: 11/3666/11.1 ppg. IAlOAlPVT: 234/0/210 bbls. ROP 20-40 fph. Wiper trip to shoe. Clean PU off bottom, thru sidetrack at 11100'. A couple of weight bobbles, but no motor work thru loss zone at 10985'. Clean up to the window. RBIH. Clean from the window down to loss zone at 10985'. Had several set downs. Finally had to drill thru it with TF held Printed: 7/1112005 10:20:33 AM BP QperationsSummaryAep.ort Page 14 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/25/2005 05:50 - 06:35 0.75 DRILL C PROD2 as as drilled. 06:35 - 07:30 0.92 DRILL C PROD2 RBIH. Clean from the window down to loss zone at 10985'. Set down. PU and tried to get thru it several times, and set down each time. Finally kept pumps at 1.5 bpm, and drilled thru it at 3 fpm. RIH to 11030' slick. Need to ream this section to try to clean up a bit. First pass up got a couple of motor bobbles at 10985'. Set down on first pass back down thru. Drilled thru it at 3 fpm. Pulled back up and set down at 10970'. Seem to be moving it around. Suspect that it is cuttings that have stacked up at the loss zone. Continue to ream up and down at full pump rate and 3 bpm. Setdowns and motor work keep getting higher in the hole. Looks like we are chasing cuttings uphole. 07:30 - 08:40 1.17 DRILL C PROD2 Area of hole near loss zone at 10985' is clean. We can run up and down thru it with no problems. Debris appears to move up hole as we work it. Chase debris up to window at 10 fpm. 1.56/0.85/3160 psi. Jog in the hole just below the window, Open EDC, and PUH at 50 fpm, pumping at full rate, trying to clean hole. Pumping at 2 bpm/0.93 bpm/3500 psi. Didn't see any motor work or overpulls on trip up to 10000'. 08:40 - 08:55 0.25 DRILL C PROD2 Log tie in pass over RA tag. Make +1' correction. 08:55 - 09: 15 0.33 DRILL C PROD2 RIH. Smooth below window to 10933.8'. Then set down again. Had motor work and some weight bobbles. Catch sample of solids from last bottoms up when chasing debris to the window. No significant amount of cuttings from bottoms up. There is defiantely debris in the hole of some kind that we are chasing around. Get thru it easily, then try to chase it back up hole. 09:15 - 09:50 0.58 DRILL C PROD2 Run back in hole. Smooth to 10952'. Ran thru it at 31 fpm, had just a slight weight bobble and motor work. Set down at 11000', popped thru ok. 09:50 - 15:15 5.42 DRILL C PROD2 Resume drilling. Free spin = 3250 psi at 1.6 bpm. Drilling at 1.6/0.8/3500 psi. ROP=30 fph. IAP=220 psi, OAP=O psi. Pit volume = 370 bbls. ROP 30 fph. 15:15 -16:15 1.00 DRILL C PROD2 Wiper trip to window. Clean PU off bottom at 23 klbs. 1.6/0.83/3450 psi off bottom. Slightly ratty from 11120'-11000' on tension, but no motor work. Clean thru sidetrack at 10985', and up to the window. The cleanest trip we have had in a couple of days. RBIH. Clean down to 10985'. Set down. Had to RIH at 3 fpm, and pumps at full rate. Made it thru ok. 16:15-18:00 1.75 DRILL C PROD2 Resume drilling. Free spin 3400 psi at 1.69 bpm. Drilling at 1.69/.85/3700 psi. ROP=30 fph. 18:00 - 22:00 4.00 DRILL C PROD2 Drill ahead from 11,455'. 3200 psi fs at 1.6 intO.7 out. DPSI: 150-300 DHWOB: 2.0 - 3.0k#. INC/AZlTF: 86.0/107/60L. WHP/BHP/ECD: 11/3695/11.1 ppg. IAlOAlPVT: 212/0/186 bbls. ROP 20-40 fph. 22:00 - 23:00 1.00 DRILL P PROD2 Drill ahead from 11546'. Past L2 PB1 max depth. Continued slow drilling (15-30 fph). Continue to circulate at 1.6 in / 0.8 out. 23:00 - 00:00 1.00 DRILL P PROD2 Wiper trip to just below window. Smooth trip out. 6/26/2005 00:00 - 00:30 0.50 DRILL P PROD2 Continue wiper trip from window. Hole smooth. Slight mtr work at 10985, no wt bobble. Hole smooth. 00:30 - 04:30 4.00 DRILL P PROD2 Drill ahead from 11,580'. 3450 psi fs at 1.65 in/0.83 out. DPSI: 150-300 DHWOB: 1.0 - 2.0k#. INC/AZlTF: 86.0/107/60L. Printed: 7/1112005 10:20:33 AM BP Operations Summary Report Page 15 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/26/2005 00:30 - 04:30 4.00 DRILL P PROD2 WHP/BHP/ECD: 1113720/11.3 ppg. IAlOAlPVT: 212/0/328 bbls. ROP 15-30 fph. 04:30 - 06:00 1.50 DRILL P PROD2 Drilling ahead from 11650'. 3400 psi fs @ 1.6 in/ 0.8 out on flo pro. Begin pumping 3% KCL fluid 06:00 - 06:40 0.67 DRILL P PROD2 Continue drilling lateral section. 1.68/1.55/2300 psi. ECD=10.14 ppg. BHP=3360 psi. IAP=200 psi, OAP=O psi. KCL all the way around. A couple of interesting observations. Returns are now nearly 100% with KCL in the hole. Also, the ROP seemed to increase as soon as we had KCL around. ROP went from 25 fph to 45 fph. Nearly doubling. The Geo says that there is nothing lithologically to account for the change in ROP. The samples look the same as before. 06:40 - 07:15 0.58 DRILL P PROD2 Pump 20 bbl mud sweep. Plan to pump 20 bbls of mud for !every 100 bbls of KCL pumped. (About 1 sweep per hour). At the current ROP this means a sweep for every 40' of hole 07:15 - 07:50 I drilled. Current free spin with brine is 2200 psi at 1.7 bpm. 0.58 DRILL P PROD2 Wiper trip to window. Clean PU off bottom. Chasing sweep OOH. Pulling at 1.73/1.22/2460 (Higher free spin due to ECD from mud sweep behind pipe). Clean thru OH sidetrack·at 11100'. Weight bobble at 11020'. Clean thru loss zone at 10985'. Clean up to the window. 07:50 - 08:05 0.25 DRILL P I PROD2 Log tie in pass over RA tag in whipstock. Pumps to min rate. 400 psi trapped on well. BHP=3275 psi, ECD=3275 psi. Make +4' correction. 08:05 - 08:45 0.67 DRILL P PROD2 RBIH. Ran slow down thru loss zone at 10985', no weight bobbles, no motor work. Hole was very clean. Cleanest trip we have made in the last 3 days. 08:45 - 14:10 5.42 DRILL P PROD2 Resume drilling. Free spin 2250 psi at 1.63 bpm. Drilling at 1.63/1.1/2370 psi. ECD=9.97 ppg, BHP=3305 psi. IAP=220 psi, OAP=O psi. 14:10 - 15:00 0.83 DRILL P PROD2 Wiper trip to window. Clean PU off bottom at 25 klbs. Clean in open hole up to 11025'. Had 10klbs over pull at this depth. Pulled thru the loss zone and up to the window ok. Ran back thru loss zone at 5 fpm with no motor work or weight bobbles. Overpull on trip up was most likely due to cuttings beds. 15:00 - 15:45 0.75 DRILL P PROD2 While making wiper trip held fire drill. Scenario was a small trash can fire in Pump room #1. Good response by all hands with several lessons learned. These will be reviewed at the next 2 weekly safety meetings. 15:45 - 16:00 0.25 DRILL P PROD2 Continue wiper trip to bottom. 16:00 - 17:00 1.00 DRILL P PROD2 Resume drilling wiper section. 1.65/1.41/2530 psi. Still pumping alternating 100 bbls KCU20 bbls mud sweeps. 17:00 - 20:00 3.00 DRILL P PROD2 POH to perform biweekly BOP test. Slick PU off bottom at 25 klbs. Smooth in open hole. Slight weight bobble at 11020'. Hold PJSM to review un-deployment procedure. A lot of material over shaker as BHA pulled to surface. RIHto 200'. POOH. Tag up. Space out for un-deployment. 20:00 - 21:00 1.00 DRILL P PROD2 Un-deploy lateral BHA with 350 psi trapped on well.. Grease BOP and manifold components. Printed: 7/1112005 10:20:33 AM BP o.perations Summary Report Page 16 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/12/2005 7/2/2005 Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/26/2005 21 :00 - 21 :45 0.75 DRILL P PROD2 Hold safety stand down to review Texas City incident with 4th crew. Review incident details, findings, and how these have parallels with CTD rig operations. Good response from crew members. 21:45 - 00:00 2.25 BOPSU P PROD2 Test BOP equipment. Witness waived by AOGCC J. Jones. Test witnessed by WSL and CTD Supervisor. 6/27/2005 00:00 - 04:00 4.00 BOPSU P PROD2 Continue testing BOP equipment. 04:00 - 04:05 0.08 DRILL N SFAL PROD2 Rig lost power. Restored quickly. 04:05 - 05:30 1.42 DRILL P PROD2 Deploy lateral drilling assembly (BHA #15). 1.1 deg mtr with I: HYC bi-center. Found 295 psi WHP. 05:30 - 07: 15 1.75 DRILL PROD2 RIH with BHA #15 to resume drilling lateral section. 07: 15 - 07:30 0.25 DRILL PROD2 Run thru the window slick. Log tie in pass down over RA tag in whipstock at 10596'. Make -14' correction. 07:30 - 08:30 1.00 DRILL P PROD2 Run to bottom at 30 fpm. Did not slow down thru loss zone or OH sidetrack, and did not see any motor work or weight bobbles. Hole is clean at this point. 08:30 - 12:50 4.33 DRILL P PROD2 I Resume drilling. Free spin 2300 psi at 1.6 bpm. Begin drilling ! I at 1.6/1.35/2390 psi. IAP=255 psi, OAP=O psi. Pit vol = 187 I I bbls of KCL. Pumping 100 bbls of KCL followed by 20 bbls of mud. ROP continues to be slow. 25 fph. ECD=9.84, BHP=3265 psi. 12:50 - 13:10 0.33 DRILL P PROD2 I SIMOP's meeting with rig crew and crew on pumping unit that I will rig up on well 1 D-42. They will pump CaC03 to P&A well for us. We discussed communications, primary and secondary muster areas, hazards of the jobs, and mitigations to the hazards. 13:10 - 15:35 2.42 DRILL P PROD2 Continue drilling. Slow drilling in siderite. 1.62/1.15/2430 psi. WOB=1750 Ibs, ECD=9.89 ppg, BHP=3290 psi. 15:35 - 16:50 1.25 DRILL P PROD2 Return rate improved suddenly. Went from 1.6/1.1 to 1.6/1.4. ECD=9.66, BHP=3208 psi. Pit volume = 222 bbls. Started getting gas cut mud 50 bbls later. Well taking fluid and giving up a bit of gas at the same time. Go figure. Increase BHP by holding 100 psi at surface with drilling choke. Ran retums thru the gas buster. Returns cleaned up after 1/2 an hour. Current ECD = 9.81. BHP=3261 psi. Drilling at 1.8/.85/2800 psi. 16:50 - 17:35 0.75 DRILL P PROD2 Back on the pits. No gas in returns. Pumping at 1.78/0.97/2680 psi. Holding 100 psi at surface. ECD=9.85, BHP=3270 psi. 17:35 - 19:45 2.17 DRILL P PROD2 Wiper trip to window. Clean PU off of bottom @ 25 klbs. Clean pulling out of hole. Some mtr work at 10988' while RIH. A few weight bobbles just below 10,988'. Set down at 11043' and 11120'. PU and work past ok. Rest of trip in smooth. 19:45 - 23:30 3.75 DRILL P PROD2 Drill ahead from 12,065'. 2260 psi fs at 1.75 in/1.15 out. DPSI: 150-300 DHWOB: 1.0 - 2.0k#. INC/AZlTF: 88.2/96.2/105R. WHP/BHP/ECD: 106/3266/9.82 ppg. IAlOAlPVT: 251/1/120 bbls. ROP 10-20 fph. Pump 10 bbl flo pro sweep for every 100 bbls 3% KCL pumped. 23:30 - 00:00 0.50 DRILL P PROD2 Weight transfer becoming poor. Pump additional sweeps. Short trip to window. 6/28/2005 00:00 - 02:15 2.25 DRILL P PROD2 Continue wiper trip to window. Pump several additional 10 bbl Printed: 7/11/2005 10:20:33 AM BP Operations Summary Report Page 17 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/28/2005 00:00 - 02:15 2.25 DRILL P PROD2 flopro sweeps. Getting small amount of gas in rtns. Go to gas buster. Increase WHP from 150 to 200 psi. WHP/BHP/ECD: 200/3240/9.81 ppg. Hard to get accurate rtns count due to gas effect on micro motion out. PVT shows 1 bpm loss rate. Set down at 10985'. Work past. Micro out density back to 8.45 ppg. 02:15 - 06:00 3.75 DRILL P PROD2 Drill ahead from 12,145'. 2360 psi fs at 1.75 in/0.73 out. DPSI: 150-300 DHWOB: 1.0 - 2.0k#. INC/AZlTF: 86.0/103l60L. WHP/BHP/ECD: 205/3247/9.76 ppg. 1N0AlPVT: 242/38/263 bbls. ROP 20-40 fph. Pump 10 bbl flo pro sweep every 100 bbls KCL pumped. Make frequent 100' short trips to help weight transfer. 06:00 - 06:20 0.33 DRILL P PROD2 Continue drilling lateral section. Reasonable ROP of 50 fph. It won't last, Geo has us pointed back up into hard drilling rock. 1.64/0.7/2400 psi. ECD=9.81 ppg. Pit vol=220 bbls. 06:20 - 06:30 0.17 DRILL P PROD2 Wiper trip to shoe. Clean pickup off bottom. Hung up at 12185'. Ran back down, and hung up momentarily. Broke thru. Run down, pump 20 bbls sweep. Pumping 1.84/.7612500 psi. PUH at 30 fpm. 06:30 - 08:00 1.50 DRILL N STUC PROD2 12185'. Keep hanging up at 12185'. Pumped several sweeps. Suspect cuttings bed. Tagged up on it multiple times. A little sticky going down each time we tag it. Try opening EDC. PLF. 2.37/0.66/3165 psi. PUH slowly. Try washing it away. Have not pulled into it hard. Using 10klbs over as max overpull. Packs off each time we pull into it. Pulled up at 2.5 fpm, pumping at 2.4/.9/3200 psi. Made 12169'. Making progress. Hung up, couldn't go up or down for 20 minutes. Still getting the same returns. Keep pumping and working pipe downhole. Finally popped free. PUH slowly. Ratty up to 12120', then smooth. 08:00 - 09:20 1.33 DRILL N STUC PROD2 Pull up hole to 11700'. Got above cuttings beds. Run back in hole to fluff cuttings with flopro sweeps and spinning bit. Clean down to TD. 09:20 - 10:00 0.67 DRILL P PROD2 Clean PU off bottom at 26 klbs. Clean in open hole thru initial stuck depth of 12185-12165'. Continue PUH. 10:00 - 10:15 0.25 DRILL P PROD2 SIMOP's safety meeting with Veco crew operating post hole drilling rig adjacent to Nordic 2 pipe shed. Attended by Veco crew, rig crew, welder, team leader and BP WSL. Discuss simultanious operations, muster areas, hazards and mitigations. 10:15 - 11 :20 1.08 DRILL P PROD2 Continue wiper trip to window. 50% returns. Clean thru OH sidetrack at 11100', and clean thru loss zone at 10985'. Return rate went from 1.69/0.8 to 1.69/0.45 as we pulled thru 10985'. Clean to window. Pull thru window, Open EDC. Pump at 2.2/0.9 11 :20 - 11 :35 0.25 DRILL P PROD2 Log tie in pass over RA tag. Make +6' correction. 11 :35 - 13:00 1.42 DRILL P PROD2 Continue back in hole. Set down at loss zone at 10985'. Had to pick up and work down thru it slow with 60L TF. Made it thru on 2nd attempt. Smooth thru OH sidetrack. 13:00 - 14:30 1.50 DRILL P PROD2 Return to drilling. ROP 50-80 fph. Drlg at 1.65/0.9/2340 free spin. Sticky pickups off bottom. 14:30 - 14:45 0.25 DRILL P PROD2 Cautionary wiper trip up a couple of hundred feet. If we have Printed: 7/1112005 10:20:33 AM BP Operations Sumrnary Report Page 18 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/28/2005 14:30 - 14:45 0.25 DRILL P PROD2 cutting beds building up, lets fight 'em now. No problems. 14:45-17:15 2.50 DRILL P PROD2 Resume drilling. 1.6/0.82/2360 psi. 800 Ibs WOB. 9.81 ppg ECD. 3263 psi BHP. IAP=262 psi, OAP=O psi. Pit vol = 372 bbls. Continuing to alternate 100 bbls of KCL with 20 bbls of mud sweeps. 17:15-18:00 0.75 DRILL P PROD2 Drill ahead from 12,432'. 18:00 - 19:10 1.17 DRILL P PROD2 Wiper to window, clean 1.6/0.4/2050/240 Had gas cut returns to 7.4 ppg density 19:10 - 20:30 1.33 DRILL P PROD2 Wiper back to TD. Set down at 10980' three times and had to drill thru it at 3'/min. Fin wiper to TD, clean and tagged at 12448' 20:30 - 00:00 3.50 DRILL P PROD2 Drill from 12448' 1.6/0.75/2175/150/45R w/1 00-300 psi ditt, 300-1000# wob wI 9.8 ppg ECD @ 3250 psi DHP w/20 bbls mud followed by 80 bbls 3% KCI at 94 deg and 5-30'/hr 6/29/2005 00:00 - 01 :20 1.33 DRILL IP PROD2 Continue drilling from 12515' 1.6/0.80/2170/150/80R wI 100-350 psi ditt, 300-1000# wob, 9.8# ECD @ 3250 psi DHP w/ 20 bbls mud followed by 80 bbls 3% KCI at 93 deg at I 10-45'/hr 01 :20 - 01 :45 0.42' DRILL P PROD2 Wiper to 12150', clean 01 :45 - 03:45 2.00 DRILL P PROD2 Drill from 12548' 1.6/0.80/2150/150/85R wI 100-450 psi ditt, I 300-1000# wob, 9.8# ECD @ 3250 psi DHP wI 20 bbls mud followed by 80 bbls 3% KCI at 94 deg at 10-35'/hr. Stacking at 12591 ' 03:45 - 05:00 1.25 DRILL P PROD2 Wiper to window. Minor overpull in cuttings bed at 12185'. Rest of hole was clean 05:00 - 05: 15 0.25 DRILL P PROD2 Log tie-in down at min rate from 10600' w/ choke SI wI 300 psi/3200 psi DHP. Corr + 10.5' 05: 15 - 06:30 1.25 DRILL P PROD2 Wiper back to TD. MW and wt loss at 10985', 11615'. Hole otherwise smooth. 06:30 - 12:15 5.75 DRILL P PROD2 Drill ahead from 12,591'. 2100 psi fs at 1.61 in/0.90 out. DPSI: 150-300. DHWOB: 0.5 - 1.5 k#. I NC/AZlTF: 92.2I77.1/100R. WHP/BHPIECD: 152/3282/9.89 ppg. IAlOAlPVT: 222/0/226 bbls. Weight transfer very good, but only taking 500 to 1000 Ibs DHWOB to drill at 30-40 fph. Must be soft formation. Continue to have very poor cuttings returns. 12:15 - 15:15 3.00 DRILL P PROD2 Begin wiper trip to 4500'. Pump 40 bbl flopro sweep while POH. Pump several 20 bbl sweeps once above window. 15:15 - 17:45 2.50 DRILL P PROD2 RIH. A lot of cuttings noted on shaker while RIH. 17:45 - 18:45 1.00 DRILL P PROD2 RIH thru window, clean. Set down once at 10985'. Wiper to TD while swap to 20k LSRV mud 18:45 - 20:30 1.75 DRILL P PROD2 Drill with mud at bit from 12751' tag at 1.6/0.8/2450/1 00/85R wI 100-400 psi ditt, 500-1200# wob at 9.9# ECD @ 3290 psi DHP at 92 deg at 10-45'hr. Open choke fully as mud displaced KCI in annulus and increased ECD's 20:30 - 00:00 3.50 DRILL P PROD2 Drill with hole fully displaced to mud 1.57/0.35/2630/0/95R wI 100-300 psi ditt, 800# wob at 10.11# ECD @ 3355 psi DHP at 91 deg 5-45'/hr. Swap to left side at 12800' 6/30/2005 00:00 - 02:30 2.50 DRILL P PROD2 Continue drilling from 12870' 1.57/0A0/2660/0/95L wI 100-300 psi ditt, 800-1300# wob at 10.28# ECD @ 3412 psi DHP at 90 deg 5-35'/hr. Last 10' took one hour-assume siderite. 02:30 - 03:50 1.33 DRILL P PROD2 Wiper to window, clean Printed: 7/11/2005 10:20:33 AM BP Operations Summary Report Page 19 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/30/2005 03:50 - 04:10 0.33 DRILL P PROD2 Pull thru window, SD pump and reboot SWS PC Log tie-in down, corr + 1.5' 04:10 - 05:30 1.33 DRILL P PROD2 Wiper back to TD. MW at 10985', MW and near set down at 11620'. Set down and stall at 12052' (twice )-ream it clean. Set down and stall at 12154'. Tag at 12898' 05:30 - 12:00 6.50 DRILL P PROD2 Drill from 12898' 1.56/0.35/2780/0/60L w/1 00-300 psi ditt, 800-1300# wob at 10.37# ECD @ 3442 psi DHP at 91 deg 1 D-40'/hr. Starting to drill wI neg surface wt 12:00 - 12:45 0.75 DRILL P PROD2 Drill ahead from 13,000'. 3200 psi fs at 1.68 in/0.35 out. DPSI: 150-300. DHWOB: 0.5 - 1.5 k#. I NC/AZlTF: 95.0/80.1/65L. WHP/BHP/ECD: 4/3478/10.49ppg. IAlOAlPVT: 139/0/261 bbls. 12:45 - 14:30 I 1.75 i DRILL P PROD2 Wiper trip to window. Smooth on trip out. 1.66 in/0.55 bpm i i out. 14:30 - 16:15 1.75 DRILL P PROD2 Continue wiper trip in hole. Slow to 5 fpm and reduce rate to 1.0 bpm at 10985'. Take a lot of weight, but popped through. I Rest of hole smooth to TD. 16:15 - 20:00 ! 3.75 DRILL P PROD2 Drill ahead from 13,050'. 3250 psi fs at 1.67 in/0.50 out bpm. I I Slow drilling. Drill to 13070' and hit a hard streak at 96 deg. I Broke thru and drilled with faster penetration to 13087' (and one sticky pickup at 13074') and see GR shift indicating I Kalubik which is TD 20:00 - 21 :30 1.50 DRILL P PROD2 Wiper to window 21 :30 - 21:45 0.25 DRILL P PROD2 Log tie-in down from 10610'. Corr +5.5' 21:45 - 23:00 1.25 DRILL P PROD2 Wiper back to TD was clean, but set down at 13072'. PUH and sticky with some drag. Call this good eventhough geo's want 20' more 23:00 - 23:30 0.50 DRILL P PROD2 Slow wiper up hole 1.6/0.48/2988/0 w/1 0.52 ECD @ 3489 psi DHP while swap to 10.0 ppg Flo Pro KWF 23:30 - 00:00 0.50 DRILL P PROD2 Wiper OOH from 13030' at 40-45'/min 1.210.5/2850/0 w/1 0.4 ECD @ 3450 psi DHP leaving 9.91# (measured at 'in' MM) mud in OH 7/1/2005 00:00 - 00:30 0.50 DRILL P PROD2 Continue wiper leaving 9.9# KWF in OH at 40-45'/min from 11700' 1.18/0.31/2860/0 wi 10.14# ECD @ 3361 psi DHP 00:30 - 02:30 2.00 DRILL P PROD2 Pull thru window clean at min rate w/1 0.24# ECD after pumping 110 bbls of 285 bbls. POOH 1.4/0.35/3600/0 w/ open choke and retums gradually improving. Flag at 8178' EOP. Red rate to 1.010.5/2050/0 while POOH to surface. Lost 72 bbls 9.9# mud on trip ooH 02:30 - 02:45 0.25 DRILL P PROD2 Flow check before LD BHA Safety mtg 02:45 - 03:30 0.75 DRILL P PROO2 LD drilling BHA. Bit was 2-1-1 (had lost one nose cutter near TO) 03:30 - 03:45 0.25 CASE P RUNPRD Safety mtg re: liner 03:45 - 07:30 3.75 CASE P RUNPRD MU Unique Indexing Shoe and BTT O-ring sub on 75 jts 2-3/8· 4.43# L-80 STL slotted and solid liner 07:30 - 08:15 0.75 CASE P RUN PRO MU Baker GS assembly on Inteq MWD BHA. Engage deployment sleeve on liner. Get on well. 08:15 -11:00 2.75 CASE P RUNPRD RIH with 2-318· slotted liner assembly. Tie into EOP flag. -24' correction. Up wt: 28.5k#. 10k# dn wt at window. Continue to RIH. Set down at 10982'. PU. RIH smooth to 13000' Printed: 7/11/2005 10:20:33 AM BP Operations Summary Report Page 20 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-37 1 D-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 Date From - To Hours Task Code NPT Phase Description of Operations 7/1/2005 11 :00 - 11 :30 0.50 CASE P RUNPRD Log up and down at 2 fpm to verify depth of liner top. 36.5k# up wt, 5k# dn wt. Log RA tag and RIH additional 10'. Liner top at 10,610', bottom at 12988' Close EDC and bring pump on line. 4100 psi @ 1.37 bpm. PU from liner, free at 24k# up wt. 11 :30 - 13:30 2.00 CASE P RUNPRD POOH. Fill hole down coil. 13:30 - 14:00 0.50 CASE P RUNPRD At surface. Get off well. Unstab coil. LD liner running tools. 14:00 - 15:00 1.00 FISH P PROD2 MU Wthfrd whipstock retrieval assembly (MWD, motor, box tap). Stab coil. Get on well. 15:00 - 16:45 1.75 FISH P PROD2 RIH. Fill across top due to surge losses. Up wt: 22.5k#. 16:45 - 17:15 0.50 FISH P PROD2 Engage WS at 3 fpm, circ at 1.25 bpm @ 2650 psi. Tag WS at 10610'. Set dn 4000#. PU 28k#. Slack off. PU to 30k#. Set dn. PU to 40k#. WS popped free (we think). Open EDC. 17:15 - 18:45 1.50 FISH P PROD2 I POOH to check recover. Fill hole through EDC wI 9.4# mud I due to losses of 9.9# mud on trips 18:45 - 19:00 0.25 FISH P PROD2 I Flow check/safety mtg Grading/leveling 1 D-42 location 19:00 - 19:30 0.50 FISH P PROD2 Find that WIS disconnect had disconnected leaving box tap and lower part of disconnect in hole (+/-2.0'). LD WIS motor and upper part of disconnect. Stand back BHI BHA. Close swab on full hole 19:30 - 23:00 3.50 FISH N DFAL PROD2 WO WIS to obtain a 3" GS from Deadhorse shop 23:00 - 23:45 0.75 FISH N DFAL PROD2 Open swab-static. MU BHA (WIS hyd GS) 23:45 - 00:00 0.25 FISH N DFAL PROD2 RIH wI BHA #18 circ thru tool 0.34/0.80/1055 7/2/2005 00:00 - 01 :40 1.67 FISH N DFAL PROD2 Continue RIH to retrieve WS filling from BS after losses became excessive 01 :40 - 02:10 0.50 FISH N DFAL PROD2 10550' 25.0k PVT 124 RIH and lost wt at 10609' CTD. PUH to verify latched to 29k. Then pull wlo jars to 45k and hold. Repeat 7 more times and had immediate loss of weight back to normal string wt. Open EDC and switch to filling wI CT 02:10 - 04:20 2.17 FISH N DFAL PROD2 POOH to check recovery filling down CT at 0.8/0.2/1470. Had returns cut wIg as to 9.27 ppg. Flowcheck at 200' 04:20 - 05:00 0.67 FISH N DFAL PROD2 Pull BHA out of hole. No recovery-dogs may not have been fully engaged. MU same BHA 05:00 - 07:00 2.00 FISH N DFAL PROD2 RIH w/ BHA #19 wlo pump (low on fluid). Returns were gas cut to 8.5 ppg, but increasing in density. Returns decreasing by 2700' so SI well. Fill w/ charge pump dn BS 07:00 - 07:20 0.33 FISH N DFAL PROD2 Wt check: 24k# up, 10k# dn wt. Close EDC. Circulate through coil to make sure GS is clear. 1300 psi @ 0.52 bpm. Tag fish at 10608'. Set dn 3k#. PU to 24k to stroke out jars. No overpull while PU. Either fish is free or GS did not engage. PU and set 4k# while circ at 0.5 bpm. No over pull. Set dn 4k# one more time. PU. No overpull. 07:20 - 09:15 1.92 FISH N DFAL PROD2 POOH. Hold 300 psi WHP to maintain overbalance. Hole taking more than enough fill. Hold PJSM in ops cab before reaching surface. 09:15 - 10:00 0.75 FISH N DFAL PROD2 Tag up. Get off well. Unstab coil. Whipstock assembly recovered. LD ws and Inteq tools. Printed: 7/1112005 10:20:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 21 of 21 BP Operations Summary Report 1 0-37 1 0-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/12/2005 Rig Release: 7/2/2005 Rig Number: Spud Date: 1/15/2001 End: 7/2/2005 712/2005 10:00 - 13:30 From - To Hours Task Code NPT Phase Description of Operations Date 13:30 - 16:30 3.50 CLEAN P 3.00 DEMOS P CLEAN Displace tbg with 70 bbls kcl water followed by 22 bbls diesel to FP to 2500'. 450 psi WHP with 8.4 ppg kcl, 538 psi WHP wtih 2500' diesel on top of kcl. POST Secure well. Clean pits. ND BOPs. NU tree cap. Prep location and equipment for move to 1 D-42. Release rig at 1630 hrs 7/212005 Printed: 7/1112005 10:20:33 AM y ConocoPhillips .Baker Hughes INTEQ . Baker Hughes INTEQ Survey Report INTEQ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1 D Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57.217 N From: Map Easting: 560670.61 ft Longitude: 149 30 31.143W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.46 deg Well: 1 D-37 Slot Name: Well Position: +N/-S -75.40 ft Northing: 5959174.03 ft - Latitude: 70 17 56.476 N +E/-W -0.57 ft Easting : 560670.65 ft - Longitude: 149 30 31.160 W Position Uncertainty: 0.00 ft Wellpath: 1 D-37L2 Drilled From: 1O-37L2PB1 Tie-on Depth: 11100.00 ft Current Datum: 1 D-37 Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/11/2005 Declination: 24.28 deg Field Strength: 57606 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 128.52 Survey Program for Definitive Wellpath Date: 7/11/2005 Validated: No Actual From To Survey ft ft 120.00 10577.14 10595.00 11075.93 11100.00 13087.00 Version: 0 Toolcode Tool Name 10-37 (120.00-11003.00) (0) MWD (10595.00-11546.00) (2) MWD (11100.00-13087.00) MWD MWD MWD MWD - Standard MWD - Standard MWD - Standard Annotation Survey: MWD Start Date: 7/11/2005 Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Engineer: Tied-to: From: Definitive Path 11075.93 67.53 6481.07 6375.07 -4913.53 4959.00 5954301.16 565668.68 6939.96 0.00 MWD 11100.00 63.21 6480.96 6374.96 -4903.50 4980.87 5954311.37 565690.47 6950.83 18.42 MWD 11129.47 67.68 6481.75 6375.75 -4891.26 5007.65 5954323.82 565717.14 6964.16 21.83 MWD 11159.58 70.45 6483.68 6377.68 -4880.53 5035.71 5954334.78 565745.12 6979.43 9.26 MWD 11189.93 75.65 6484.93 6378.93 -4871.69 5064.71 5954343.85 565774.04 6996.61 18.69 MWD 11219.57 89.34 80.48 6485.41 6379.41 -4865.57 5093.70 5954350.21 565802.97 7015.48 16.40 MWD 11249.70 89.92 85.20 6485.61 6379.61 -4861.81 5123.58 5954354.20 565832.82 7036.52 15.78 MWD 11281.88 89.43 89.01 6485.79 6379.79 -4860.19 5155.71 5954356.09 565864.94 7060.65 11.94 MWD 11314.05 88.54 93.18 6486.36 6380.36 -4860.80 5187.87 5954355.73 565897.09 7086.19 13.25 MWD 11357.46 87.90 98.82 6487.71 6381.71 -4865.33 5231.00 5954351.55 565940.25 7122.76 13.07 MWD 11387.69 89.03 103.13 6488.52 6382.52 -4871.09 5260.66 5954346.04 565969.96 7149.54 14.73 MWD 11418.85 89.28 107.85 6488.98 6382.98 -4879.41 5290.67 5954337.96 566000.04 7178.21 15.17 MWD Conoc~illips -Baker Hughes INTEQ _ Baker Hughes INTEQ Survey Report 11448.44 87.28 108.43 6489.87 6383.87 -4888.61 5318.78 5954328.98 566028.21 7205.93 7.04 MWD 11479.61 86.76 104.76 6491.49 6385.49 -4897.50 5348.61 5954320.34 566058.11 7234.80 11.88 MWD 11509.66 88.63 100.79 6492.70 6386.70 -4904.14 5377.88 5954313.94 566087.43 7261.84 14.59 MWD 11543.54 88.39 95.04 6493.58 6387.58 -4908.80 5411.41 5954309.54 566121.00 7290.98 16.98 MWD 11573.26 89.25 91.03 6494.19 6388.19 -4910.37 5441.08 5954308.21 566150.67 7315.17 13.80 MWD 11603.38 86.45 87.62 6495.32 6389.32 -4910.02 5471.17 5954308.81 566180.75 7338.49 14.64 MWD 11633.54 85.99 82.03 6497.31 6391.31 -4907.31 5501.13 5954311.76 566210.69 7360.24 18.56 MWD 11665.38 87.16 76.60 6499.22 6393.22 -4901.42 5532.35 5954317.91 566241.85 7381.00 17.42 MWD 11696.38 87.37 73.57 6500.70 6394.70 -4893.45 5562.26 5954326.12 566271.70 7399.44 9.79 MWD 11728.28 87.19 69.86 6502.21 6396.21 -4883.45 5592.51 5954336.35 566301.87 7416.89 11.63 MWD 11758.67 86.23 66.43 6503.96 6397.96 -4872.16 5620.67 5954347.87 566329.93 7431.88 11.70 MWD 11797.19 86.11 61.05 6506.53 6400.53 -4855.16 5655.12 5954365.15 566364.24 7448.25 13.94 MWD 11831.66 88.14 65.92 6508.26 6402.26 -4839.80 5685.92 5954380.75 566394.91 7462.78 15.29 MWD 11860.56 87.71 69.95 6509.31 6403.31 -4828.95 5712.68 5954391.82 566421.58 7476.96 14.01 MWD 11895.94 86.30 73.75 6511.16 6405.16 -4817.95 5746.25 5954403.09 566455.05 7496.37 11.44 MWD 11925.85 85.81 77.88 6513.21 6407.21 -4810.64 5775.17 5954410.63 566483.91 7514.44 13.87 MWD 11956.43 85.96 84.58 6515.41 6409.41 -4805.99 5805.30 5954415.52 566514.00 7535.12 21.86 MWD 11987.42 87.96 90.80 6517.06 6411.06 -4804.74 5836.20 5954417.02 566544.89 7558.52 21.06 MWD 12017.89 87.22 96.19 6518.34 6412.34 -4806.60 5866.58 5954415.41 566575.28 7583.45 17.84 MWD 12048.33 88.33 99.94 6519.52 6413.52 -4810.86 5896.69 5954411.39 566605.42 7609.66 12.84 MWD 12079.97 87.13 103.60 6520.77 6414.77 -4817.31 5927.63 5954405.19 566636.41 7637.89 12.16 MWD 12110.14 86.48 103.24 6522.46 6416.46 -4824.30 5956.93 5954398.44 566665.76 7665.17 2.46 MWD 12142.00 85.99 97.66 6524.55 6418.55 -4830.07 5988.18 5954392.92 566697.06 7693.21 17.54 MWD 12175.10 87.52 93.76 6526.42 6420.42 -4833.35 6021.06 5954389.90 566729.95 7720.97 12.64 MWD 12205.53 92.13 90.19 6526.52 6420.52 -4834.40 6051.46 5954389.10 566760.36 7745.41 19.16 MWD 12244.48 89.89 82.34 6525.83 6419.83 -4831.87 6090.28 5954391.95 566799.16 7774.21 20.95 MWD 12279.25 92.75 76.65 6525.03 6419.03 -4825.53 6124.45 5954398.56 566833.27 7796.99 18.31 MWD 12310.40 91.25 71.86 6523.94 6417.94 -4817.09 6154.40 5954407.24 566863.15 7815.17 16.10 MWD 12345.79 89.34 66.19 6523.76 6417.76 -4804.43 6187.43 5954420.17 566896.07 7833.12 16.91 MWD 12375.77 90.51 62.05 6523.80 6417.80 -4791.34 6214.39 5954433.47 566922.93 7846.08 14.35 MWD 12413.60 90.32 58.34 6523.52 6417.52 -4772.54 6247.21 5954452.53 566955.59 7860.04 9.82 MWD 12443.85 93.49 59.98 6522.52 6416.52 -4757.05 6273.17 5954468.24 566981.42 7870.70 11.80 MWD 12473.89 94.49 64.77 6520.43 6414.43 -4743.15 6299.71 5954482.34 567007.84 7882.81 16.25 MWD 12503.04 93.64 70.14 6518.36 6412.36 -4732.01 6326.56 5954493.70 567034.59 7896.88 18.61 MWD 12533.24 93.40 73.57 6516.50 6410.50 -4722.63 6355.20 5954503.32 567063.15 7913.44 11.36 MWD 12575.38 93.79 77.13 6513.86 6407.86 -4711.99 6395.88 5954514.28 567103.75 7938.65 8.48 MWD 12605.51 92.20 80.56 6512.29 6406.29 -4706.17 6425.39 5954520.34 567133.21 7958.11 12.53 MWD 12641.16 92.23 85.99 6510.91 6404.91 -4702.00 6460.76 5954524.79 567168.54 7983.19 15.22 MWD 12672.12 91.73 90.78 6509.84 6403.84 -4701.13 6491.68 5954525.91 567199.45 8006.84 15.55 MWD 12704.02 91.18 94.96 6509.03 6403.03 -4702.73 6523.52 5954524.57 567231.30 8032.74 13.21 MWD 12734.29 90.90 100.28 6508.48 6402.48 -4706.74 6553.51 5954520.80 567261.31 8058.70 17.60 MWD 12764.65 91.33 104.33 6507.88 6401.88 -4713.20 6583.16 5954514.58 567291.01 8085.93 13.41 MWD 12794.66 91.06 107.68 6507.26 6401.26 -4721.48 6611.99 5954506.54 567319.91 8113.64 11.20 MWD 12824.77 90.08 104.37 6506.96 6400.96 -4729.79 6640.93 5954498.46 567348.91 8141.46 11.46 MWD 12854.31 90.57 99.81 6506.79 6400.79 -4735.97 6669.81 5954492.51 567377.83 8167.90 15.53 MWD 12886.40 90.72 95.23 6506.43 6400.43 -4740.17 6701.61 5954488.57 567409.67 8195.40 14.28 MWD 12920.35 91.77 89.00 6505.69 6399.69 -4741.42 6735.51 5954487.59 567443.57 8222.70 18.60 MWD 12950.81 91.83 84.81 6504.73 6398.73 -4739.78 6765.90 5954489.48 567473.95 8245.46 13.75 MWD 12981.11 91.49 80.10 6503.86 6397.86 -4735.80 6795.92 5954493.70 567503.93 8266.47 15.58 MWD 13012.77 92.42 76.93 6502.78 6396.78 -4729.50 6826.92 5954500.25 567534.88 8286.80 10.43 MWD 13041.71 95.55 75.20 6500.76 6394.76 -4722.55 6854.94 5954507.42 567562.84 8304.39 12.35 MWD ./ 13087.00 95.55 75.20 6496.38 6390.38 -4711.04 6898.52 5954519.29 _ 567606.32 - 8331.32 0.00 MWD Conoc;pt,illips -Baker Hughes INTEQ - Baker Hughes INTEQ Survey Report ... Bf&'Iœ. INTEQ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959249.42 ft 560670.61 ft Latitude: 70 17 Longitude: 149 30 North Reference: Grid Convergence: 57.217 N 31.143 W True 0.46 deg Well: 1D-37 Slot Name: Well Position: +N/-S +E/-W Position Uncertainty: -75.40 ft Northing: -0.57 ft Easting: 0.00 ft 5959174.03 ft 560670.65 ft Latitude: Longitude: 70 17 56.476 N 149 30 31.160W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1 D-37 10595.00 ft Mean Sea Level 24.43 deg 80.75 deg Direction deg 128.52 Wellpath: 1D-37L2PB1 Current Datum: Magnetic Data: Field Strength: Vertical Section: 1 D-37 3/8/2005 57594 nT Depth From (TVD) ft 0.00 Height 106.00 ft Survey Program for Definitive Wellpath Date: 7/11/2005 Validated: No Actual From To Survey ft ft 120.00 10577.14 10595.00 11546.00 Version: Toolcode Tool Name 10-37 (120.00-11003.00) (0) MWD (10595.00-11546.00) MWD MWD MWD - Standard MWD - Standard Annotation Survey: MWD Start Date: 7/11/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey 10577.14 67.88 136.19 6441.60 6335.60 -4779.09 4513.88 5954431.99 565222.53 6507.98 0.00 MWD 10595.00 67.84 136.39 6448.33 6342.33 -4791.05 4525.31 5954420.13 565234.06 6524.37 1.06 MWD 10625.87 71.18 132.56 6459.14 6353.14 -4811.30 4545.94 5954400.05 565254.85 6553.12 15.88 MWD 10655.83 74.98 128.98 6467.86 6361.86 -4830.00 4567.65 5954381.52 565276.71 6581.75 17.07 MWD 10685.54 77.75 125.54 6474.86 6368.86 -4847.47 4590.63 5954364.24 565299.82 6610.61 14.61 MWD 10717.71 80.52 121.92 6480.93 6374.93 -4865.01 4616.90 5954346.92 565326.23 6642.08 14.01 MWD 10746.60 84.05 118.72 6484.81 6378.81 -4879.45 4641.60 5954332.68 565351.05 6670.41 16.42 MWD 10776.38 90.66 116.86 6486.18 6380.18 -4893.31 4667.91 5954319.03 565377.46 6699.62 23.06 MWD 10807.58 89.68 111.62 6486.09 6380.09 -4906.12 4696.34 5954306.46 565406.00 6729.85 17.09 MWD 10838.19 87.00 104.43 6486.98 6380.98 -4915.58 4725.42 5954297.23 565435.14 6758.49 25.06 MWD 10867.74 90.35 102.23 6487.66 6381.66 -4922.39 4754.16 5954290.65 565463.94 6785.21 13.56 MWD Conoc;Phillips -Baker Hughes INTEQ _ Baker Hughes INTEQ Survey Report 10898.52 93.36 98.15 6486.66 6380.66 -4927.83 4784.43 5954285.46 565494.24 6812.28 16.47 MWD 10941.81 93.21 93.82 6484.18 6378.18 -4932.34 4827.40 5954281.30 565537.25 6848.71 9.99 MWD 10975.13 91.49 88.68 6482.81 6376.81 -4933.06 4860.67 5954280.84 565570.52 6875.19 16.25 MWD 11013.27 91.49 81.24 6481.82 6375.82 -4929.71 4898.62 5954284.50 565608.44 6902.80 19.50 MWD 11045.12 90.72 75.49 6481.21 6375.21 -4923.29 4929.80 5954291.17 565639.56 6923.20 18.21 MWD 11075.93 89.77 67.53 6481.07 6375.07 -4913.53 4959.00 5954301.16 565668.68 6939.96 26.02 MWD 11105.61 91.00 62.20 6480.87 6374.87 -4900.93 4985.86 5954313.98 565695.43 6953.13 18.43 MWD 11135.30 92.47 66.14 6479.97 6373.97 -4888.00 5012.56 5954327.12 565722.03 6965.97 14.16 MWD 11166.30 89.68 71.44 6479.39 6373.39 -4876.79 5041 .44 5954338.56 565750.82 6981.59 19.32 MWD 11198.20 91.34 77.80 6479.11 6373.11 -4868.34 5072.18 5954347.26 565781.48 7000.37 20.60 MWD 11228.76 90.48 83.33 6478.62 6372.62 -4863.33 5102.31 5954352.51 565811.57 7020.83 18.31 MWD 11259.38 92.35 86.82 64 77.87 6371.87 -4860.70 5132.80 5954355.39 565842.04 7043.05 12.93 MWD 11289.66 91.43 90.77 6476.87 6370.87 -4860.07 5163.05 5954356.27 565872.28 7066.32 13.39 MWD 11320.85 92.19 96.13 6475.88 6369.88 -4861.94 5194.16 5954354.64 565903.39 7091.82 17.35 MWD 11351.23 91.61 99.83 6474.87 6368.87 -4866.16 5224.23 5954350.67 565933.49 7117.97 12.32 MWD 11381.22 88.39 101.31 6474.87 6368.87 -4871.66 5253.70 5954345.41 565963.01 7144.46 11.82 MWD 11413.28 88.97 106.11 6475.61 6369.61 -4879.25 5284.83 5954338.07 565994.19 7173.54 15.08 MWD 11455.61 88.14 109.46 6476.68 6370.68 -4892.17 5325.12 5954325.4 7 566034.58 7213.11 8.15 MWD 11485.79 89.00 103.43 6477.43 6371.43 -4900.71 5354.04 5954317.17 566063.57 7241.06 20.18 MWD 11515.61 86.76 100.72 6478.54 6372.54 -4906.94 5383.18 5954311.17 566092.75 7267.73 11.79 MWD 11546.00 84.20 98.00 6480.93 6374.93 -4911.87 5413.06 5954306.49 566122.67 7294.19 12.27 MWD ConocoPhllllpe Alast. Inc. _ KRU Ð-37L2 1 D-37L2 API: 500292299261 Well Tvce: PROD Anqle (â) TS: de<] (â) TUBING SSSV Type: NIPPLE Orig Angle @ TD: deg@ (0-9961, Completion: OD:3.500, ID:2.992) Annular Fluid: Last W/O: Rev Reason: NEW WELL, LEG L2, GLV desiqn Reference Loq: 28.8' RKB Ref Loq Date: Last UDdate: 7/9/2005 Last Tag: TD: 12986 ftKB Last Taq Date: Max Hole Anqle: 0 d= Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED SURFACE 9.625 0 5081 5081 40.00 L-80 BTC MOD PRODUCTION 7.000 0 10093 10093 26.00 J-55 BTC MOD LINER 3.500 9920 11003 11003 9.30 L-80 SLHT L2 SLOTTED LINER 2.700 10611 12986 12986 4.43 L-80 STL Tubing Strina . TUBING Size I TOD I Bottom I TVD Wt I Grade I Thread 3.500 I 0 I 9961 I 9961 9.30 I L-80 I EUE MOD Perforations SummarY Interval TVD Zone Status Ft SPF Date TYDe Comment 10611 - 10928 10611 - 10928 317 40 6/30/2005 IPERF Alternating Slotted/Solid Jts 11054 -12037 11054-12037 983 40 6/30/2005 IPERF Alternatinq Slotted/Solid Jts 12163 - 12955 12163 - 12955 792 40 6/30/2005 IPERF Alternating Slotted/Solid Jts Gas lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2577 2577 CAMeO KBUG GLV 1.0 BK 0.188 1275 7/512005 2 4301 4301 CAMCO KBUG GLV 1.0 BK 0.250 1385 7/512005 3 6742 6742 CAMeo KBUG OV 1.0 BK 0.250 0 7/512005 4 8617 8617 CAMeo KBUG DMY 1.0 BK 0.000 0 6/4/2005 5 9825 9825 CAMCO MMG DMY 1.5 RK 0.000 0 6/6/2005 Other pluQs, eauip., etc.) - JEWELRY Depth TVD Type Description ID 522 522 NIP CAMCO DS NIPPLE wINO GO PROFILE 2.875 9878 9878 NIP CAMCO DS NIPPLE wINO GO PROFILE 2.812 9922 9922 LOCATOR BAKER LOCATOR 3.000 9924 9924 SEAL BAKER GBH-22 SEAL ASSEMBLY, 35' LONG 6.000 9927 9927 PACKER BAKER ZXP PAO<ER, w/5" TKC COUPLING 5.000 9947 9947 SBE BAKER SBE 80-40, w/TKC COUPLINGS XO 4.000 10006 10006 NIP CAMCO DS NIPPLED w/2.75" NO GO PROFILE 2.750 10594 10594 Window L2 0.000 10610 10610 Deploy Sub L2 DEPLOYMENT SUB 2.000 10928 10928 Solid Liner L2 SOLID LINER (AL TERNA TES WITH SLOTTED LINER) 1.995 12037 12037 Solid Liner L2 SOLID LINER (AL TERNA TES WITH SLOTTED LINER) 1.995 12955 12955 Solid Liner L2 SOLID LINER (ALTERNATES WITH SLOTTED LINER) 1.995 General Notes Date Note 7/1/2005 MUL T-LATERAL WELL: MAIN LEG, LATERAL LEGS L 1 & L2 TREE: FMC / GEN V SLIM HOLE / 5000 psi TREE CAP CONNECTION: 3.5" OTIS Deploy Sub .10610-10611. OD:2.700) = = == Solid Liner :10928-11054, OD:2.375) Perf 11054-12037) Perf .12163-12955) Solid Liner 12955-12988, OD:2.375) -- , (ñ)'ñ), iF ,',. ' I ~ H.-, ~u II r", ~ ' ¡ U! \:::V " iT\ /8\ IJ'¡j FRANK H. MURKOWSKI, GOVERNOR AI',ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1D-37L2 ConocoPhillips Permit No: 205-047 Surface Location: 492' FNL, 421' FEL, SEC. 23, TI1N, R10E, UM Bottomhole Location: 5194' FNL, 1305' FWL, SEC. 19, T11N, RIlE, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well KRU 1D-37, Permit No. 200-204, API No. 50-029-22992-00. 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 revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ,/S+ncerelv d:~~?:;' 'Li,>~, // /-::t//~.-, -,/ f í/j,/ -/" . 0\ 1'1 /¿/ TIaniel T. Seamount, Jr. Commissioner -f-Á DATED this ç day of April, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. "aSk:!' r, x, 1 a. Type of work o Drill a Redrill 11b, Current Well Class o Exploratory a Development Oil _~u'r ORe-Entry o Stratigraphic Test o Service o Development Gas e 2. Operator Name: 5. Bond: IBI Blanket o Single Well 11. Well Name and Number: Conoco Phillips Alaska Inc. Bond No. 59-52-180 )þ ~.I,or; KUP 1D-37L2 3. Address: 6. Proposed Depth: h?"èD f 12. Field I Pool(s): c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 13200 ' TVD 6394~ L'Ì\ Kuparuk River Unit 4a. Location of Well (GOVe~1 Section): 7. Property Designation: IftJL i¡.l,e>Ç" Surface: Igr:;;;~ç;bl4' ADL 028243 Á c>zž?:>Z'1f5 492:1NL, 421' Ør=L, SEC. 23, T11 N, R10E, UM / Top of Productive Horizon: 8, Land Use Permit: 13. Approximate Spud Date: 5268'.ßNL, 4087'S^'L, SEC. 25, T11 N, R1OE, UM April 15, 2005 Total Depth: 9, Acres in Property: 14, Distance to Nearest Property: 5194'~L, 1305'ftJL, SEC. 19, T11N, R11E, UM , 2560 1216' , 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15, Distance to Nearest Well Within Pool Surface: x-560670 '" Y-5959174 ' Zone- ASP4 (Height above GL): 104.9' feet 1 D-30 is offset by 400' 16. Deviated Wells: Kickoff Depth: 10589 .. feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 dearees Downhole: 3219 . Surface: 2580 18. casIng program: Specifications Setting D~pth ...q~(~ntityofGe~~nt Size Too ... . Bottom c.f.orsacks Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD Cincludina staae data) 3" 2-3/8" 4.6# L-80 STL 2601' 1 0599' ~ 13200' ~ Uncemented Slotted Liner I. . .""..., . , _. ~. ....- ~ \' 19. PRESENTWELL CONDITION SUMMARY (To be completed for Aedrill ANQRe-el1tryOþeratlons) < Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft):1 Junk (measured): 11003 6606 None 10719 6495 None Casing Length Size Cement Volume MD TVD r 121' 20" 1460 sx Arcticset I 121' 121' 5081' 9-5/8" ~12 sx AS III LW, 403 sx LiteCRETE 5081' 4380' 10093' 7" 170 sx Class 'G' 10093' 6262' Pr Liner 1083' 3-1/2" ~43 sx Class 'G' 9920' - 11003' 6199' - 6606' Liner 1716' 2-3/8" Uncemented Slotted Liner 10734' - 12450' 6396' - 6468' Perforation Depth MD (ft): 10705' - 10720' IPerfOration Depth TVD (ft): 6490' - 6496' ~ 20. Attachments Filing Fee, $100 IBI BOP Sketch IBI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IBI Drilling Fluid Program IBI 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 Aras Worthington, 240-5780 Printed Name Scott Kolstad Title CT Drilling Engineer Scott Kolstad, 564-5347 ~ y¿¡-/ ""> ,/ . /(- Prepared By Name/Number: Sianature Phone 564-5347 Date s/..);) CS Terrie Hubble, 564-4628 Commission Use Only Permit To Drill . I API Number: I Permit AP~/:!- Ie ~ I See cover letter for Number: Âj~ó({7 50- 029-22992-61-00 Date: Œ> OS other requirements Conditions of Approval: Samples Required [J Yes~o Mud Log Required [J Yes PrNo Hydrogen Sulfide Measures ~s No Directional Survey Required ~Yes [J No Other: ::&00 r' ~C)?~\-Cl-.s.{>\<:¡:~ .. Original Signed By 'l ç:::; \ \\\ A \ '-//ólo~ DAN SEAMOUNT APPROVED BY ADDroved Bv: ". THE COMMISSION Date 1 I I STATE OF ALASKA · ALA KA OIL AND GAS CONSERVATIO~OMMISSION PERMIT TO DRILL 20 AAC 25 005 ~I . RËCEIVEQ Ivu.t+? 2 2 20DW-~ ion Form 10-401 Revised 06/2004 Submit In Duplicate 'tRU 1 D-37L 1 and 1 D-37L2 Sidetrac! Coiled Tubing Drilling Summary of Operations: Coiled tubing drilling will drill 2 laterals in producer KRU ID-37 using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). This horizontal laterals will target Kuparuk C sand reserves for production. The Kuparuk C Sand perforations in the existing welllD-37 will be retained. CTD Drill and Complete ID-37Ll & ID-37L2 proeram: Planned for April 15. 2005 1. Pre CTD Positive pressure and drawdown tests on MV and SV 2. Pre CTD MIT-IA, MIT-OA 3. Pre CTD Caliper 3-112" liner 4. Pre CTD drift tubinglliner with dummy whipstock 5. MIRU Nordic 2. NU 7-1116" BOPE, test. 6. Set 3-112" LSX whipstock @ 10,744' md. 7. Mill 2.74" window at 10,744 md and 10' of openhole. 8. Drill 3" bicenter hole horizontal lateral from window to -12,450' TD targeting Kuparuk C1IC2 sands. 9. Kill well wI brine & Complete with 2 3/8" slotted liner from TD 12,450' up into the 3-112" liner to ~ -10,734' . 1 Ö~~a erford packer - 10,604' md 11. Stab into packer with retrievab!y 3-112" whipstock, targeting top of whipstock @ 10,589' md. 12. Mill 2.74" window at 10,589' md and 10' of openhole.'/ / 13. Drill 3" bicenter hole horizontal lateral from window to -13,200' TD targeting Kuparuk C3/C4 sands. 14. Kill well wI brine & Complete with 2 3/8" slotted liner from TD 13,200', to 5'-10' outside the 3-112" casing exit -10,599' . / 15. ND BOPE. RDMO Nordic 2. 16. Post CTD rig -Run GL V s. BOL. T~\c:, ~<L'~"-\- -~,~-- ~-- Mud Program: · Step 7: 8.7 ppg chloride-based biozan brine · Steps 8, 10-13: chloride-based Flo-Pro (8.6 ppg) · Steps 9 & 14: Viscosified potassium formate KWF (10.0 ppg) Disposal: · No annular injection on this well. " · Class II liquids to KRU lR Pad Class II disposal well / · Class II drill solids to Grind & Inject at PBU Drillsite 4 / · Class I wastes will go to Pad 3 for disposal. ,/ Casing Program: · ID-37L1: 23/8",4.6#, L-80, STL slotted linerfrom 10,734' md to 12,450' md · ID-37L2: 23/8",4.6#, L-80, STL slotted liner from 10,599' md to 13,200' md ,/ · Well Control: · Two wellbore volumes (--270 bbls) of KWF will be location during drilling operations. · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for ID-37L1 & ID-37L2 / · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · The nearest well to ID-37Ll is ID-30 which is offset by 1170'. KRU boundary is 2046' away. / 4ItRU 1 D-37L 1 and 1 D-37L2 Sidetrac," Coiled Tubing Drilling · The nearest well to ID-37L2 is ID-30 which is offset by 400'. KRU boundary is 1216' away. /~ Logging . A MWD Gamma Ray log will be run. ,/ Hazards · There are several mapped faults in the planned well path; lost circulation risk is therefore high. High pressure is not expected. ,/ · WelllD-37 has a H2S reading of 70 ppm. ID is an H2S pad, the highest H2S measurement on the pad is 120 ppm. All H2S monitoring equipment will be operational. "" Reservoir Pressure ;' -:.(o4c; \~t'\:.~ ::::s S,StH VV · The latest Shut in bottom hole pressure is approximately 3219 psi at 6385' TVD, 10.0 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2580 psi. ~ DOBCTD Pressure Drilling ,/ Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.7 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 wellbores. 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. Estimated reservoir pressure: 3219 psi at 6385' TVD, 10.0 ppg EMW. ,/ Expected annular friction losses while circulating: 1080 psi Planned mud density: 8.6 ppg equates to 2855 psi hydrostatic bottom hole pressure. While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3935 psi or 11.8 ppg ECD When circulation is stopped, a minimum of 950 psi surface pressure will be applied to maintain constant ' BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by swapping the wellbore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (minimum weight = 10.0 ppg for overbalance) . . ConocoPhllllps Alaska, Inc. . KRU 1 D-37 10-37 API: 500292299200 Well Tvoe: PROD Annie (ij¡ TS: 68 dea @ 10573 SSSV Type: NIPPLE Orig 1/1512001 Angle @ TD: 67 deg @ 11003 lIP (522-523, Comoletion: 00:4.520) Annular Fluid: Last W/O: Rev Reason: Taafill Reference Loa: Ref Loa Date: Last Uodate: 4/4/2004 Last T ao: 10719 TD: 11003 ftKB Last Tao Date: 41212004 Max Hole Anole: 70 deo (ij¡ 6926 Gas LIft Casino StrIno - CASING MandntllValw Descrlotlon Size Too Bottom TVD Wt Grade Thread 1 CONDUCTOR 20.000 0 120 120 91.50 H-40 WELDED (2577-2578, SURF CASING 9.625 0 5081 4380 40.00 L-80 BTC MOD PROD CASING 7.000 0 10093 6262 26.00 J-55 BTC MOD LINER 3.500 9920 11003 11003 9.30 L-80 SLHT Gas LIft Tublna Strino - TUBING MandntllValw 2 Size I TOD I Bottom I TVD I Wt I Grade T Thread (4301.01302, 3.500 I 0 I 9961 I 6214 I 9.30 I L-80 I EUE 8rd Perforations Summerv Interval TVD I Zone I Status I Ft T SPFì Date I Tv.... I Comment Gas LIft 10705 - 10720 6490 - 6496 I C-3 I I 15 I 6 ì 2I251200fl IPERF 12.5"HSD 60 deo ohase MandntllValw StImulations & Treatments 3 (6742-6743, Interval I Date I Tvoe I Comment 10705-10720 I 3/1112001 IFRAC I Gas Uft MandnJIsNalves . Gas LIft St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date VIv MandntllV_ Mfr Run Cmnt 4 1 2577 2574 CAMeO KBUG CAMeo GLV 1.0 BK 0.156 1226 3/2312001 (8617"18, 2 4301 4030 CAMeo KBUG CAMeo GLV 1.0 BK 0.188 1261 3/2312001 3 6742 5007 CAMeo KBUG CAMeo GLV 1.0 BK 0.250 1355 3/2312001 Gas LIft 4 8617 5700 CAMeo KBUG CAMeo OV 1.0 BK 0.250 0 3/2312001 IIIdreI/Dummy 5 9825 6164 CAMeo MMG CAMeo DMY 1.5 RK 0.000 0 2/1912001 Valw 5 Other (I lloos. E ulo. etcJ - JEWELRY (9825-9826, Death TVD Tvoe Descrintinn ID 00:5.968) 522 522 NIP Cameo DS NiDDle wINo Go Profile 2.875 NIP 9878 6183 NIP Cameo DS NiDDle wINo-Go Profile 2.812 (9878-9879, 9922 6200 NIP Baker Locater 3.000 00:4.520) 9924 6200 SEAL Baker GBH-22 Seal Assemblv: 35' Iono 3.000 9927 6202 PKR Baker ZXP Packer w/5" TKC counlino 5.000 lUSING ¡¡ 9947 6209 SBE Baker SBE 80-40 wrrKC counlinn.c:: & XO 4.000 (CHI961, 10006 6230 NIP Cameo DS NiDDlewl2.75" No-Go 2.750 00:3.500, 11001 6605 SHOE Baker Float Shoe 0.000 )-.2.992) SEAl (9924-W25, 00:4.(00) lillER (9920-11003, 00:3.500, Wl"9.3O) PKR (9927-9928, 00:7.(00) PRoa . CASING (0-10093, 00:7.000, Wt26.oo) SSE 01 (9947-9948, 00:5.(00) ----' NIP - :10006-10007, 00:4.520) Perf - - ~ :10705-10720) - - FRAC - - J705-1072O) I J l KRU 1 D-37L 1 & L2 Producer Proposed Com pletion 3-1/2" Cameo DB nipple, 2.875" min ID at 522' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing ~ ConocoPhillips Alaska, Inc. 3-Y2" Cameo KBUG GLM @ 2577',4301',6742',8617', & 9825' MD . 9-518" 40# L-80 0 5081' 3-%" Cameo DS nipple, 2.812" min ID @ 9878' MD @ 9927' MD 7" 26. J-55 0 10093' MO 2-3/8· liner top @ +/·10599' MD . 3" openhole Packer, 1.25' ID +/-10604' MD C3 Sand perfs L1 KOP 10744 'MD 2-3/8· Baker deployment sub @ 10734' md 3" openhole C1/C2 - Sands 3-W LSX WS 3-112" 9.3# L-80 o 11003 MO' Fill \\)-~'"' L~ 1 D-37L2 Lateral, TO @ 13200· md 2-3/8" slotted liner . 2-3/8" slotted liner 1 0-37L 1, TO @ 12450' md 02/25/05 y . - ConocoPhillips Baker Hughes INT~ Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1 D Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: 10-37 Well Position: +N/-S +E/-W Position Uncertainty: -75.40 ft Northing: -0.57 ft Easting: 0.00 ft 5959249.42 ft Latitude: 70 17 57.217 N 560670.61 ft Longitude: 149 30 31.143 W North Reference: True Grid Convergence: 0.46 deg Slot Name: 5959174.03 ft ,. Latitude: 70 17 56.476 N 560670.65 ft ,. Longitude: 149 30 31.160 W Wellpath: 1O-37L2 Current Datum: Magnetic Data: Field Strength: Vertical Section: 10-37 3/8/2005 57594 nT Depth From (TVO) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1O-37L 1 10485.97 ft Mean Sea Level 24.43 deg 80.75 deg Direction deg 123.84 Height 106.00 ft +N/-S ft 0.00 Plan: Plan #4 Copy Lamar's Plan#4 Principal: Yes Targets Date Composed: Version: Tied-to: 3/8/2005 2 From: Definitive Path 10485.97 10589.00 10609.00 10810.00 11060.00 11310.00 11510.00 11610.00 11885.00 12160.00 12235.00 12385.00 12510.00 12635.00 12935.00 13200.00 6407.66 6446.07 6453.35 6489.20 6482.50 6474.47 6472.44 6476.11 6498.97 6518.68 6520.90 6518.27 6514.13 6510.69 6504.45 6499.92 TIP KOP End 9°/100 DLS 4 5 6 7 8 9 10 11 12 13 14 15 TD y . - ConocoPhillips Baker Hughes INT:fQ Baker Hughes INTEQ Planning Report INTEQ 10485.97 68.41 136.10 6407.66 -4718.08 4455.25 0.00 0.00 0.00 0.00 10577.14 67.88 136.19 6441.60 -4779.09 4513.88 0.59 -0.58 0.10 171.06 10589.00 67.86 136.32 6446.07 -4787.03 4521.48 1.03 -0.17 1.10 99.45 10609.00 69.42 135.36 6453.35 -4800.39 4534.45 9.00 7.81 -4.81 330.00 10810.00 90.00 122.50 6489.20 -4923.15 4687.59 12.00 10.24 -6.40 327.00 11060.00 93.00 92.63 6482.50 -4997.76 4923.12 12.00 1.20 -11 .95 276.00 11310.00 90.60 62.71 6474.47 -4944.99 5164.44 12.00 -0.96 -11.97 266.00 11510.00 90.55 86.71 6472.44 -4892.65 5355.95 12.00 -0.03 12.00 90.00 11610.00 85.25 97.49 6476.11 -4896.30 5455.63 12.00 -5.30 10.78 116.30 11885.00 85.48 64.38 6498.97 -4853.73 5722.51 12.00 0.08 -12.04 269.00 12160.00 86.53 97.45 6518.68 -4811.08 5989.62 12.00 0.38 12.02 89.40 12235.00 90.07 89.17 6520.90 -4815.39 6064.39 12.00 4.72 -11.04 293.00 12385.00 91.92 71.26 6518.27 -4790.02 6211.58 12.00 1.23 -11.94 276.00 12510.00 91.86 86.27 6514.13 -4765.75 6333.76 12.00 -0.05 12.01 90.00 12635.00 91.28 101.26 6510.69 -4773.94 6458.09 12.00 -0.46 12.00 92.00 12935.00 91.03 65.26 6504.45 -4739.32 6751.08 12.00 -0.08 -12.00 270.00 13200.00 90.88 97.06 6499.92 ~ -4699.12 7009.54 12.00 -0.06 12.00 90.00 Survey 10485.97 68.41 136.10 6301.66 -4718.08 4455.25 5954492.53 565163.42 0.00 6327.83 0.00 MWD 10500.00 68.33 136.11 6306.83 -4727.48 4464.30 5954483.20 565172.54 0.59 6340.58 171.06 MWD 10525.00 68.18 136.14 6316.09 -4744.22 4480.39 5954466.59 565188.76 0.59 6363.27 171.06 MWD 10550.00 68.04 136.16 6325.41 -4760.94 4496.46 5954450.00 565204.97 0.59 6385.93 171.05 MWD 10575.00 67.89 136.19 6334.79 -4777.66 4512.51 5954433.41 565221.15 0.59 6408.57 171.04 MWD 10577.14 67.88 136.19 6335.60 -4779.09 4513.88 5954431.99 565222.53 0.59 6410.51 171.03 MWD ....10589.00 67.86 136.32 6340.07 -4787.03 4521.48 5954424.12 565230.19 1.03 6421.24 99.45 MWD 10600.00 68.72 135.79 6344.14 -4794.39 4528.57 5954416.82 565237.34 9.00 6431.22 330.00 MWD 10609.00 69.42 135.36 6347.35 -4800.39 4534.45 5954410.86 565243.27 9.00 6439.45 330.20 MWD 10625.00 71.04 134.25 6352.76 -4811.00 4545.13 5954400.34 565254.04 12.00 6454.24 327.00 MWD 10650.00 73.57 132.57 6360.36 -4827.37 4562.44 5954384.12 565271.47 12.00 6477.72 327.37 MWD 10675.00 76.12 130.93 6366.90 -4843.43 4580.44 5954368.20 565289.60 12.00 6501.62 327.89 MWD 10700.00 78.67 129.32 6372.35 -4859.15 4599.09 5954352.63 565308.38 12.00 6525.86 328.32 MWD 10725.00 81.24 127.74 6376.71 -4874.48 4618.35 5954337.46 565327.76 12.00 6550.40 328.67 MWD 10750.00 83.81 126.18 6379.96 -4889.38 4638.15 5954322.72 565347.68 12.00 6575.14 328.94 MWD 10775.00 86.39 124.64 6382.10 -4903.81 4658.45 5954308.45 565368.09 12.00 6600.04 329.14 MWD 10800.00 88.97 123.11 6383.11 -4917.74 4679.19 5954294.70 565388.94 12.00 6625.02 329.28 MWD 10810.00 90.00 122.50 6383.20 -4923.15 4687.59 5954289.35 565397.39 12.00 6635.02 329.34 MWD 10825.00 90.19 120.71 6383.18 -4931.01 4700.37 5954281.60 565410.22 12.00 6650.00 276.00 MWD 10850.00 90.50 117.73 6383.02 -4943.21 4722.19 5954269.57 565432.14 12.00 6674.92 276.00 MWD 10875.00 90.82 114.74 6382.74 -4954.26 4744.61 5954258.71 565454.64 12.00 6699.69 275.98 MWD 10900.00 91.13 111.76 6382.31 -4964.13 4767.57 5954249.03 565477.68 12.00 6724.26 275.94 MWD 10925.00 91.43 108.77 6381.75 -4972.78 4791.01 5954240.56 565501.19 12.00 6748.56 275.89 MWD 10950.00 91.73 105.79 6381.06 -4980.21 4814.87 5954233.33 565525.11 12.00 6772.51 275.83 MWD 10975.00 92.03 102.80 6380.24 -4986.37 4839.08 5954227.36 565549.37 12.00 6796.05 275.74 MWD 11000.00 92.32 99.81 6379.29 -4991.27 4863.58 5954222.66 565573.90 12.00 6819.12 275.65 MWD 11025.00 92.61 96.82 6378.21 -4994.88 4888.29 5954219.25 565598.64 12.00 6841.66 275.53 MWD 11050.00 92.89 93.83 6377.01 -4997.20 4913.15 5954217 .13 565623.51 12.00 6863.60 275.40 MWD 11060.00 93.00 92.63 6376.50 -4997.76 4923.12 5954216.65 565633.49 12.00 6872.20 275.26 MWD 11075.00 92.87 90.84 6375.73 -4998.22 4938.09 5954216.32 565648.46 12.00 6884.89 266.00 MWD 11100.00 92.65 87.84 6374.53 -4997.93 4963.06 5954216.81 565673.42 12.00 6905.46 265.91 MWD 11125.00 92.43 84.85 6373.42 -4996.34 4987.98 5954218.60 565698.33 12.00 6925.28 265.76 MWD 11150.00 92.20 81.85 6372.41 -4993.45 5012.79 5954221.69 565723.11 12.00 6944.27 265.63 MWD 11175.00 91.96 78.86 6371.50 -4989.26 5037.42 5954226.08 565747.70 12.00 6962.40 265.51 MWD 11200.00 91.72 75.87 6370.70 -4983.80 5061.80 5954231.74 565772.03 12.00 6979.61 265.40 MWD Conc>cÓPhillips · Baker Hughes INT! Baker Hughes INTEQ Planning Report INTEQ 11225.00 91.47 72.88 6370.01 -4977.07 5085.86 5954238.66 565796.04 12.00 6995.85 265.31 MWD 11250.00 91.22 69.89 6369.42 -4969.09 5109.55 5954246.83 565819.65 12.00 7011.08 265.22 MWD 11275.00 90.96 66.90 6368.95 -4959.88 5132.78 5954256.22 565842.81 12.00 7025.25 265.15 MWD 11300.00 90.70 63.91 6368.58 -4949.48 5155.51 5954266.80 565865.45 12.00 7038.34 265.10 MWD 11310.00 90.60 62.71 6368.47 -4944.99 5164.44 5954271.37 565874.35 12.00 7043.26 265.05 MWD 11325.00 90.60 64.51 6368.31 -4938.32 5177.88 5954278.14 565887.73 12.00 7050.70 90.00 MWD 11350.00 90.60 67.51 6368.05 -4928.16 5200.72 5954288.48 565910.48 12.00 7064.01 90.02 MWD 11375.00 90.59 70.51 6367.79 -4919.21 5224.05 5954297.62 565933.74 12.00 7078.41 90.05 MWD 11400.00 90.59 73.51 6367.53 -4911.49 5247.83 5954305.53 565957.45 12.00 7093.86 90.08 MWD 11425.00 90.58 76.51 6367.28 -4905.03 5271.97 5954312.19 565981.54 12.00 7110.32 90.11 MWD 11450.00 90.57 79.51 6367.02 -4899.84 5296.42 5954317.58 566005.95 12.00 7127.74 90.14 MWD 11475.00 90.56 82.51 6366.78 -4895.94 5321.11 5954321.68 566030.60 12.00 7146.07 90.17 MWD 11500.00 90.55 85.51 6366.53 -4893.33 5345.97 5954324.49 566055.44 12.00 7165.27 90.20 MWD 11510.00 90.55 86.71 6366.44 -4892.65 5355.95 5954325.24 566065.41 12.00 7173.18 90.23 MWD 11525.00 89.75 88.33 6366.40 -4892.00 5370.93 5954326.01 566080.39 12.00 7185.27 116.30 MWD 11550.00 88.42 91.02 6366.80 -4891.86 5395.93 5954326.36 566105.38 12.00 7205.95 116.30 MWD 11575.00 87.10 93.71 6367.77 -4892.89 5420.89 5954325.53 566130.34 12.00 7227.25 116.26 MWD 11600.00 85.78 96.41 6369.33 -4895.09 5445.74 5954323.53 566155.20 12.00 7249.12 116.16 MWD 11610.00 85.25 97.49 6370.11 -4896.30 5455.63 5954322.40 566165.11 12.00 7258.01 115.99 MWD 11625.00 85.22 95.69 6371.35 -4898.01 5470.48 5954320.81 566179.97 12.00 7271.30 269.00 MWD 11650.00 85.19 92.68 6373.44 -4899.83 5495.32 5954319.19 566204.82 12.00 7292.95 269.15 MWD 11675.00 85.16 89.67 6375.55 -4900.34 5520.23 5954318.88 566229.73 12.00 7313.92 269.40 MWD 11700.00 85.15 86.66 6377.66 -4899.54 5545.12 5954319.88 566254.61 12.00 7334.15 269.65 MWD 11725.00 85.15 83.65 6379.77 -4897.44 5569.94 5954322.19 566279.41 12.00 7353.59 269.91 MWD 11750.00 85.17 80.64 6381.88 -4894.03 5594.62 5954325.79 566304.06 12.00 7372.19 270.16 MWD 11775.00 85.20 77.62 6383.98 -4889.33 5619.08 5954330.69 566328.48 12.00 7389.89 270.42 MWD 11800.00 85.24 74.61 6386.07 -4883.36 5643.26 5954336.86 566352.61 12.00 7406.65 270.67 MWD 11825.00 85.29 71.60 6388.13 -4876.12 5667.10 5954344.29 566376.38 12.00 7422.42 270.92 MWD 11850.00 85.36 68.60 6390.17 -4867.64 5690.52 5954352.95 566399.74 12.00 7437.16 271.17 MWD 11875.00 85.44 65.59 6392.18 -4857.94 5713.47 5954362.84 566422.61 12.00 7450.82 271.42 MWD 11885.00 85.48 64.38 6392.97 -4853.73 5722.51 5954367.12 566431.61 12.00 7455.98 271.66 MWD 11900.00 85.50 66.19 6394.15 -4847.48 5736.09 5954373.48 566445.14 12.00 7463.78 89.40 MWD 11925.00 85.54 69.20 6396.10 -4838.02 5759.15 5954383.13 566468.11 12.00 7477.66 89.26 MWD 11950.00 85.60 72.21 6398.03 -4829.78 5782.67 5954391.55 566491.57 12.00 7492.61 89.02 MWD 11975.00 85.67 75.21 6399.94 -4822.79 5806.59 5954398.74 566515.43 12.00 7508.59 88.79 MWD 12000.00 85.75 78.22 6401.81 -4817.06 5830.85 5954404.66 566539.64 12.00 7525.55 88.56 MWD 12025.00 85.84 81.23 6403.64 -4812.62 5855.38 5954409.30 566564.13 12.00 7543.45 88.34 MWD 12050.00 85.95 84.23 6405.43 -4809.46 5880.12 5954412.66 566588.84 12.00 7562.24 88.12 MWD 12075.00 86.06 87.24 6407.17 -4807.61 5904.98 5954414.71 566613.69 12.00 7581.86 87.90 MWD 12100.00 86.19 90.24 6408.86 -4807.06 5929.92 5954415.46 566638.61 12.00 7602.27 87.69 MWD 12125.00 86.33 93.25 6410.50 -4807.82 5954.85 5954414.90 566663.55 12.00 7623.40 87.49 MWD 12150.00 86.47 96.25 6412.07 -4809.88 5979.71 5954413.04 566688.42 12.00 7645.20 87.29 MWD 12160.00 86.53 97.45 6412.68 -4811.08 5989.62 5954411.93 566698.34 12.00 7654.10 87.10 MWD 12175.00 87.24 95.79 6413.49 -4812.80 6004.50 5954410.32 566713.23 12.00 7667.42 293.00 MWD 12200.00 88.42 93.03 6414.44 -4814.72 6029.40 5954408.60 566738.15 12.00 7689.17 293.09 MWD 12225.00 89.60 90.27 6414.87 -4815.44 6054.39 5954408.08 566763.13 12.00 7710.32 293.19 MWD 12235.00 90.07 89.17 6414.90 -4815.39 6064.39 5954408.21 566773.13 12.00 7718.60 293.24 MWD 12250.00 90.26 87.38 6414.86 -4814.94 6079.38 5954408.78 566788.12 12.00 7730.81 276.00 MWD 12275.00 90.57 84.40 6414.67 -4813.15 6104.31 5954410.78 566813.03 12.00 7750.52 275.99 MWD 12300.00 90.89 81.41 6414.36 -4810.06 6129.12 5954414.06 566837.81 12.00 7769.40 275.97 MWD 12325.00 91.19 78.43 6413.90 -4805.69 6153.72 5954418.64 566862.38 12.00 7787.40 275.93 MWD 12350.00 91.50 75.44 6413.31 -4800.04 6178.07 5954424.48 566886.67 12.00 7804.48 275.88 MWD y - ConocoPhillips Baker Hughes INTI Baker Hughes INTEQ Planning Report 12375.00 91.80 72.46 6412.59 -4793.13 6202.08 5954431.58 566910.63 12.00 7820.58 275.81 MWD 12385.00 91.92 71.26 6412.27 -4790.02 6211.58 5954434.77 566920.10 12.00 7826.73 275.72 MWD 12400.00 91.92 73.06 6411.77 -4785.43 6225.85 5954439.48 566934.33 12.00 7836.03 90.00 MWD 12425.00 91.91 76.06 6410.93 -4778.78 6249.93 5954446.32 566958.35 12.00 7852.33 90.06 MWD 12450.00 91.90 79.07 6410.10 -4773.40 6274.33 5954451.89 566982.71 12.00 7869.60 90.16 MWD 12475.00 91.89 82.07 6409.27 -4769.31 6298.97 5954456.19 567007.32 12.00 7887.79 90.26 MWD 12500.00 91.87 85.07 6408.45 -4766.51 6323.80 5954459.19 567032.12 12.00 7906.85 90.36 MWD 12510.00 91.86 86.27 6408.13 -4765.75 6333.76 5954460.02 567042.07 12.00 7914.71 90.46 MWD 12525.00 91.79 88.07 6407.65 -4765.01 6348.74 5954460.88 567057.04 12.00 7926.74 92.00 MWD 12550.00 91.68 91.07 6406.89 -4764.82 6373.72 5954461.27 567082.02 12.00 7947.38 92.06 MWD 12575.00 91.57 94.07 6406.18 -4765.94 6398.68 5954460.35 567106.99 12.00 7968.74 92.15 MWD 12600.00 91.45 97.07 6405.52 -4768.37 6423.56 5954458.13 567131.88 12.00 7990.75 92.23 MWD 12625.00 91.33 100.07 6404.92 -4772.09 6448.27 5954454.61 567156.61 12.00 8013.35 92.31 MWD 12635.00 91.28 101.26 6404.69 -4773.94 6458.09 5954452.84 567166.45 12.00 8022.54 92.38 MWD 12650.00 91.27 99.46 6404.36 -4776.64 6472.84 5954450.26 567181.22 12.00 8036.29 270.00 MWD 12675.00 91.27 96.46 6403.80 -4780.10 6497.59 5954447.00 567206.00 12.00 8058.78 269.96 MWD 12700.00 91.26 93.46 6403.25 -4782.26 6522.49 5954445.04 567230.91 12.00 8080.66 269.89 MWD 12725.00 91.25 90.46 6402.70 -4783.12 6547.47 5954444.38 567255.89 12.00 8101.89 269.83 MWD 12750.00 91.24 87.46 6402.16 -4782.67 6572.45 5954445.04 567280.87 12.00 8122.39 269.76 MWD 12775.00 91.22 84.46 6401.62 -4780.91 6597.38 5954447.00 567305.78 12.00 8142.12 269.70 MWD 12800.00 91.20 81.46 6401.09 -4777.84 6622.19 5954450.26 567330.56 12.00 8161.01 269.63 MWD 12825.00 91.18 78.46 6400.57 -4773.49 6646.79 5954454.81 567355.13 12.00 8179.03 269.57 MWD 12850.00 91.15 75.46 6400.07 -4767.85 6671.14 5954460.65 567379.43 12.00 8196.11 269.51 MWD 12875.00 91.12 72.46 6399.57 -4760.94 6695.16 5954467.75 567403.39 12.00 8212.22 269.44 MWD 12900.00 91.08 69.46 6399.09 -4752.79 6718.79 5954476.09 567426.94 12.00 8227.30 269.39 MWD 12925.00 91.05 66.46 6398.63 -4743.41 6741.95 5954485.66 567450.03 12.00 8241.32 269.33 MWD 12935.00 91.03 65.26 6398.45 -4739.32 6751.08 5954489.82 567459.12 12.00 8246.62 269.27 MWD 12950.00 91.03 67.06 6398.18 -4733.26 6764.79 5954495.99 567472.79 12.00 8254.64 90.00 MWD 12975.00 91.03 70.06 6397.73 -4724.12 6788.06 5954505.31 567495.97 12.00 8268.87 90.03 MWD 13000.00 91.02 73.06 6397.28 -4716.22 6811.77 5954513.41 567519.61 12.00 8284.16 90.09 MWD 13025.00 91.01 76.06 6396.84 -4709.56 6835.86 5954520.26 567543.65 12.00 8300.47 90.14 MWD 13050.00 91.00 79.06 6396.40 -4704.18 6860.26 5954525.84 567568.01 12.00 8317.74 90.19 MWD 13075.00 90.99 82.06 6395.96 -4700.08 6884.92 5954530.14 567592.63 12.00 8335.94 90.25 MWD 13100.00 90.97 85.06 6395.53 -4697.28 6909.75 5954533.14 567617.44 12.00 8355.01 90.30 MWD 13125.00 90.95 88.06 6395.12 -4695.78 6934.70 5954534.84 567642.37 12.00 8374.90 90.35 MWD 13150.00 90.93 91.06 6394.71 -4695.58 6959.70 5954535.23 567667.36 12.00 8395.55 90.40 MWD 13175.00 90.90 94.06 6394.31 -4696.70 6984.67 5954534.32 567692.33 12.00 8416.91 90.45 MWD 13200.00 90.88 97.06 6393.92 -4699.12 7009.54 5954532.10 567717.23 12.00 8438.92 90.50 MWD Well 13" 5000 psi Kuparuk DOBCTD BOP config on 2"CT Rig Floor Lubricator ID = 6.375" with 6" Otis Unions 171/16" 5000 psi BOP·s. ID = 7.06" I 71/16" 5000 psi, RX-46 11/4 Turn LTValve 71/16" 5000 psi (RX-46) or 4 1/16" 5000 psi (RX-39) :J BÞ Tree Size SSV I :J :J :J Page 1 Swab Valve Master Valve Base Flange KRU 1 D-37L2 Proposed Produ 2050470 SFD 4/1/2005 - - 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 shan designate one branch as the primary well bore 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 kR¿( /D-37L¿ PTD# 2-0S- - cl-f7 Development Service Exploration Stratigraphic CHECKWBAT ADD-ONS ·'CLUE". APPu:tS (OPTIONS) Ml)LTI Tbe permit is for a Dew weJlbore segmeDt of LATERAL e:xistiDg weD kl2t( I}) - ~ 7 . . . V Permit No, Z£.i)..-2£'~] No. 5-ò-()2-~-.~~ (If API number ProductioD. sbould continue to be reponed as last two. (2) digits a fUDctioD· of tbe origioal API Dumber. stated are betweeD 60-69) above. .. PD..OT HOLE ID accordaDce witb· 20 AAC 25.005(1), all (PH) records, data aDd logs acquired. 'or tbe pilot bole must be clearly differeD1Îated "in botb Dame (Dame OD permit plus PH) .. aDd API Dumber (SO - 10/80) from records, data aDd logs acquired for well (Dame OD permit). SPACING Tbe permit is approved subjeca -to fuD EXCEPTION .' compJiaDce witb 20 AAC 25~055~ Approval 10 periorate aDd produce is coDtiDgeDt UpoD issuaDce of I! cODservation order approviDg a spaciag e:x ~eptioD. (ComÐaDv Name) assumes tbe lIabiDt)" of aD)' protest to tbe spaciDg .e:lCeptioD tbat IDa)' occur. : DRY DITCH All dry ditch sample sets submiued to the SAMPLE CommissioD must be in DO greater ..baD 30' .. sample iDtervals from below tbe permafrost or from where samples are fint caught aDd ] 0' samplebjter-vals through target 2.0Des. .' --co PTD#: 2050470 Administration Well bore seg Annular Disposal Appr Date SFD 4/1/2005 Engineering Appr Date TEM 4/4/2005 ~~ Geology Appr SFD Date 4/1/2005 Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 D-37L2 Program DEV Company CONOCOPHLLLlPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On 1 Per.mitfee attaçhe9_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ Multilateral weUbore~ fee waived_per. :20_AAC :25.Q05(e); retyrtl çhec~ tooper;:¡tor. 2 Lease number appropriate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ Corrected omissioll Qn407 f.orm: top J)ro_duc;tive intervaUs in AD_L025661, cpmpleted interval pa$ses through 3 ,U_nique welL n_arne _and OUJ1)b.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . _ , . ,Yes, , . . . . . ~Ol.,,002a.2~6, TD.is in ADL00:28244.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , , , . . , . . . . . . . 4 Well I.ocated ina defiJ"!e9Pool_ _ . _ . _ _ _ Yes _ . Kup.ar.uk River. Oil F'ool, governed by CQn.servatioo Order f\Jo. 43:2C _ 5 Well J.ocated pr9perdistance. from driJling uJ"!itboUJ"!d_al)' _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ Yes _ . . . . Conservatioo Order f\Jo. 432C co.ntainsno spa_cing restrictions with respeçUo drjllinguoit bo.undaries.. . 6 WelU.ocated proper distance from otl1er wel!s. _ . . . . . . . _ _ _ _ _ _ Yes _ _ _ Con.servatioo Order f\JQ. 43:2C l1asno jn_terwell.spac;illg.restrjctiOlls. 7SuffiçieJ"!taçreageavail;:¡ble in_drilliog unjt . _ Yes _ _ _ _ _ _ _ Conservatioo Ord.er f\JQ. 43:2C l1asno jnterwellspac;iJ"!grestrjctiOlls. WeIJb9r.e.will be.m.ore thao 5QO' fr.om _ 8 Jtdeviated, js weJlb.ore plaUJ"!cJuged _ . No_ _ _ _ _ _ _ _ an extemal prope.rty lille.where.ownership orJandoWJ"!ership_chan.ges. .G_enerated plaUr.orn GeoFr.arne. 9 _OJ)er.ator ollly affeçted party _ _ _ . _ _ _ . . . . . .. _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _. ........ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . 10 _OJ)er.ator l1as.appr9pr[ate. bond inJQrce . . . . . . . . . . . . . . . . . . . . . . . . . , _ . . , . . _ Yes. . . . . . . . . . . . . . . . . . . . . , . , . , . . . . . . . . . . . . . . . . . . . . . . . . . . , . , , , . , , , _ , . . , . . . . . . . . . 11 Per.mitc;anbeisSl!edwjtl1.outco.nserva.tiOJ"!order. _ _ _ _ _yes.......... _. _...... _ _ _ _ _ _ _ _.. 12 Per.mitcan be issl!ed wjtl1.out admiJ"!istr.atille_appr9vaJ _ _ . . _ . . . . . . _ Yes _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . . . . . . . . . 13 Can permit be approved before 15-day wait Yes 14 WelU.ocated withill area alldstrata _authorized by_lojectioo Order. # (putlO# in.c.ommeots) (For NA _ . . . . . _ _ _ _ . . 15 AJI wel!s.withil1.114.mite.area.of review jdeotified (F9r servjc_e.w.ell oJ"!ly). . . . . . . . . . . . . . . NA . . . . . . . , , , , . . . . . . . . . . . . . . . . . . . . . . . . , . _ , , . , , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , _ 16 Pre-produced injector; 9ur;:¡ti.onof pre-J)r09uc;tioJ"! less. than 4 mOJ"!tl1s. (For.service well QnJy) _ NA . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ .. . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . 17 .AÇMPFïllding.of Con_si$tencyhas been issued_ fortl1is proieçt . . _ . . . . . _NA _ _ _ _ Multilateral well.bore. . . . . _ _ _ _ _ _ _ _ . . . . . . . . . . . . . . . 18 .C.onductor strillg.prQvided _ _ _ . _ . _ . . . Yes _ _ _ _ _ _ _ Conductor .setio origjn.al weJI, 10-37 (20Q-:204). _ _ . . . . . . . . . 19Suct'acecasiJ"!gpr.otectsaILknownUSDWs. . _ . . . . . . . _ _ _ _ _ _ _ _ _ _ _NA _ _~llaq.uife.rsexempted,40CFRt47.102(b)13). _ . _ . . . . . . . . .. . 20 _CMTv9Iadeql!atetocircJJlate.011.cooduçtor&suJfcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. . NA _ _Surtacecasingsetjn..origil1al.w.ell. 21 .CMT v91 adeql!ateto tie-inl.ong .string to.surf csg. _ _ . NA . . . ~Il hydroçarb.onzpoes_cpvered, _ _ . . . . . 22CMTwill coverall koo.w.nproductive l1.orizons _ . . . . . . _ _ _ _ _ __No _ _ _ _ _ _ _ Slotte.dJioer.completioo pLaOJ"!ed. 23Casiog de_sigos ad_equa.te f9r. C,.T, B .&. permafr.ost _ Yes _ . _ . _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . 24 Agequ;:¡tetankageor reserve pit _ _ _ _ . .. _...... . _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Rig js.e.quippe_dwith steelpits. _ No reseJlle_pjtJ)laooe.d, All w¡¡ste to.approve9anouJl!sOr dispo$alwells. 25 Jfa.re-drill~ has a 10-403 f.or ;:¡bandOllment beeo ¡¡PPJoved . . . _ _ _ _ _ _ _ NA . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . . . 26 .Agequate.w.ellboreseparatjo.nproJ)osed................................. ,Yes_..... .l?r9~imityan;:¡lysisperf9rme.d. .1D__37l.,,2.dillergesfromrn.otherbor.and~37\..1..NQdirectional.coJ"!flicts,.... _... 27 Jfdjvecterrequired,d.oesjtmeetreguJatioJ"!s. _.. _. _ _ .......... _.. _ _ _ _ _ _ _ _ _ NA _BOl?wUl.alrea9Ybeinplace._ _ _ _ _ _ _.. _ _............. 28 Drilliog fJujdprQgram sc;hem¡¡tic& e~uiplistadequ¡¡te. . _ _ _ _ _ _ _ _ _ _ _ _ Yes . Maximum expected fprma.tiOJ"! pressureJO.O_EMW.. Wel! tpbe dr.illed with dy_n¡¡micoverbaJance. 21l0]umes p{kilL 29 .B.OPEs,do.theymeetreguJatioJ"! _ _ _ _ _ _... _......... _ _ _ _ _ Yes_ _ _ _ _ _ _ _WeightmudwiJIÞe¡¡llajlabJe.onJoc:atiQnfor_a9ditooalwelJc.ontr01........ . 30 .BOPE.pressra.tiogappropriate;.testto.(pu.tpsigin_commeJ"!ts) _ _ _ _ _ _ _ _ _ _ _ _ _. _.... Yes... .M~Sl?calc;uJated_at2580psi. 35QO.psipJa.nnedBQF'testpressure._ ............. 31 .C.hokemanifold cQmpJies w/APL RF'-53 (May 84) . . . . . . . . Yes _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ . _ . _ _ . . . . . . . . _ . 32 W.ork will occur withoytoperatiol1shutdo.w.n . _ _ _ . . . _ . . . . . . . . . . . _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 33 Is preseoce .of H2S gas_ probable. . . . . . . . . Yes . . iD .pad has prepocted 1-12S.Mud _shQuJd_ prec;lu.de H2S 90 rig. . Re.g.h_as sensors aod alarms. 34 Mechanic¡¡lcpodition 9{ we.lIs withiJ"! ~OR verified (For service welJ ollly) . . _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ . . . - - - - - - - - - - - - - - - - - - 35 Permit cao be issl!ed wl.o hYdrogen_ s.ulfide meaSJJres. _ 36 .D.ata.preseoted Qn pote.ntial pveJpressurezOJ"!es _ _ _ _ _ _ _ _ . . _ _ . . . . . _ . . . . . . 37Seismicanalysjs .of Sl1aJlow gas_z90es. . . _ . . . 38SeabedcOJ"!ditioo Sl!rvey(if off-shor.e) . . . . . . . . . 39 _ C.ontactllarnelpholleforwee~ly progress reports [e¡cplor¡¡tory .only). . . . . _ No_ _ _ _ _ _ _ _ 1D-37' r.epQrtedly has_7'OppmH2S, H2SmeasuJesrequired.. . . . . . . . . . . Yes. _ _ _ Expected reservoir J)re.sSUJe is1 0.0 ppg EMW; will Þe drjlled with C.oiled Tl!bing .and 6.6 ppg mud _ _ _ NA ysjn.g.overbalanced pressure_drilJiJ"!g.techniQues, SfD . . _ _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ NA_ _ ...... _ _ _ _ _ _....... ......... _. _ _ _ _ _ _ _ _ _ _ _ _ _. _ _...... . _ _ _ NA_ _ _...... . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _.. _........... ~ D . . Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date ~<f-S~OS- - . Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennìttìng Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, infonnation 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. - **** REEL HEADER **** MWD 06/11/21 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD OS/06/23 919S93 01 2.37S" CTK *** LIS COMMENT RECORD *** - !!!!! ! !! !! !!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10600.0000: STOP.FT 11S46.0000: STEP.FT O.SOOO: NULL. -999.2S00: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1.20 : NO: ------------------------------- SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OS1 . -Remarks 23 11N 10E MSL o RKB 106 KB 106 N/A o N/A DIRECTIONAL Qt;þ- 047- * tl./;)SCJ CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska, Inc. 1D-37L2PB1 Kuparuk River Unit 70 deg 17' S6.476"N 149 deg 30' 31.160"W North Slope Borough Alaska Baker Hughes INTEQ 2.37S" CTK 23-Jun-OS S00292299270 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 . . (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 real time 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) 1/2" liner. Top of Window 10595 ft.MD (6342 ft.SSTVD) Bottom of Window 10600 ft.MD (6344 ft.SSTVD) (8) The interval from 11522 ft. to 11546 ft.MD (6460 ft to 6476 ft.SSTVD) was not logged due to sensor bit (9) Tied to 1D-37 at 10573.0 (10) The wellbore 1D-37L2 was The sidetrack was drilled from 1D-37 through a milled window in 3 offset. ft.MD (6334.0 ft.SSTVD) kicked off this wellbore 1D-37L2PB1 at 11130 ft.MD (6374.19 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 65 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1D-37L2PB1 5.xtf 150 ConocoPhillips Alaska Inc. 1D-37L2PB1 Kuparuk River Unit North Slope 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 ROP 0.0 0.0 GR ROP GRAX ROPA * 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 2 68 68 1 1 AAPI F/HR 4 4 GR ROP MWD MWD ------- Total Data Records: 23 Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 10600.000000 11546.500000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 32 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU 4 4 8 . . -------------------------------- WDFN LCC CN WN FN COUN STAT ID-37L2PBl.xtf 150 ConocoPhillips Alaska In ID-37L2PBl Kuparuk River Unit North Slope 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 ROP GRAX ROP GRAX ROPA 0.0 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 2 GRAX MWD ROP MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 46 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10600.000000 11546.250000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 55 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD . 05/06/23 919593 01 **** REEL TRAILER **** MWD 06/11/21 BHI 01 Tape Subfi1e: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . . rape Subfile 2 is type: LIS DEPTH GR ROP 10600.0000 71. 6767 -999.2500 10600.5000 76.8700 -999.2500 10700.0000 89.3300 76.4200 10800.0000 97.3733 77.4300 10900.0000 97.9000 66.5200 11000.0000 89.3300 56.3200 11100.0000 106.7200 70.7000 11200.0000 103.8700 15.0800 11300.0000 105.6800 19.9900 11400.0000 104.9000 35.5600 11500.0000 197.5900 6.1900 11546.5000 -999.2500 -999.2500 Tape File Start Depth 10600.000000 Tape File End Depth 11546.500000 Tape File Level Spacing 0.500000 Tape File Depth Units feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROP 10600.0000 71. 6767 -999.2500 10600.2500 74.2733 -999.2500 10700.0000 89.3300 76.4200 10800.0000 97.3733 77.4300 10900.0000 97.9000 66.5200 11000.0000 89.3300 56.3200 11100.0000 106.7200 70.7000 11200.0000 103.8700 15.0800 11300.0000 105.6800 19.9900 11400.0000 104.9000 35.5600 11500.0000 197.5900 6.1900 11546.2500 -999.2500 -999.2500 Tape File Start Depth 10600.000000 Tape File End Depth 11546.250000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . Tape Subfile 4 is type: LIS ~~.ê.., ~.t~ ~'~' . . ~t/[~:~/ ~ REEL HEADER **** MWD 06/11/21 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/01 919S93 01 2.37S" CTK *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!! ! ! !!!!!!!!!!!!!!!!!! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10600.0000: STOP.FT 13087.0000: STEP.FT O.SOOO: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- *** Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska, Inc. 1D-37L2 Kuparuk River Unit 70 deg 17' 56.476"N 149 deg 30' 31.160"W North Slope Borough Alaska Baker Hughes INTEQ 2.37S" CTK 01-Jul-OS S00292299261 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSI . -Remarks 1 L.t~ 6" "ð .;;05 -04?- ~ ~ 23 11N 10E MSL o RKB 106 KB 106 N/A o N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 . . (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 real time 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) 1/2" liner. Top of Window 10595 ft.MD (6342 ft.SSTVD) Bottom of Window 10600 ft.MD (6344 ft.SSTVD) (8) The interval from 13063 ft. to 13087 ft.MD (6392 ft. to 6390 ft.SSTVD) was not logged due to Tied to lD-37 This wellbore The sidetrack was drilled from 1D-37 through a milled window in 3 37L2PB1 (9) (10) at 11130 ft.MD (6374.19 ft.SSTVD) MNEMONICS: GRAX -> ROPS -> TVD -> sensor bit offset. at 10573.0 ft.MD (6334.0 ft.SSTVD) lD-37L2 was kicked off this plugback wellbore 1D- Gamma Ray MWD-AAPI [MWD] (MWD-API units) Rate of Penetration, feet/hour Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1D-37L2 5.xtf 150 ConocoPhillips Alaska Inc. 1D-37L2 Kuparuk River Unit North Slope 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 ROP 0.0 0.0 GR ROP GRAX ROPA * 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 2 68 68 1 1 AAPI F/HR 4 4 GR ROP MWD MWD ------- Total Data Records: 60 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10600.000000 13086.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 69 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU 4 4 8 . . -------------------------------- WDFN LCC CN WN FN COUN STAT ID-37L2.xtf 150 ConocoPhillips Alaska In ID-37L2 Kuparuk River Unit North Slope 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 ROP ---------------------------------------------------- GRAX ROPA GRAX ROP 0.0 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 2 68 68 GRAX MWD ROP MWD 1 1 4 4 4 4 AAPI F!HR ------- 8 Total Data Records: 119 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10600.000000 13086.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 128 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD . 05/07/01 919593 01 **** REEL TRAILER **** MWD 06/11/21 BHI 01 Tape Subfi1e: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . rape Subfile 1 is type: LIS . rape Subfile 2 is type: LIS DEPTH 10600.0000 10600.5000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13086.0000 GR 71. 6767 76.8700 89.3300 97.3733 97.9000 89.3300 106.7200 103.0900 116.5900 102.3100 110.3600 110.1000 109.8400 130.6100 112.9500 120.4800 106.4600 102.8300 118.1500 113.7300 106.4600 96.0800 102.0500 121.5200 111.4000 100.2300 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP -999.2500 -999.2500 76.4200 77.4300 66.5200 56.3200 70.7000 53.7200 28.0800 20.8100 18.9600 11.4200 38.0900 38.4800 38.5300 15.1700 45.6600 81.5200 73.6500 40.3400 15.6000 35.7000 23.8200 48.3700 9.4200 33.6300 -999.2500 10600.000000 13086.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROP 10600.0000 89.5900 -999.2500 10600.2500 86.2150 -999.2500 10700.0000 89.3300 76.4200 10800.0000 99.1900 77.4300 10900.0000 97.9000 66.5200 11000.0000 89.3300 56.3200 11100.0000 94.0000 2.1100 11200.0000 103.0900 53.7200 11300.0000 116.5900 28.0800 11400.0000 102.3100 20.8100 11500.0000 110.3600 18.9600 11600.0000 110.1000 11.4200 11700.0000 109.8400 38.0900 11800.0000 130.6100 38.4800 11900.0000 112.9500 38.5300 12000.0000 120.4800 15.1700 12100.0000 106.4600 45.6600 12200.0000 102.8300 81. 5200 12300.0000 118.1500 73.6500 12400.0000 113.7300 40.3400 12500.0000 106.4600 15.6000 12600.0000 96.0800 35.7000 12700.0000 102.0500 23.8200 12800.0000 121. 5200 48.3700 12900.0000 111.4000 9.4200 13000.0000 100.2300 33.6300 13086.0000 -999.2500 -999.2500 Tape File Start Depth 10600.000000 Tape File End Depth 13086.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . Tape Subfile 4 is type: LIS . . **** REEL HEADER **** MWD 06/08/18 BHI 01 LIS Customer Format Tape RECEIVED AUG 3 0 2006 **** TAPE HEADER **** MWD OS/07/01 919593 01 2.37S" CTK .t\Iaska 011 & Gas ConS. Commission Anchorage *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10600.0000: STOP.FT 13087.0000: STEP.FT O.SOOO: NULL. -999.2S00: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska, Inc. 1D-37L2 Kuparuk River Unit 70 deg 17' 56.476"N 149 deg 30' 31.160"W North Slope Borough Alaska Baker Hughes INTEQ 2.37S" CTK 01-Jul-OS S00292299261 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . -Remarks eos- -cfl9 1i- It:..¡ Cß3 23 llN 10E MSL o RKB 106 KB 106 N/A o N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. DatUm Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 . . (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 real time 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) 1/2" liner. Top of Window 10595 ft.MD (6342 ft.SSTVD) Bottom of Window 10600 ft.MD (6344 ft.SSTVD) (8) The interval from 13063 ft. to 13087 ft.MD (6392 ft. to 6390 ft.SSTVD) was not logged due to Tied to 1D-37 This wellbore The sidetrack was drilled from 1D-37 through a milled window in 3 37L2PB1 (9) (10) at 11130 ft.MD (6374.19 ft.SSTVD) MNEMONICS: GRAX -> ROPS -> TVD -> sensor bit offset. at 10573.0 ft.MD (6334.0 ft.SSTVD) 1D-37L2 was kicked off this plugback wellbore 1D- Gamma Ray MWD-AAPI [MWD] (MWD-API units) Rate of Penetration, feet/hour Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1D-37L2 5.xtf 150 ConocoPhillips Alaska Inc. ID-37L2 Kuparuk River Unit North Slope 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: 40 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10600.000000 13086.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 48 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-37L2.xtf . . LCC CN WN FN COUN STAT 150 conocoPhillips Alaska In ID-37L2 Kuparuk River Unit North Slope 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: 79 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10600.000000 13086.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 87 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/07/01 919593 01 . **** REEL TRAILER **** MWD 06/08/18 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . rape Subfile 1 is type: LIS rape Subfile 2 is DEPTH 10600.0000 10600.5000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13086.0000 . type: LIS GR 71. 6767 76.8700 89.3300 97.3733 97.9000 89.3300 106.7200 103.0900 116.5900 102.3100 110.3600 110.1000 109.8400 130.6100 112.9500 120.4800 106.4600 102.8300 118.1500 113.7300 106.4600 96.0800 102.0500 121. 5200 111.4000 100.2300 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . 10600.000000 13086.000000 0.500000 feet Tape Subfile 3 is DEPTH 10600.0000 10600.2500 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13086.0000 . type: LIS GRAX 89.5900 86.2150 89.3300 99.1900 97.9000 89.3300 94.0000 103.0900 116.5900 102.3100 110.3600 110.1000 109.8400 130.6100 112.9500 120.4800 106.4600 102.8300 118.1500 113.7300 106.4600 96.0800 102.0500 121. 5200 111.4000 100.2300 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . 10600.000000 13086.000000 0.250000 feet . . Tape Subfile 4 is type: LIS