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Home My WebLink About203-019 ) ) 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. .;z 03 - 0 1 q Well History File Identifier Organizing (done) o Two-sided '"" I II 1111/1 " III ~can Needed RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: Helen ("Maria ) D Other:: Date: D I '<r (ß> /5/ m J I Project Proofing BY: Helen (""Maria ) Date¡Ó f6. 05 151 V11ð Scanning Preparation ~~ x 30 = I(7D . + 3 = "T.OT~ PAGES &3 (count. does not' clude cover sheet) r I1AD Date: Õ t ~ tJS- 151 V r ~. , r BY: Helen (Maria) BY: Production Scanning Stage 1 Page Count from Scanned File: /¡; LJ- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YE;S, ~ NO :J Helen (Maria ") Date:&," t'6 05 151 V\1 '" If NO in stage 1 page( s) discrepancies were found: YES NO Stage 1 BY: Helen Maria Date: 151 II III I I Date: 151 Quality Checked III "1111111 "1111I Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_Inserts~lVlicrofilm_Marker. doc J f'J~~ ^~~~- DATA SUBMITTAL COMPLIANCE REPORT 5/212005 Permit to Drill 2030190 Well Name/No. KUPARUK RIV UNIT 3N-18L 1 Operator CONOCOPHILLlPS ALASKA INC MD 12133'- TVD 6622 ~. Completion Date 4/1/2003 /" Completion Status 1-OIL ----- REQUIRED INFORMATION Mud Log No Samples No -------~~ DATA INFORMATION Types Electric or Other Logs Run: GR Well Log Information: Logl Electr Data Digital Dataset Log Log Run Type Med/Fnnt Number Name Scale Media No Ftõ9~ Gamma Ray Blu i1:6g Gamma Ray Blu !~ Directional Survey ~ Directional Survey ~~ C Asc ~2415 Gamma Ray C Pdf 2415 Gamma Ray ¡~ Gamma Ray 5 Blu I ¡Hpf Gamma Ray I tD C Lis "'f 2501 Gamma Ray - l.~~______ 12501 LIS Verification Well Cores/Samples Infonnation: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? <"7'7"N- Daily History Received? Formation Tops Analysis Received? -~ ~------ Comments: Current Status 1-01L Sf t..t.d... í f{ ~ ÅAYIJ ~ API No. 50-029-21595-60-00 UIC N Directional Survey ~ (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 10006 12133 10006 12133 10330 12133 10006 12147 10006 12227 10006 12227 10006 12227 10006 12227 9981 12133 0 0 - OHI CH Received Comments Open 4/29/2004 MWD Open 4/29/2004 MWD 5/15/2003 5/15/2003 Open 2/18/2004 Open 2/18/2004 Open 2/18/2004 Open 2/18/2004 4/29/2004 4/29/2004 Sample Set Number Comments @N @J/N Gamma Ray MWD Gamma Ray MWD Gamma Ray MWD Gamma Ray MWD MWD/Log Images '- DATA SUBMITTAL COMPLIANCE REPORT 5/2/2005 Permit to Drill 2030190 Well Name/No. KUPARUK RIV UNIT 3N-18L 1 Operator CONOCOPHILLlPS ALASKA INC MD 12133 TVD 6622 Completion Date 4/1/2003 Completion Status 1-01L Current Status 1-01L ----- ~ Date: Compliance Reviewed By: API No. 50-029-21595-60-00 UIC N 3·~ ~.>~ .~ .~" Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 3N-18Ll Contains the following: 1 LDWG Compact Disc .I ~ ç'û·( (Includes Graphic Image files) 1 LDWG lister summary .--....... ) ".. BAKER HUGHES Anchorage GEOScience Center L/"'"" . 1 blueline - GR/Directional Measured Depth Log /"'"'. 1 blue line - GR/Directional TVD Log ~. LAC Job#: 447715 Sent By: GI~1 ~orel Received By: ~j ¡)LL) Date: Apr 29, 2004 Date: ;2 q tar) M~ '4. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 ;<03-0¡Q Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 f'...·.'.r;:'~):"·;·;r¡';'it1:c1:;.';.;i;7:.¡.:"¡:'¡", '·1 .: Illl'Ur,,,,,· I"","*ÞI1.r~ TII:W, ~:~. Is \.~~I'. ¡~" ",'~ ," ':,." ;y'1:,J,;..:-.";~ '~V¡ I "',v. "" ",'~ .(,~,', .;,:~ ! :-·····_······;;;;;õ7.:;·;;:~.;:¡···;·;············_····1 ;~:{'d~;~:~1 '::::. =... ! ~I _,.'" =:::!:-:~, ...__.__~.___NaN___________ ~~~::::~€~~~;.~~;, ·;.'··;~4~ !~~~;i~·-~~;_.._-~~--~-~_·_~~~· iiE~~-~ ,~~_ i ",·",t·· .'''~'' __"___0 ____._.._____ ~...;,;~ --__-.__0..- ~__.____.___~_______ __ ____ _~. _h___ ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3N-18LIPBl Contains the following: 1 LDWG Compact Disc J d tf IS (Includes Graphic Image files) I LDWG lister summary é903~O\q ) ,&.. BAKER HUGHES Anchorage GEOScience Center 1 blueline - GRJDirectional Measured Depth Log 1 blueline - GRJDirectional TVD Log LAC Job#: 447715 Sent By: Glen Horel ,"', ~ - ..~-- Received By: ~ \ ~.Jv'- -1"-"') '- Q.Q~~~:~~:t:~~),/, Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~--.....~ '" '"\J ~~ \\, ~ Date: Rbèè2ËÎVED Date: Fr.·"P 1 PJ ~nn4 .~.u .....\.it¡ 1-'(::::~;~:;:~:·:;~~:;;'~~:~::::i'1 ....... ... ···;~'::;:'''.~;~·······-··-l !~-.r~ ~ ~;:: ~~ ,;~~ ~,......._,....-,:.:',~:.,.....,....~.::::.".:.'.._..,.-.,...-,...,.....-. r ~:?",. ....;: ~:,., '~?" .~' . t·,!- i,:::~~~,."~~:;;~,,.,~.~ ...~L. '~~. I ;;;i~,," 1~;~::::;~f[~i:~:~J~;=4: llUIQI'll1 .t. w 11I'1 IC\JI\~: ... .." .... . j~1"r~\,.:u..w ~L~;I}- ..,- PLEASE ACKNOWLEDGE RECEIPT BY SIGNI~stt~ OR FAXING YOUR COpy n FAX: (907) 267-6623 ,. , ' ~ r~ : L__________L__________________. Schlumbergep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ,\ ì.. c\ ).D>--':' ? . 1 N-(~t-.-{ Well } 83-0\5 1Y-13 M3 -0 \ t)..3N-1-~ J qo :,OLPl1L-19 O-O'B3G-12 ~ 61-1-011 2P-419 Job# 10709699 10696831 10696833 10709686 10703972 Log Description Date INJECTION PROFILE (REDO) PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE USIT/CBL 01/27/04 01/30/04 02/01/04 12/31/03 02/06/04 SIGN;;~c;\__~ ,~.~C h ~~_ DATE: 02/16/04 NO.3113 Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk _/ BL Color CD 1 1 1 1 .~ RECEIVED FEB 1 8 2004 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank,Y~ask80i1&GasCons.CommiIion Andø8ge ............ ~ ~ bp ') '\ ) Terrie Hubble Direct: (907) 564-4628 hubbletl@bp.com Technical Assistant GPB Drilling & Wells BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 May 6, 2003 Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Permit to Drill, 203-018 To Whom It May Concern: Please find attached the Completion Report for 3N-18Ll. At this time we would like to request that you cancel the second (planned) Permit to Drill for 3N-18L2. This leg was not drilled and there are no immediate plans to attempt to drill it. Thank YOLl very much for your assistance in this matter. Sincerely, ,~A f'j ~.. ,'} lJ¿/V u...t:, Terrie Hubble ) () 3-0 (c{ .,. ,"f.'''. -......~ ~.....- ~..- ~..-- ..'\: F~'" ·'.'·'1'" ". STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) Multilateral 1. Status of Well Ifa Oil 0 Gas 0 Suspended 0 Abandoned 2. Name of Operator ConocoPhillips 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1561' NSL, 20' EWL, SEC. 28, T13N, R09E, UM At top of productive interval 3494' SNL, 5057' EWL, SEC. 33, T13N, R09E, UM X = 523484, Y = 6008;i5 ~ W II N b At total depth . e um er 2523' SNL, 153' EWL, SEC. 33, T13N, R09E, UM X = 523855, Y = 6009 3N-18L1 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field I Oil Pool RKB = 68' MD ADL 025520 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/19/2003 3/31/2003 4/1/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12133 6622 FT 12133 6622 FT Ifa Yes 0 No 22. Type Electric or Other Logs Run GR 23. CASING SIZE 16" 9-5/8" Classification of Service Well _Bf~i;;~~i1 ~~.. I·'···.· ~ ..~ V~ ~: :__.1/1:~.~ ~ ~ lSlJrf1ðl~;~ ~.; \ 'r .... !r\ ~. .~ r.~)!-~qxJ .:; ~. .t~!, °kt, ~. ì. .'" '':::,,,~~~:;~~ ~ """_"<Mo" .-.......''1''....,.'''1'' ~ ".-," ,. ,., "II w" , '..,,' """",,,,,,,,,,..,,,,,,"".,,,..- .2!JVV 9. Unit or Lease Name X = 518122, Y = 6013800 Kuparuk River Unit 7. Permit Number 203).W DIg 8. API Number 50- 029-21595-60 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost 1801' MD 1700' (Approx.) Vw~~ /&JDo~/;nþ ¿,. till'" 7Y'l::> WT. PER FT. 62.5# 36# 26# 4.6# GRADE H-40 J-55 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 115' 24" Surface 5144' 12-1/4" Surface 10007' 8-1/2" 9936' 12133' 3" CEMENTING RECORD 242 sx CS II 1500 sx AS III, 400 sx Class 'G' 400 sx Class 'G', 175 sx PF 'C' Uncemented Slotted Liner AMOUNT PULLED 7" 2-3/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-3/8" Slotted Section 25. TUBING RECORD SIZE DEPTH SET (MD) 3-1/2",9.2#, J-55 10067' 2-7/8",6.5#, J-55 10067' - 10080' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1800' Freeze Protect with Diesel PACKER SET (MD) 9902' & 10057' MD TVD 11046' - 12121 r 6564' - 6621' MD TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 3, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBL 4/7/2003 5.8 TEST PERIOD 409 1,252 334 Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl Press. 148 24-HoUR RATE 28. CORE DATA :.,. , i'-- I~ ~.-,¡ \ I.'~-- W'-...· Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiPt1:. t:!l,,p r.;:, á \1' t~:, ¡L) CHOKE SIZE GAS-Oil RATIO 978 OIL GRAVITY-API (CORR) No core samples were taken. fRBDMS ~t- t" rV1i~\ y 0 b n MAY 72mB ~~ À~~ß.'ti~,~'( \~,~.~ & l~~~J.Ç~ C'::ns.. C.»r~"'~r:l~~~~~:1'i~t Ar7(;t1~ ~q~¡;; 9 RIG I N /å'tmt In Duplicate Form 10-407 Rev. 07-01-80 ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Kuparuk B4 Kuparuk B3 Kuparuk B2 Kuparuk 84 Kuparuk 83 Kuparuk 82 Kuparuk 81 10000' 10043' 10143' 10765' 10835' 10895' 1 0947' 6408' 6430' 6462' 6476' 6494' 6514' 6533' Kuparuk A6 Kuparuk A5 Kuparuk A3 Kuparuk A3 Kuparuk A2 Kuparuk A3 Kuparuk A2 11005' 11011' 11045' 11200' 11275' 11649' 11900' 6553' 6555' 6564' 6574' 6580' 6588' 6594' 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~JV\.i..A..., ~ Title Technical Assistant Date 0 S .. 0 ~ ·03 3N-18L 1 203-109 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Dril/ing Engineer: Dan Kara, 564-5667 Permit No. / Approval 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: Field: API: Permit: Date Date 1 2/1 9/02 12/26/02 01/11/03 01/12/03 01113/03 01/28/03 02/15/03 02/16/03 02/17103 02/18/03 02/19/03 02/20103 ') ,1 ) 3N-18L 1 Kuparuk River Unit 50-029-21595-60 203-019 Accept: Spud: Release: Rig: 03/17103 03/19/03 04/01/03 Nordic #2 PRE-RIG WORK Comment POT-T - PASSED, PPPOT-T - FAILED [WH MAINTENANCE] MITOA -PASSED [WH MAINTENANCE] DRIFTED TBG TO AVA @ 10,042' RKB WI 25'·6" WEATHERFORD WHIPSTOCK DUMMY [TAG] TAGGED FILL @ 10,166' RKB, 176' OF FILL, REPLACED 2.75" AVA BPC WI BPI, REPLACED GLV'S WI DV'S @ 2749',5546',8333' & 9841' RKB, IN PROGRESS [TAG, OPEN-CLOSE C SAND, GLV] LOADED II A WI 260 BBL'S DIESEL, PT TBG & II A TO 2500# PULLED A-2 PLUG- UNABLE TO TEST SSSV 0# TBG PRESSURE [PT TBG-CSG, OPEN-CLOSE A SAND] PERFORMED STATIC BOTTOM HOLE PRESSURE SURVEY. WHP = 403 PSI, WHT =- 12 DEGF. FLUID LEVEL DETECTED AT 6640'. LOGGED PRESSffEMP PASS FROM TD (10157') TO SURFACE AT 140 FPM. 10148' - PRESS = 1110.1 PSI, TEMP = 156.9 DEGF. 10000' - PRESS = 1081.1 PSI, TEMP PULL AVA BPI @ 10042' RKB, PULL DV @ 9942' RKB, SET 1"X 3/81TOP- 7/16"BOTTOM PORT CV WI CHECKS ON BEK @ 9942' RKB, SET 2.25" CA-2 PLUG @ 10072' RKB & DUMP BAIL SALT ON TOP OF PLUG LAST TAG @ 10068 WLM ON SALT. JOB IN PROGRESS. [OPEN-CLOSE C SAND, OPEN-C DUMP BAIL 50% ROCK SALT & 50% FINE SALT MIXTURE ON TOP OF 2.25" CA-2 PLUG @ 10072' RKB UP TO 10052' RKB THEN SLUGGIT FROM 10052'RKB TO 10050' RKB. DISPLACE TBG WI 90 BBLS SEA WATER THEN PUMP 20 BBLS OF SEA WATER @ 1000 PSI. @ WELL HEAD FOR INJECTIVITY TES FISH E-LlNE TOOL STRING TOTAL LENGTH 291 @ 244' WLM DRIFT TBG WI 2.78" GAUGE RING 5' 1.875" STEM 2.78" CENT. 8" 2.74" CENT. TOAL LENGTH OF 16' DOWN TO 10042 RKB [FISH] ATTEMPTED TO SET EZ DRILL SV CEMENT RETAINER. FAILED TO GET DOWN AGAIN. TOOLS SET DOWN @ 300' SAME AS BEFORE. APPROX. FIVE FEET OF THE TOOL STRING GOES THROUGH THE COLLAR @ 292' MD. POOH, RDMO. WELL TO BE DRIFTED WITH LARGER STRING BEFORE RETURNING T DRIFT TBG WI 15' X 2.795" BROACH I DMY SETTING TOOL TO 10042' RKB. [MAINTENANCE] SET EZ DRILL SV CEMENT RETAINER @ 10028' MD. DID NOT TAG PBTD. RAN 19.8' LONG STRING WI BTM 9'= 2.72". TAGGED TO VERIFY GOOD SET. POOH, RDMO LEFT WELL SHUT IN NOTIFIED DSO OF WELL STATUS. ') ) 3N-18L 1, Coil Tubing Drilling Page 2 02/21/03 02/24/03 02/25/03 02/27/03 02/28/03 03/01/03 03/02/03 03/03/03 03/06/03 03/13/03 03/14/03 03/15/03 PERFORMED C-SAND CEMENT ISOLATION SQZ. APROX 9.8 BBLS OF 17 PPG CEMENT BEHIND PIPE WITH A 750# SQZ PRESS. WASHED AND CONTAMINATED ALL CEMENT TO A DEPTH OF 10,000' CTMD. WELL FREEZE PROTECTED TO 3000' CTMD. 2 MIN FLUID LOSS = 54CC. 30 MIN FLUID LOSS = PERFORMED A CEMENT RETAINER AND CEMENT REMOVAL BY MEANS OF A 2.8011 SC & 2.7011 OPTICUT MILL. 2.8011 SC MILL PERFORMED EXCEPTIONAL Y WELL IN REMOVING THE TOP SECTION OF CEMENT AND THE RETAINER IN ONE RUN. SECOND RUN WAS PERFORMED BY THE BAKER OPTICUT 2.70" PERFORMED A CEMENT REMOVAL WITH THE SECOND RUN WITH A 2.7011 OPTI- CUT BAKER MILL. WAS ABLE TO ACHIEVE A HARD TAG ON THE2 7/8" X/O ABOVE THE CAMCO D-NIPPLE AT 10057.7' CTMD, WHICH CORRESPONDS TO 10,072' RKB. WASHED ALL MANDRELS ON THE WAY TO SURFACE. WEL BAILED BRIDGE PLUG DEBRIS FROM TOP OF 2.2511 PLUG @ 10072' RKB. TESTED TBG 1000 PSI, GOOD. IN PROGRESS. [TAG] PULLED EQ-PRONG F/ A2-PLUG BODY. BAILED MINOR VOL. SAND & DEBRIS. ATTEMPTED PULL PLUG @ 100721 RKB, UNSUCCESSFUL. IN PROGRESS. [OPEN- CLOSE A SAND] MADE SEVERAL ATTEMPTS TO PULL PLUG @ 100721 RKB, NO SUCCESS. [OPEN- CLOSE A SAND] SET 2.2511 G-BAIT SUB W/ GUTTED 2.25" JD ON CA2 PLUG @ 10072' RKB. WELL READY FOR CTU. [FISH] PERFORMED A CA2 PLUG EXTRACTION FROM THE CAMCO NO-GO D NIPPLE AT 100721. PLUG IN GOOD SHAPE AND FILLED WITH FINE SAND AND SMALL BITS AND SHAVINGS FROM THE MILL PROGRAM PRIOR TO PLUG PULL. SUGGEST LARGER HOLES IN THE CA2 PLUG IN THE SAME SCENARIO ALONG W MITMV - PASSED [WH MAINTENANCE] SET BTM OF 3.511 TIW WS LOWER PACKER ASSY @ 10018' ELMD CORRELATED TO SWS P-PROF DATED 25-APR-1999. MULE SHOE GUIDE SLOT IS ORIENTED 157 DEG LEFT OF HIGH SIDE LOOKING DOWN HOLE. PKR TEMPORARILY STUCK IN PROD. MAN. FREE AFTER PUMPING. STICKY LOGGING OFF TAGGED WHIP STOCK @ 10,0131RKB, LOCATED MANDREL 8 @ 9934'ELM FOR CORRECTION FACTOR, JOB IN PROGRESS [TAG] RAN WHIPSTOCK STINGER AND LOCKED INTO WHIPSTOCK ANCHOR PACKER @ 99751 WLM TO ASSURE PACKER CLEAR THROUGH ID. RAN WHIPSTOCK STINGER W/ SPERRY EMS MULTISHOT AND PDS MEMORY STRING TO ASSURE DEPTH AND ORIENTATION OF WHIPSTOCK ANCHOR. [PRESSURE DATA] ') ) 3N-18L 1, Coil Tubing Drilling Page 3 04/02/03 04/03/03 TAGGED TOP OF LINER @ 99281 WLM, PERFORMED SBHP SURVEY W 1 TANDEM PANEX GAUGES @ 99281 WLM, PULLED DV FI 98411 RKB IN PROGRESS. [TAG] SET OV @ 98411 RKB, SET GLV1S @ 8871" 72961, 55461, 2749" RKB, MIT IA ALL GLV1S SET, COMPLETE [GLV] ') "\ BPEXPLORA TION OperatiionsSu m01aryReport Page 1 of15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: . Date From - To Hours Task Code NPT Phase Description of Operations 3/1/2003 00:00 - 00:40 0.67 DRILL P PROD1 Finish wiper trip. No problems to bottom. Much better wiper trip. 00:00 - 0.00 CASE PROD1 00:00 - 02:25 2.42 DRILL P PROD1 00:00 - 00:50 0.83 DRILL P PROD1 00:40 - 04:30 3.83 DRILL P PROD1 Continue drilling ahead f/ 11882'. 1.5bpm 8.9ppg in/out 2.4k wob 70-80'/hr. TF 165 chasing A3 dropping inc to 83 deg. Start mud swap at 12000'. (before fs 3680 @ 1.55bpm, after 3500psi) Back into A3 at +/- 11935'md 6521'ss. Align toolface highside and landout. Continue drilling ahead to 12080'. 00:50 - 03:40 2.83 DRILL P PROD1 02:25 - 04: 15 1.83 DRILL P PROD1 04:30 - 06:45 2.25 DRILL P PROD1 Wiper trip. Pull tight at 11827' briefly stuck. Continue TOH 1.76bpm. RBIH Stack out at 11818', pull heavy, attempt to clean up tight spot from 11815-11830'md. Ream down past, PU backream. Repeat x3. (Geo: 11824'md faulted from A3 into A5 shale) Continue in hole to TD, tag at 12075'. 04: 15 - 06:00 1.75 DRILL P PROD1 03:40 - 03:50 0.17 DRILL P PROD1 06:45 - 08:00 1.25 DRILL P PROD1 Drilling. circ press 3650, DH ann 4020, DH CT 4580-4620, DH WOB 2000-2100. Plan to drop at 86deg to revised td of 12200. TD at 12200' At TD DH WOB=2000-2500 Slackoff=1 Klbs. 06:00 - 10:15 4.25 DRILL P PROD1 10:15-11:15 1.00 DRILL P PROD1 Wiper to window. PU wt = 24500'. Tight spot: 1 0640-1 0680'md 11: 15 - 13: 15 2.00 DRILL P PROD1 Directionally drill. DH CT 4800-5000psi, DH annular 4000-4100, Circ press. 4000-4200, DH WOB=2500-3000Ibs. 1.7in/out. Drill to 11,278'md. Avg ROP=85fph. 13:15 -15:00 1.75 DRILL P PROD1 Wiper to window. ECD and annular press drop after each wiper. 15:00 - 17:45 2.75 DRILL P PROD1 Directionally Drill, plan to roll TF over and target A3 sand @ 6502'TVDss. Having trouble getting started drilling, getting DH WOB 2000-35001bs, and 300lb motor work but no progress. DH CT 4900, DH Ann 3900-4000. Circulating press 4100-4200. 1.7 in/out TryPU, overpull, motor stalls out. RBIH try to start drilling, 11255' tight spot, hanging up on BHA? Backream / ream 11255' at a different orientations. Decide to POH and check BHA for failure. 17:45 - 19:45 2.00 DRILL N DPRB PROD1 POH above 1800' and close SSSV valve. Bleed annulus and confirm shut. Close EDC valve and continue POH 19:45 - 21 :00 1.25 DRILL N DPRB PROD1 UD motor/bit from BHA#6. P/U new motor. Scribe toolfaces. Check torque on service breaks. M/U injector. 21 :00 - 22:40 1.67 DRILL N DPRB PROD1 RIH to 350' shallow hole test and open EDC. Open SSSV. RIH following TIH pressure schedule. Through window no problem with highside TF. 22:40 - 23:05 0.42 DRILL N DPRB PROD1 Log tie-in. +2' correction. 23:05 - 00:00 0.92 DRILL N DPRB PROD1 Close EDC continue RIH setdown at 10668' work through to 10721' PUH to 10600' working back through, stacking out at 10670-85'. RIH setdown at 10880' 00:00 - 01 :00 0.00 3/2/2003 00: 00 - 0.00 PROD1 00:00 - 02:00 2.00 DRILL PROD1 Printed: 4/8/2003 11:52:04 AM ') ) BP EXPLORATION Operation$ Summa.ry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From ~ To Hours Task Code NPT Phase . Description of Operations 3/3/2003 00:00 - 00:50 0.83 3/17/2003 03:00 - 06:00 3.00 MOB P PRE Continue RD, back rig off of well. 06:00 - 06:30 0.50 MOB P PRE SAFETY meeting prior to Rig move with rig crew and Kuparuk escort. Emphasize good communication and importance of stopping the operation if anyone sees something unexpected. 06:30 - 18:00 11.50 MOB P PRE Pull rig off of 2B pad and move to 3N pad 15.8 miles. 18:00 - 18:30 0.50 MOB P PRE Arrive on location, 3N pad. PJSM prior to pulling over well. Crew change. 18:30 - 20:00 1.50 RIGU P PRE Position rig, Pull rig over well, set down, prep cellar. 20:00 - 21 :30 1.50 RIGU P PRE Pre Spud meeting with rig crew, MWD, Phillips production, pad operators, & drilling safety rep. 21 :30 - 00:00 2.50 RIGU P PRE Accept rig at 21 :30 hrs. NU BOPE, Continue RU, start CT swap for eline reel. 3/18/2003 00:00 - 05:00 5.00 BOPSURP PRE BOPE test to 250psi and 4500psi. 250psi and 3500psi on annular. Blow down kill line and test pump. SIMOPS with REEL swap. 05:00 - 06:00 1.00 RIGU P PRE RU to stab CT to injector, Stab CT to injector 06:00 - 07:00 1.00 RIGU P PRE Pre Spud meeting with rig crew and Phillips engineer 07:00 - 09:30 2.50 RIGU P PRE Test BHI tools on catwalk. RU and pump slack management. Cut 66' of CT. 09:30 - 11 :30 2.00 STWHIP P WEXIT Re-Head Coil, install BHI eline Coiled Tubing Connector. 11 : 30 - 12: 15 0.75 STWHIP P WEXIT PU injector, 2' and 5' lubricator above rig floor. Install RA tag in Whipstock. 12:15-12:30 0.25 STWHIP P WEXIT PJSM prior to PU BHA #1. 12:30 -13:30 1.00 STWHIP P WEXIT PU BHA #1. TIW Whipstock tray, setting tool, Daily Jars, BHI Coiltrack MHA. Unthaw end of CT. 13:30 - 15:30 2.00 STWHIP P WEXIT RIH with BHA #1. Slow to 1 Of pm at 9950'md. RIH wt= 5700-6000Ibs. PU wt =25Klbs Tag anchor, set down 10001bs. PU, tag anchor again, set down 2000-2500Ibs. PU to 35Klbs, CT weight fell off, indicating the running assembly has sheared off as planned. 15:30-16:15 0.75 STWHIP P WEXIT Circulate out wellbore fluids from above the whipstock tray with 1/2# Bio milling fluid. Getting 1: 1, good indication the tray has set. 16:15 - 17:30 1.25 STWHIP P WEXIT POH, BHA #1. 17:30 - 18:10 0.67 STWHIP P WEXIT lD Whipstock tray setting assembly 18:10 - 19:15 1.08 STWHIP P WEXIT Crew change and wait on replacement for leaking 3' section of lubricator. Replace lubricator section. 19:15-19:40 0.42 STWHIP P WEXIT P/U 1 st milling BHA. Surface test tools - ok. 19:40 - 21 :50 2.17 STWHIP P WEXIT Open ECD and RIH at min rate. Shutdown pump and reduce RIH speed across SSSV @ 1800'. Resume RIH at 100'/min 21 :50 - 22:25 0.58 STWHIP P WEXIT log tie-in using CCl option with BHI f/9921' to tag depth of 10009.6' While waiting for printout closed choke and PT packer with 500 psi surface pressure (+/- 2300 psi differential across packer) no leak-off. Correct -4.6' 22:25 - 00:00 1.58 STWHIP P WEXIT RIH tag top ofWS at 10005'. Free-spin 1.662650 psi. Slowly work up to 4k wob and 4-500 psi motor work. Milling at 10006.6' @ midnight. 3/19/2003 00:00 - 02:20 2.33 STWHIP P WEXIT Continue milling window in 3.5" tbg from 10006.6' off bottom 1.60bpm 2620psi, on bottom 2900-3050 psi, 2-3k wob. Mill to 10010' appears to be through 3.5". RIH to 10011' w/o much motor work. Pick ups clean. Open ECD pump around high vis bio sweep. Printed: 4/8/2003 11 :52:04 AM ) ') Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Description of Operations TOH. Stop at 250' clse EDC shutdown pump and check and confirm no flow. Tag up Setback injector. UD BHA #2 and M/U BHA #3 surface test EDC and directional package. P/U RIH with BHA #3. Stab injector. Inspect WS mill & string reamer, both in good condition. Good wear pattern across the mill face. Gage: HC diamond whipstock mill 2.79 no go, CutRite reamer 2.79" GO/2.77" No Go. WEXIT RIH with BHA #3. 2.5deg Weatherford motor, Fat radius mill, Full BHI eline MWD package, WOB/DHPress sub, orientor. Close circ sub to bump 1 pump through mandrels and collars. Turning mill more effective and faster than orienting. Shut in and pressure up to 500psi at surface, good test. Therefore no hole in 7". IA=575, OA=720psi WEXIT Tie-in with CCl, no correction. WEXIT Orient to whipstock face, 345deg, for dry tag. Tagged up at 10,003.8' dry. May have tagged at a connection above pinch point. PU, try tagging at min pump rate. Tagged up at 10,008.5' at min rate. PU & RIH at full rate, 1.7/1.7bpm. Zero both WOB at 10,000'. Still taking weight at 10,008. Start time drill. 200psi initial motor work. (Hearn recording time drill on excel spreadsheet, see Remarks Tab), DH press=4240psi. 70psi press increase going to 10,008.6'. 50psi increase in circualting press w/0.1' of movement. Drills off. Snubbed to get to 10008.9', looking for some motor work. Circ press up to 3250 and steady. Snubbed 1000# getting to 10,009.3' Orient TF to 330deg to finish window ROP up to 1'/hr (6min/ft) lots of stick slip getting weight transferred downhole. WOB lower than Houston test according to Heard Dog. Motor work increase. 1.7/1.7bpm, Circ press= 4450DH bore, 3370 at surface. Should indicates mill crossing over center-line. Through window out in OH, ROP=0.1-0.2Ftlmin, DH WOB=300-700Ibs, DH annular=3494psi, 1.7/1.7bpm Circ press=4350DH bore, 3300psi at surface, 8.7PPG on MM. Weight transfer is poor, seeing stick- slip, DH WOB and WOB calculated at surface showing pronounced delay. Drill to 10013',2' ofOH. WEXIT PU and backream window 0.2-0.3fpm. TOW=10005', BOW=10,011.5' RBIH, TF=315. Backream up thru window at 60R, RBIH clean. Orient to 270, Back ream up thru window at 0.3fpm. Send high vis bio pill downhole. 1.7/1.7bpm, 4200DH bore, 3200-3300 circ press, 3485DH annular. RIH, drift dry at 270TF, looks clean. Backream up through window at 270TF. WEXIT 8.7ppg Formate Flo-Pro drilling fluid on bottom. Drill OH from 10012 to 10021 1.5/1.5BPM, DH annular 4000psi, DHWOB=4400Ibs, ROP=15-20fph WEXIT POH following choke schedule. Open EDC. Pumping at 1.23bpm. Out density= 8.8ppg Date From - To Hours Task Code NPT Phase 3/19/2003 02:20 - 04:10 1.83 STWHIPP WEXIT 04:10 - 05:20 1.17 STWHIP P WEXIT 05:20 - 08:00 2.67 STWHIP P 08:00 - 08:15 08:15 - 08:45 0.25 STWHIP P 0.50 STWHIP P 08:45 - 09:30 0.75 STWHIP P WEXIT 09:30 - 10:15 0.75 STWHIP P WEXIT 10:15 -10:46 0.52 STWHIP P WEXIT 10:46 - 11 :00 0.23 STWHIP P WEXIT 11 :00 - 11 :40 0.67 STWHIP P WEXIT 11 :40 - 12:00 0.33 STWHIP P WEXIT 12:00 - 12:30 0.50 STWHIP P WEXIT 12:30 - 14:25 1.92 STWHIP P 14:25 - 15:00 0.58 STWHIP P 15:00 - 16:30 1.50 STWHIP P Depth DH ann Choke ECD Printed: 4/8/2003 11 :52:04 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From - To Hours Task Code NPT Phase· Description of Operations 3/19/2003 15:00 - 16:30 1.50 STWHIP P WEXIT 9000' 3890 590 13.1 8000' 3619 590 13.2 7000' 3303 590 13.5 5000' 2610 600 14.3 4400 2426 650 14.8 4000 2375 660 15.2 3500 2200 670 15.9 2800 2020 710 17.19 2000 1820 800 18.9 Close SSSVwith Mill at 1715'md. Bleed off well head pressure. Monitor WHP, no change over 30min. SSSV is holding. Continue POH. PJSM on BHA change out. Discuss pinch points, good communication, SSSV. LD Milling BHA, PU drilling BHA for the build (HC DOSTRW324 2.7x3" bicenter, 2.6deg Xtreme, CoilTrac) RIH to 1550'. Pressure up annulus to 750 psi. Open SSSV. RIH slowly past SSSV- no problems. Continue RIH following TIH choke schedule to 9905'. 16:30 - 17:00 0.50 STWHIP P WEXIT 17:00 - 17:25 0.42 STWHIP P WEXIT 17:25 - 18:15 0.83 STWHIP P WEXIT 18:15 - 20:20 2.08 DRILL P PROD1 04:00 - 06:00 2.00 DRILL P PROD1 Log tie-in f/ gr source depth 9875' to 9990'. Very difficult correlating to PDC log. make +4' correction. PROD1 RIH tag bottom tagged at 10020'. Up wt 25k dwn 18k. PROD1 Close choke trapping 750 psi 3995 BHP and then close EDC. Bring on pumps slowly to 1.5 bpm and slowly open choke. Stabilize pressures. free-spin @ 1.44bpm 3550psi, 3920psi bhp (11.79 ECD) 8.8ppg mud wt. in/out. Wash fill back to corrected TD of 10025' then seen motor work. Corrected window depths: top 10009', bottom 10015.5' PROD1 Directionally drill f/ 10025' 1.44bpm 8.8ppg in/out 3933 bhp 11.91 ECD 3550psi free-spin 2-300psi motor work 25-30'/hr Drilled to 10095'. PROD1 Continue drilling build section f/ 10095'. 1.5 bpm in/out 8.8 in 8.5+ out. adding defoamer to mud system, centrifuges airing system. ROP slowed due to drilling B zone shale +/- 10'/hr 3580 fs 4020 on btm. Drilled to 10150'. PROD1 Wiper trip to window. Make several passes. PROD1 Directionally drill f/ 10150'. 1.5 in/out 8.8+ in/out ecd= 11.95ppg 3-5k wob 15-20'/hr. Drill to 10175' PROD1 TOH. Shutdown pump and close choke with 1000psi while tripping through window. Open EDC return to 1.5 bpm and holding back pressure to TOH schedule: Depth BHP Choke ECD 9000 3700 300 12.17 8000 3430 380 12.57 7500 3330 460 13.02 7000 3220 540 13.45 6000 2980 610 13.97 5000 2620 630 14.39 4000 2390 700 15.35 3000 2140 870 17.22 2000 1970 950 20.42 1700 shutdown pump and trapped 1150 psi. 20:20 - 20:45 0.42 DRILL P 20:45 - 21 :00 21 :00 - 21 :20 0.25 DRILL P 0.33 DRILL P 21 :20 - 00:00 2.67 DRILL P 3/20/2003 00:00 - 02:45 2.75 DRILL P 02:45 - 03:15 03:15 - 04:00 0.50 DRILL P 0.75 DRILL P Printed: 4/8/2003 11 :52:04 AM ') ) BP EXPLORATION OperationsSu mmary . Report Page 5 of 15 Legal Well Name: 3N-18 Common Well Name: 3N-18 Spud Date: 3/3/1980 Event Name: REENTER+COMPLETE Start: 3/17/2003 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: 2 Date From - To Hours Task Code NPT Phase Description·of Operations 3/20/2003 04:00 - 06:00 2.00 DRILL P PROD1 Close SSSV and EDC. Hold PJSM for next BHA and watch pressures. Open choke bleed-off annulus to Opsi. Close choke and confirm SSSV is closed. Continue TOH 06:00 - 07:00 1.00 DRILL P PROD1 LD BHA #4 / PU BHA #5. 1.1 deg Xtreme motor, Re-Run HC DOSTRW324 bi center. 07:00 - 09:00 2.00 DRILL P PROD1 RIH with BHA #5, stop at 1600', pressure up to 1050 on wellhead, open SSSV. Did not see any pressure bleed off after opening SSSV. Continue RIH. 09:00 - 09:45 0.75 DRILL P PROD1 Log GR tie in to PDC, identify feature at 9917', continue logging down to capture Pip tag. Correct 4', PIP tag at 10012'. Corrected window depths: TOW=10,007 BOW=10,013 Seeing higher than expected DH annular while RIH at 3fpm, 0.3bpm 09:45 - 12:00 2.25 DRILL P PROD1 Tag bottom at 10176'md. PU clean at 19,2001b. 1.5in/out RIH Freespin=3650psi, DH annular off bottom=3980. Drilling, 1.5in/out, circ press=3900-3950psi, DH annular=3950-3980psi, ECD=11.9-12ppg, DHWOB=2440-4500. Drill to 10243'md. 12:00 - 15:00 3.00 DRILL P PROD1 Directionally drilling. INC=89deg, 1.5in/out, circ press=3750-3950psi, DH annular=3980psi, ECD=12ppg, DHWOB=3500-4510. Avg ROP=29fph. Drill to 10289'md. 15:00 - 17:30 2.50 DRILL P PROD1 Directionally drilling, on plan. INC=90deg, TF=215, 1.5in/out, circ press=3800-3950psi, DH annular=3975-3990psi, ECD=11.9-12ppg, DHWOB=4000-5000. Avg ROP=30 Drill to 10,339. 17:30 - 17:45 0.25 DRILL P PROD1 Directionally drilling in B shale, sporadic ROP. INC=91deg, TF=270, 1.5in/out, circ press=3900-4050psi, DH annular=3980-3990psi, ECD=11.9-12ppg, DHWOB=4000-5000. Drill to 10350'md 17:45 - 18:05 0.33 DRILL P PROD1 Wiper to window. up wt 18.9k, dw wt. 2.5k 18:05 - 21 :45 3.67 DRILL P PROD1 Directionally drill f/ 10350'. 1.55bpm, 8.8ppg in/out, 3720psi free-spin 2-300psi motor work. 35-40'/hr avg 2-3k wob. Drill to 10495'. 21:45 - 22:10 0.42 DRILL P PROD1 Wiper trip to window 19.6k up, 2.7k dwn 22:10 - 00:00 1.83 DRILL P PROD1 Directionally drill f/ 10495'. 1.57bpm, 8.8ppg in/out, 3850psi free-spin 2-300psi motor work. 4060psi annular BHP 2-3k wob. Drill to 10576' 3/21/2003 00:00 - 02:35 2.58 DRILL P PROD1 Continue drilling ahead with laterial in B shale f/ 10576'. Hit what appears to be 1 st fault at 10598' when 50'/hr ROP halted. Spend 15 min working through fault and continue drilling ahead 30-40'/hr. 1.57bpm 8.88ppg in/out. 4045psi annular BHP w/ 12.17ppg ECD. BHP has increased to 4150psi while drilling the last 20'. Drilled to 10625'. 02:35 - 02:55 0.33 DRILL P PROD1 Wiper trip. While at 10135' notice pin hole in coil just above injector. Shutdown pump and close choke. Line up to pump down backside. 02:55 - 05: 10 2.25 DRILL N DFAL PROD1 Spool pinhole area back onto reel and flag. (mud contained within rig above injector <2 gal) TOH and maintaining 1100 psi on backside. (call for N2 and trucks for reel swap). Pull above SSSV to 1100' and close SSSV trapping 11 OOpsi below. Bleed-off pressure from annulus, shut choke valve observe well - dead. Open choke and finish TOH. 05:10 - 05:45 0.58 DRILL N DFAL PROD1 Stab off well and UD BHA #5 05:45 - 06:30 0.75 DRILL N DFAL PROD1 Prep to displace mud from coil with water. Then blowdown w/ Printed: 4/8/2003 11:52:04 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operations Summary Report 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From-To Hours Task Code NPT Phase Description of Operations . 3/21/2003 05:45 - 06:30 0.75 DRILL N DFAL PROD1 N2. 06:30 - 07:00 0.50 DRILL N DFAL PROD1 Displace mud from CT. 07:00 - 07: 15 0.25 DRILL N DFAL PROD1 PJSM prior to pumping N2. 07:15 - 08:30 1.25 DRILL N DFAL PROD1 Pressure test lines to 4000psi. Blow down reel with N2. 08:30 - 09:00 0.50 DRILL N DFAL PROD1 Unstab injector. Install tree cap, double block the choke line, open MV (Opsi WHP), open HCR to pump down kill line, press up to 1070psi. Close blind Rams. Open SSSV, monitor shut-in pressure. Bleed off from 1070 to 920 over 10min. Bump pressure back up to 980psi. Maintain shut-in pressure between 900-1000psi. 09:00 - 11 :00 2.00 DRILL N DFAL PROD1 Cut off end of CT, install grapple, secure injector, unstab injector, guide end of CT back to reel, prep hardlines in reel house to drop reel. 11 :00 - 12:00 1.00 DRILL N DFAL PROD1 Wait on new reel and low-boy trailer to drop current reel. 12:00 -15:00 3.00 DRILL N DFAL PROD1 Swap Reels, RU hard line in reel house, replace bushing on off driller's side of reel drive shaft, install grapple to end of CT. 15:00 - 16:00 1.00 DRILL N DFAL PROD1 Lead CT over reelhouse and stab injector. Prep end of eline for pumping slack mgmt. 16:00 -17:15 1.25 DRILL N DFAL PROD1 Install eline pressure bulkhead on reel. Establish eline connection to MWD input. 17:15 - 18:00 0.75 DRILL N DFAL PROD1 Line up to pump slack management. Finding ice plugs in the coil. Unable to pressure up too much on this coil with the eline inside which may cause damage to the eline itself. Rig-up steam under reel. 18:00 - 21 :00 3.00 DRILL N DFAL PROD 1 Steam coil reel. (periodically checking pressures on annulus and bumping back up to +/- 1000psi. Finding pressures around 700psi over 90 min period. Only taking .2 bbls to build up pressure) 21 :00 - 00:00 3.00 DRILL N DFAL PROD1 Cut-off 100' coil. Weld on SLB CTC. Stab on well. Slowly pump 1 coil volume water back through coil and fill reel. Increase rate to 2.6bpm pump 2 coil volumes for "slack management". Unstab injector. Eline didn't move, but not hung up either. Call it good. Blow back water with air. Prep to rehead with Kendle BHI CTC. 3/22/2003 00:00 - 02:00 2.00 DRILL N DFAL PROD1 Chase down problems with continuity on eline. Found at MWD shack. 02:00 - 03:35 1.58 DRILL N DFAL PROD1 Rehead with Kendel CTC. Pull test to 25K, PT to 3500psi. 03:35 - 04:35 1.00 DRILL N DFAL PROD1 Reinstall injector pack-off and displace coil to Flo-Pro mud. Close SSSV and bleed down tbg. (found 775psi after opening master/swab valves) 04:25 - 04:55 0.50 DRILL N DFAL PROD1 P/U BHA #6 Stab-on injector. Pressure up tbg to 1000 psi 04:55 - 07:10 2.25 DRILL N DFAL PROD1 RIH. Adjusting choke pressures as per TIH vs Bit Depth schedule. Depth Annular 1600 1850 3000 2270 3600 2560 4600 2700 9700 4035 07:10 - 07:30 0.33 DRILL N DFAL PROD1 Tie in to PIP tag, add 3'. 07:30 - 08:00 0.50 DRILL P PROD1 Continue RIH, tag TD at 10624'md. Hole is in good condition, no set downs in OH. Need to orient to whipstock tray TF to get by window. Printed: 4/8/2003 11 :52:04 AM ) ) BP EXPLORATION Operations Summary ·Report Page 7 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 3/22/2003 08:00 - 10:30 2.50 DRILL P PROD1 Directionally drill. DH WOB=2500-3500Ibs, DH Annular 4010-4025psi. 1.5in/out, circ press 3680psi. Drill to 10660'md. Avg ROP=16ft1hr Erratic instantaneous ROP, pick-ups are clean, no sticking. Samples at 10650' showing more Pyrite, possible indication of fracture. INC=81deg 10:30 - 14:30 4.00 DRILL P PROD1 Directionally drill. DH WOB=2500-3500Ibs, DH Annular 4020-4100psi. 1.5in/out, circ press 3800-4000psi. Drill to 10685 'md. Avg ROP= 8ft1hr Discuss directional plan with town, decide to adjust plan and flatten out, to 75deg INC from 73deg at the bit. This should help us to avoid intersecting the fault & A6 shale at the same time. Fault was prognosed at 10637'md, still no definitive sign of fault #1. Order out new mud. Reology still looks reasonable but solids are 0.8%. ECD and DH annular starting to climb. 14:30 - 15:30 1.00 DRILL P PROD1 Wiper to window 15:30 - 17:00 1.50 DRILL P PROD1 Directionally drill. DH WOB=1500-5000Ibs, DH Annular 4100-4300psi. 1.5in/out, circ press41 00-4300psi. Drilling break at 10690'md, ROP increase to 60-90fph. Drill to 10718'md. INC=75deg 17:00 - 22:25 5.42 DRILL P PROD1 Directionally drill. DH WOB=2000-4000Ibs, DH Annular 4100-4200psi, DH CT 4600psi. 1.5in/out, circ press 4000-4100psi. Still geologically challanged, may have clipped the A6 and now back into the B shale. Inc is 75 deg will hold this and continue to look for diffinative A3 sand. Making short wiper trips back to 10600', 700psi motor work from 10678' -10638'. Starting mud swap at 10742'. ( now: 1.6 bpm in/out free-spin 3900psi w/ 2-300psi motor work, 4200psi annular psi 12.5ecd) (after: 1.7bpm in/out free-spin 3780psi, annular 4040psi 12.2 ecd) 10760' dropping inc f/ 75 to 70 deg looking for A-3 sand Drilled to 10837'. 22:25 - 23:15 0.83 DRILL P PROD1 Wiper trip to window. Up wts 20.1 k down 2k to negitive numbers. Setdown at 10680' and 10738' shutdown pump (trap pressure at surface) and work through. 23:15 - 00:00 0.75 DRILL P PROD1 Continue drilling ahead f/ 10837'. 1.67bpm 8.9/8.9 in/out fs= 3800psi 2-300psi motorwork, 4068psi bhp w/ 12.1 ecd. INC 69 deg Drill to 10860'. 3/23/2003 00:00 - 02:25 2.42 DRILL P PROD1 Continue drilling ahead f/ 10860'. INC 69 deg. Looking for A3 sand. 1.67bpm 8.9 in/out free-spin 381 Opsi w/ 2-300psi motor work. 1.6k wob pick-up wt 21 k dwn wt 2k. 4080 psi annular w/ 12.13 ecd. ROP increase to 100'+/hr at 10914' drill to 10921'. 02:25 - 04:15 1.83 DRILL P PROD1 Wiper trip. p/u 21.7k Confer with town geo. Decide this is the A3. Top of A3 @ 10,911 (6498'TVDss). Decide to turn TF Highside. 04: 15 - 06:00 1.75 DRILL P PROD1 Directionally drill f/ 10921' adjust TF to highside 2-3k wob. Slow drilling with abrupt TF change. Should pick-up. 0600 hr depth 10934'. 06:00 -10:15 4.25 DRILL P PROD1 Directionally drill. DH CT 4800-5000psi, DH annular 4000-4100, Circ press. 4000-4200, DH WOB=2500-3000Ibs. Drill to 11,108'md. Avg ROP=40fph. Revised plan is to land horizontal in A2 and then quickly build back up into the A3. This will result in 200' less A3 drilled, than if we had landed and stayed in the A3. Printed: 4/8/2003 11 :52:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) '") BP EXPLORATION ·OperationsSummary 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2003 10:15-11:15 1.00 DRILL P PROD1 Wiper to window. PU wt = 24500'. Tight spot: 1 0640-1 0680'md 11:15 -13:15 2.00 DRILL P PROD1 Directionally drill. DH CT 4800-5000psi, DH annular 4000-4100, Circ press. 4000-4200, DH WOB=2500-3000Ibs. 1.7in/out. Drill to 11,278'md. Avg ROP=85fph. 13:15 -15:00 1.75 DRILL P PROD1 Wiper to window. ECD and annular press drop after each wiper. 15:00 - 17:45 2.75 DRILL P PROD1 Directionally Drill, plan to roll TF over and target A3 sand @ 6502'TVDss. Having trouble getting started drilling, getting DH WOB 2000-35001bs, and 300lb motor work but no progress. DH CT 4900, DH Ann 3900-4000. Circulating press 4100-4200. 1.7 in/out Try PU, overpull, motor stalls out. RBIH try to start drilling, 11255' tight spot, hanging up on BHA? Backream / ream 11255' at a different orientations. Decide to POH and check BHA for failure. 17:45 - 19:45 2.00 DRILL N DPRB PROD1 POH above 1800' and close SSSV valve. Bleed annulus and confirm shut. Close EDC valve and continue POH 19:45 - 21 :00 1.25 DRILL N DPRB PROD1 LID motor/bit from BHA#6. P/U new motor. Scribe toolfaces. Check torque on service breaks. M/U injector. 21 :00 - 22:40 1.67 DRILL N DPRB PROD1 RIH to 350' shallow hole test and open EDC. Open SSSV. RIH following TIH pressure schedule. Through window no problem with highside TF. 22:40 - 23:05 0.42 DRILL N DPRB PROD1 Log tie-in. +2' correction. 23:05 - 00:00 0.92 DRILL N DPRB PROD1 Close EDC continue RIH setdown at 10668' work through to 10721' PUH to 10600' working back through, stacking out at 10670-85'. RIH setdown at 10880' 3/24/2003 00:00 - 00:50 0.83 DRILL N DPRB PROD1 Continue work to bottom. Tight at 10950' area where build started. Work to bottom with frequent pick-ups required with pumps on/off. 00:50 - 03:40 2.83 DRILL P PROD1 Drilling ahead f/ 11279' w/ INC 95 deg, working back up to the A3 sand. Free-spin 3560psi 1-200psi motorwork, 1.6bpm 8.95 in/out annular 4250psi 12.3ppg ECD 1-2k wob. Pick-up 25k dwn -2k Drilled to 11286. Frequent stalls here, good stall pressures. Make several 200' short trips. Finally get to drilling. Gamma shows entering A3 at 12275'md 6508'tvd. Drilling ahead with TF at 150 to land out mid-section of A3. Good ROP then slowing. Acting like the bit is balling. Good wt transfer but little to no motor work. Drill to 11338'. 03:40 - 03:50 0.17 DRILL P PROD1 Wiper trip 200' 03:50 - 04:40 0.83 DRILL N DPRB PROD1 Drill fighting balled bit at 11338'. Lost all signal from BHI tools. 04:40 - 06:00 1.33 DRILL N SFAL PROD1 Make wiper trip and looking at BHI surface cables for any damage. Found open short in cable coming from reel to SLB collector 06:00 - 07:00 1.00 DRILL N SFAL PROD1 Continue to trouble shoot MWD short in reel house with coil parked above window. Found bad connection, establish comms with MWD tool. 07:00 - 08:00 1.00 DRILL N SFAL PROD1 RBIH, 1.25bpm, oriented 330deg, 45fpm. Small bobbles near 10623' and 10648'md. 08:00 - 11 :15 3.25 DRILL N DPRB PROD1 Attempt to drill at 11338'. Still no progress on bottom. Try RIH with pumps off, bringing pumps up to fullrate and backreaming off bottom, no change. Park bit just off bottom, bring pumps up to 1.9bpm to try and "wash" the bit, no change. Park on bottom, 1.7/1.7bpm, Freespin 3700, circ press 3850-3870psi, Printed: 4/8/2003 11 :52:04 AM ) '} Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 9 of 15 BP EXPLORATION Operations Summary Report 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: 3/24/2003 08:00 - 11 :15 From - To Hours Task Code NPT Phase Description of Operations 11 :15 - 13:15 13:15 - 14:15 14:15-15:30 15:30 - 17:30 17:30 - 18:30 18:30-20:15 20:15 - 23:05 3/25/2003 23:05 - 00:00 00:00 - 00:40 00:40 - 04:30 04:30 - 06:45 06:45 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 11 :00 11 :00 - 13:00 13:00 - 13:30 13:30 -14:00 14:00 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 20:30 3.25 DRILL N DPRB PROD1 2.00 DRILL P PROD1 1.00 DRILL P PROD1 1.25 DRILL P 2.00 DRILL P PROD1 PROD1 1.00 DRILL P PROD1 1.75 DRILL P PROD1 2.83 DRILL P PROD1 0.92 DRILL P 0.67 DRILL P 3.83 DRILL P 2.25 DRILL P PROD1 PROD1 PROD1 PROD1 1.25 DRILL P PROD1 1.50 DRILL P 0.50 DRILL P 1.00 DRILL P 2.00 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 0.50 DRILL P 0.50 CASE P 2.00 CASE P PROD1 PROD1 PROD1 1.00 CASE P 3.00 CASE N PROD1 SFAL PROD1 DH ann 4015, DH CT 4510, DH WOB 37001bs. Launch 20bbls new mud down hole, no change. Launch 15bbl Caustic pill (8.9ppg, Formate Brine, unviscosified, Ph=13-13.5) down hole. See shale over shakers. Continue working on bottom See motor work come up, circ press 4250, and getting weight back. Drilling takes off. ROP=80fph Based on samples from 11338' (Shale, siltstone & sandstone very highly cemented with some Ankorite and Pyrite) we were working on a very hard stringer. Anchorage geo says this is not unexpected in A3. Drill to 11485'md. Avg ROP=75fph Directionally drill. Believed to have crossed an unmapped fault at 11277'md, town geo orders to drop 8'TVD and target 6508'TVDss. Drill to 11540'md Wiper to window, hole is in good condition. Directionally drill. 1.6in/out, Circ press 4000, DH ann 4100-4200, DH CT 4800, DH WOB 550. INC=85 Drill to 11685'md. Looking for 2nd predicted fault. Drilling ahead increase inc 89deg stilllookinmg for forcasted fault. Appear to have crossed fault sand/sand at 11650'. Drilled to 11731'. Wiper trip. p/u 25-6k. MW at 10860', 10659' - 10590' (3-4k overpull). Good to window. RIH 45fpm 1.3bpm 280 TF setdown at 10640' pick-up 50' and work back through with reduced gpm. Some hesitation at 10920-950'. Good to bottom. Drilling ahead f/ 11731' 1.7bpm 8.95ppg in/out free-spin 4050psi 2-300psi motor work. 50'-60'/hr rop. At 11825' A3 appears to have faulted out again. Drilled to 11882'. Predict 12-15'tvd above A3. Wiper trip to 10090'. Looked better at 10840'. Finish wiper trip. No problems to btm. Much better wiper trip. Continue drilling ahead f/ 11182'. Wiper trip. Pull tight at 11827' briefly stuck. Continue TOH 1.76bpm. RBIH Stack out at 11818', pull heavy, attempt to clean up tight spot from 11815-11830'md. Ream down past, PU backream. Repeat x3. (Geo: 11824'md faulted from A3 into A5 shale) Continue in hole to TO, tag at 12075'. Drilling. circ press 3650, DH ann 4020, DH CT 4580-4620, DH WOB 2000-2100. Plan to drop at 86deg to revised td of 12200. TO at 12200' At TO DH WOB=2000-2500 Slackoff=1 Klbs. Condition hole. Tie into PIP tag. Add 30' correction. Correct TO at 12227'. RIH to condition again. Tag TO at 12227'. POOH to PU liner. Lay in 80k LSRV Flo-pro in open hole. POH above 1800' and close SSSV valve. Bleed annulus and confirm shut. Close EDC valve and continue POH UD BHA. RU floor to run 2-3/8" , 4.6# slotted liner with 3" GS. MU 37 jts liner with cementralizers, pack off bushing, and round nose guide shoe. MU liner running assembly. Not able to establish comms with BHI tools. Found bad soldered connection in collector box at reel. Stab on coil and Printed: 4/8/2003 11 :52:04 AM ) ) IBPEX¡F>L.GRAXj"I<Df\J º!f.)e~ª~iE>~s.·.Sl.lrnliDªr'I·...~~f)Ð.rt DPRB PROD1 Started taking weight at 10670' work down, setdown at 11490'. P/U wt 28.5k work dwn to 11840' with numerious setdowns along the way. Worked on 11840' (last faulted area) for 30min with max RIH speeds without making progress. Setdowns are hard with no progress. Discuss options with town either TOH and p/u 1" CSH inner string with limited circulation rates or pick-up cleanout assembly. Decide for the motor cleanout because of hard setdowns. TOH with 2.375" liner following TOH pressure schedule to above SSSV. Close valve bleed down annulus, confirm valve shut. TOH to top of liner LID BHI and BOT tools. Stand back 12 stands of liner. P/U BHA #8 RIH. Pressure annulus to 1000 psi. Open SSSV. RIH following TIH schedule. Log gr tie in. RIH to condition & clean up for liner. 20K# up, 2K# dn wt. 2900 psi fs @ 1.21 bpm. Tight at 10560' and several spots down to 10850'. Work back up to 10705'. Stuck. Open EDC. 90% packed off above EDC port: ie: not bit stuck. Work pipe up & down to 50K#. 10% rtns. Pull 50K & bleed WHP down from 1120 to 300 psi. Came free. Increase WHP as per schedule & POOH slowly to csg. DPRB PROD1 Continue to attempt to clean up hole. Unable to get past 10650'. Try several pump rates & running speeds. Get stuck two more times. Rest hole. Pull up to 55K#. Finally popped free when WHP was dropped from 1200 to 300 psi, no pump rate. Hole conditions getting worse. Risk of losing BHA high and increasing. Pull into csg to discuss options. Discuss options with town. ( Decision made to set open hole whipstock and red rill 1 st lateral targets) POOH. POH above 1800' and close SSSV valve. Bleed annulus and confirm shut. Close EDC valve and continue POH Get off well. LD BHA. Weekly pressure test of BOPs. 250 psi/low 4500 psi/high 5 min each. Perform accumulator draw down test. Witness waived by J. Spaulding, AOGCC. Replace o-rings on lubricator sections and test same to 4500 psi. PJSM discuss picking up Weatherford Open hole whipstock assembly. P/U whipstock BHA. Stab-on coil. Surface check BHI comms - ok. M/U injector. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date Frorrf"Tó Hours Task Code NPT Phäse 3/25/2003 17:30 - 20:30 3.00 CASE N SFAL PROD1 20:30 - 23:00 2.50 CASE P PROD1 23:00 - 00:00 1.00 CASE N 3/26/2003 00:00 - 02:30 2.50 CASE N DPRB PROD1 02:30 - 03:00 0.50 CASE N DPRB PROD1 03:00 - 04:20 1.33 CASE N DPRB PROD1 04:20 - 04:45 0.42 CASE N DPRB PROD1 04:45 - 06:45 2.00 CASE N DPRB PROD1 06:45 - 07:00 0.25 CASE N DPRB PROD1 07:00 - 09:00 2.00 CASE N DPRB PROD1 09:00 - 12:30 3.50 CASE N 12:30 - 13:30 1.00 CASE N DPRB PROD1 13:30 - 14:30 1.00 CASE N DPRB PROD1 14:30 - 15:00 0.50 CASE N DPRB PROD1 15:00 - 15:45 0.75 CASE N DPRB PROD1 15:45 - 20:30 4.75 BOPSURP PROD1 20:30 - 22:00 1.50 BOPSUR P PROD1 22:00 - 22: 1 0 0.17 STKOH N DPRB PROD1 I 22: 1 0 - 22:45 0.58 STKOH N DPRB PROD1 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Descri ptionôf Operations function test tools. Stiil have problem. Unstab injector. Re-check surface connections-OK clean wet connect area. Stab-on coil. Retest wet connect -ok. M/U injector. RIH. Close choke and pressure up annulus to 800psi. Open SSSV pressure dropped to 725psi (11.1 ppg bhp @ 6500'tvd). Bump up annulus pressure to 1050psi and RIH following WHP vs. Bit Depth schedule pumping at .3bpm Printed 4/8/2003 11 :52:04 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Operations .Summa.ry. Report 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 3/26/2003 22:45 - 23:20 From - To· Hours Task Code NPT Phase PROD1 0.58 STKOH N 23:20 - 00:00 0.67 STKOH N PROD1 3/27/2003 00:00 - 02:30 2.50 STKOH N DPRB PROD1 02:30 - 04:25 1.92 STKOH N DPRB PROD1 04:25 - 05:00 05:00 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 15:45 15:45 - 16:30 16:30 - 18:45 18:45 - 19:05 19:05 - 00:00 3/28/2003 00:00 - 00:45 0.58 STKOH N 4.50 STKOH N 1.00 STKOH N 1.50 STKOH N 2.00 STKOH N 1.75 STKOH N 0.75 STKOH N 2.25 STKOH N 0.33 STKOH N 4.92 STKOH N 0.75 STKOH N DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Description of Operations RIH. Having trouble getting started with coil first 5'. Suspect residual bend from hard RIH with liner. Pressure up annulus to 900 psi and open SSSV. Continue RIH to 850' and lost comms with BHI. Checking surface connections. Again faults found in collector box within reel. RIH w/ Weatherford open hole whipstock. Stop at 10000' which is approximate depth of window whipstock tray. Attempt to lightly work through window but able to do. TOH following TOH pressure schedule to inspect Weatherford OH whipstock leading edge. Also plan to cut coil and rehead due to problems starting in hole. Pull above 1800' and close SSSV and bleed down annulus. Confirm closed. TOH. LID whipstock BHA. Cutting 25' coil. And reheading. Weatherford whipstock leading edge didn't have any marks on it to indicate hitting something. But the "Alpha Setting Tool" was slightly bent, will need repaired. Could have happened while hitting on top of the window whipstock. Pressure test & continuity test good. MU side track BHA (1.9 deg mtr w/ HC R60ST bit). Stab on well. RIH with BHA. Tag up at 10001'. Unable to get through window. Work pipe & pump. Very solid tag, clean pick-up. Log gr tie in up hole to verify on depth. Add 2' correction. Appear to be hitting top of whip stock tray. RIH fast, circulating at .75 bpm. Set down again. Very solid. POOH for dressing mill. At surface. Get off well. Inspect bit. No damage. Found bit face plugged with clay material. Conclude BHA was hitting clay ball above window. Also explains why aluminum whipstock would not pass through window either. MU 2.8" parabolic speed mill on 1.9 deg mtr. RIH with clean out assembly. Log tie-in at points above "pip" tag +7' correction. RIH tag at 10003'. FS 4080 psi at 1.85 bpm 3875 annular 11.7 ecd. Frequent stalls w/low wob at 10003. Milled through something in 5 min. wash/ream down to 10016'. PUH above to 9990' clean pick-up. (pumping 5 bbl 80k LSRV sweeps/15m in). RIH clean to 10016'. W/R mw at 10033' -10050' w/rto 10066'. P/U clean to 9990'. RIH clean to 10066'. W/R in 50' intervals with toolface oriented as originally drilled, then rolling over 180 deg and washing back to just below window. Clean down to 10300', 200psi mw starting here to 10350'. PUH clean back to 350 w/r caught MW at 375' - 395' 420-435' clean to 10500'. PUH mw and overpull at 10350' w/r up to 10035'. RIH clean to 10500'. PUH to window -clean. RIH ro 10500 chase high vis pill back to window. Looks good. RIH clean to 10500'. POH to window -clean. RIH clean to 10500' and chase high vis out to above window. Hole looks good. Printed: 4/8/2003 11 :5204 AM ) ) æ.E>...l=~J?lli<JRh\"fIØN Operatiol1sSÜl11mary TOH following "TOH Pressure Schedule". Pull above 1800' and close SSSV. Confirmed closed. Bleed down annulus. Finish TOH. LID cleanout BHA and P/U Weatherford Openhole Whipstock assembly. Stab on coil check surface comms connection. M/U injector. Open EDC. RIH above SSSV. Pressure up annulus to 950psi. Open SSSV. TIH following TIH Schedule. Slow through to 1 0050'. Log tie-in to "pip" tag. +8' correction. RIH to 10448'. Close circ sub and pressure up on coil to begin setting process. Pull 50K up on coil to complete set and shear off ws/ billet assembly. Estimate top of WS at 10425'. POOH with ws/billet setting tool. At surface. Get off well. Found setting rod, lower setting tool, collet assemby had sheared off inside setting tool. Assume rod & other parts are downhole inside billet assembly. Decide to OH sidetrack. MU 1.9 mtr with 2.75 R60st bit. Get on well. RIH with open hole sidetrack BHA. Log gr tie in at pip tag. Add 13.5' correction. RIH to 10374'. No sign of whipstock setting tool fish. POOH to sidetrack depth of 10343.5'. Begin reaming trough from 10330' t01 043.5'. 3895 psi fs @ 1.68 bpm. Add 2 drums lubtex to system. Make three passes, up at 1 fpm, down at 0.5 fpm. TF:180 deg. Begin time drilling at 10343.5'. l' per hr to 10344.5. 2' per hr to 10346.5'. 4' per hr from 10346.5' to 10350.5' drill to 10360' at 150R TF. Backream w/ 90 TF to 10345' at 2'/min. Continue drilling ahead f/ 10360' with 10R TF to 10380'. PUH to 10300' RIH dry to 13380' Sidetrack looks good. Bring on pump and flop TF to 180 backream back to 10330'. TOH to window - clean. Open EDC. Continue TOH for drilling assembly following TOH Pressure Schedule above 1800'. Close SSSV check pressure continue TOH to surface. Reset BHI motor to 1.1 deg and p/u new PDC bi-center bit. (check adjustment bars on gooseneck, looking for problems we see with 5-6k negitive wt while RIH. Nothing found.) RIH open EDC and pressure up annulus to 800 psi. Open SSSV no incldec in pressure seen. Continue RIH following RIH Pressure Schedule. Adding KlayGuard to mud system Continue RIH with laterial drilling assembly to 10016'. Log tie-in at pip tag. +3' correction. Continue RIH tagged up at 10382'. (found sidetrack!) Directionally drilling ahead with sidetrack #01 from 10382'. free-spin 3700psi at 1.5bpm 200 dpsi motor work 8.9ppg in/out 4050-4100psi annular w/ 12.00ppg ecd. 1-3k wob 60-80'/hr. Drill to 10550'. Raised Lubetex f/ 10>12ppb KlaGauard and f/5 > 7% Lubtex DPRB PROD1 Wiper trip to above sidetrack. Hole smooth. DPRB PROD1 Drilling ahead. 3650 psi @ 1.6 bpm. 200-300 dpsi. 1:1 rtns. ROP:50-70 fph. WOB:1000-2000#. Hold 45 psi WHP. 4200 psi Ann press, 12.1 ppg ECD. Drill to 10700'. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 3/28/2003 00:45 - 02:30 1.75 STKOH N DPRB PROD1 02:30 - 03: 15 0.75 STKOH N DPRB PROD1 03:15 - 05:40 2.42 STKOH N DPRB PROD1 05:40 - 06:00 0.33 STKOH N DPRB PROD1 06:00 - 06:30 0.50 STKOH N DPRB PROD1 06:30 - 08:15 1.75 STKOH N DPRB PROD1 08: 15 - 09:30 1.25 STKOH N DPRB PROD1 09:30 - 11 :45 2.25 STKOH N DPRB PROD1 11:45-12:15 0.50 STKOH N DPRB PROD1 12:15 - 12:45 0.50 STKOH N DPRB PROD1 12:45 - 15:30 2.75 STKOH N DPRB PROD1 15:30 - 20:30 5.00 STKOH N DPRB PROD1 20:30 - 22:35 2.08 STKOH N DPRB PROD1 22:35 - 23:20 0.75 DRILL N DPRB PROD1 23:20 - 00:00 0.67 DRILL N DPRB PROD1 3/2912003 00:00 - 02:00 2.00 DRILL N DPRB PROD1 02:00 - 02: 1 0 0.17 DRILL N DPRB PROD1 02: 10 - 02:35 0.42 DRILL N DPRB PROD1 02:35 - 05:45 3.17 DRILL N DPRB PROD1 05:45 - 06:30 06:30 - 09:15 0.75 DRILL N 2.75 DRILL N Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Description of Operations Printed: 4/8/2003 11 :52:04 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From - To Hours Task Code NPT Phase Description of Operations 3/29/2003 09:15 -10:15 1.00 DRILL N DPRB PROD1 Wiper trip to window. Discuss directional plan with town. 10:15 -14:00 3.75 DRILL N DPRB PROD1 Drill ahead. Dropping angle after avoiding B1 shale. Planning to land in A3 14:00 - 15:00 1.00 DRILL N DPRB PROD1 Wiper trip to window. Hole smooth. Begin mud swap. 15:00 - 18:00 3.00 DRILL N DPRB PROD1 Drill ahead. 3400 psi fs @ 1.6 bpb. 200-300 dpsi. 1:1 rtns. ROP:30 fph. WOB:1000# 4049 annular psi. 12.0 ppg ECD. Drill to 11000'. 18:00 - 18:55 0.92 DRILL N DPRB PROD1 Wiper trip to window. New mud all the way around. 200psi drop in annular/ecd's. No problems with wiper trip. 18:55 - 22:15 3.33 DRILL N DPRB PROD1 Directionally drilling ahead f/ 11000'. Up wt 23K free-spin 3400psi @ 1.5bpm 8.83ppg 1.5/1.5 in/out Annular = 3990psi 11.87ppg/ecd while maintaining 11 Opsi on choke 2-3k# wob Ran into Ankorite at 11078.7' stopped dead for 30 min. Drill to 11 080' Target window for landing reported to be 6503 - 6506'. Build rate seen since truning straight up will put us at 6505.96'. Call to town geo. Maybe not good enough may trip for stronger motor? 22:15 - 00:00 1.75 DRILL N DPRB PROD1 Wiper trip. (Discuss landing with town. Decide to drill ahead.) 3/30/2003 00:00 - 00:20 0.33 DRILL N DPRB PROD1 Finish wiper trip. 00:20 - 01 :35 1.25 DRILL N DPRB PROD1 Work through Ankorite f/ 11080-81 '. Backreaming at 180 TF several times and maximum WOB. (Motor bend appears to hang-up through this stuff and shows WOB but no motorwork) 01 :35 - 02:45 1.17 DRILL N DPRB PROD1 Directionally drill ahead with highside TF. Drill into A3 and landout at 11, 120'md, 6505.7'sstvd. (target 6503'-6506'). Drill ahead 1.5 bpm 3300 fs 200psi motorwork 1-2k wob 120'/hr. Drill to 11218'. 02:45 - 04:35 1.83 DRILL N DPRB PROD1 Wiper trip to window. PLAN FORWARD: Talked with town geo plan is to drop angle once back on bottom and land out in A2 sand at +/- 11400'md 6530'sstvd 04:35 - 06:30 1.92 DRILL N DPRB PROD1 Directionally drill ahead f/ 11218' Free-spin @ 1.5 3200psi. 8.89 in/out 1:12-300 psi motor work. 1-2k wob 50-70'/hr. Diving for A2. Drill to 11360'. 06:30 - 07:30 1.00 DRILL N DPRB PROD1 Wiper trip to window. Hole smooth. Taking a little weight from 11 000' to 111 00'. 07:30 - 10:30 3.00 DRILL N DPRB PROD1 Drill ahead. 3200 psi @ 1.65 bpm. 200 dpsi on mtr. 1:1 rtns. WOB: 1000-2000#. ROP:50-80 fph. 4093 psi ann press, 12.08 ecd. Drill to 11500'. 10:30 - 11 :30 1.00 DRILL N DPRB PROD1 Wiper trip to window. Hole smooth. 11 :30 - 15:00 3.50 DRILL N DPRB PROD1 Drill ahead. 3300 psi @ 1.65 bpm. 200 dpsi on mtr. 1:1 rtns. WOB: 1000-2000#. ROP:50-80 fph. 4093 psi ann press, 12.08 ecd. Add additional2ppb klagard. Drill to 11650'. 15:00 - 16:00 1.00 DRILL N DPRB PROD1 Wiper trip to window. Hole smooth. 16:00 - 18:30 2.50 DRILL N DPRB PROD1 Drill ahead. 3300 psi @ 1.65 bpm. 500 dpsi on mtr. 1:1 rtns. WOB: 1500-2000#. ROP:50-80 fph. 4100 psi ann press, 12.13 ecd. Drill to 11815'. 18:30 - 19:50 1.33 DRILL N DPRB PROD1 Wiper trip to window. Tie-in. +10'. TIH. No problems - hole looks good. 19:50 - 23:00 3.17 DRILL N DPRB PROD1 Directionally drill ahead from corrected TD of 11825'. Free-spin 3250psi 200psi motor work. 1.54bpm in/out 8.91 mw annular = 4050psi w/ 11.95ppg ecd 1-2k wob 80-100'/hr At 11880' dived for A2 sand. Drilled to 12000'. Printed: 4/6/2003 11 :52:04 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/30/2003 3/31/2003 4/1/2003 ) EXPLORATION Ope.rationsSummaryReport 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 23:00 - 00:00 00:00 - 01 :05 01 :05 - 03:55 03:55 - 09: 15 1.00 DRILL N 1.08 DRILL N 2.83 DRILL N DPRB PROD1 DPRB PROD1 DPRB PROD1 5.33 DRILL N DPRB PROD1 09:15 - 10:00 0.75 DRILL N DPRB PROD1 10:00 - 12:30 2.50 DRILL N DPRB PROD1 12:30 - 13:00 0.50 DRILL N DPRB PROD1 13:00 - 13:45 0.75 DRILL N DPRB PROD1 13:45 - 14:15 0.50 CASE C COMP 14:15 - 16:15 2.00 CASE C COMP 16:15 - 16:30 0.25 CASE C COMP 16:30 - 00:00 7.50 CASE C COMP 00:00 - 02:05 02:05 - 04:05 04:05 - 06:00 06:00 - 07:00 2.08 CASE C 2.00 CASE C COMP COMP 1.92 CASE C COMP 1.00 CASE C COMP Page 14 of 15 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Description of Operations Wiper trip to window. Pick-up 23k. RIH from window. Down wt 2500#. Hole good. Directionally drill ahead f/ 12000'. Free-spin 3280psi. 200psi motor work at 1.53bpm. 1-2k wob 50-60'/hr. Ran into Ankorite stringer at 12059' work on it for 20min with different TF's. Drill ahead diving for A2. Land out at 6550'tvd -no sand. Shot for 6555' but not seeing anything good ROP wise or gamma. Call TD at 12130'md 6553'sstvd Wiper trip to window. Looks good. Tie-in +7' correction. Corrected TD is 12133'. RIH. Tight near btm from 12070' to 12133'. (non-pay zone below A2). Wipe back to window. RIH and wipe back to TD. Tight below 12100'. Decide to leave btm 33' alone as it is non-pay. Lay in 11.5 ppg viscous pill from 12100'. POOH. Lay in 11.6 ppg kill wt brine using pressure/displacement schedule. At surface. Monitor well for flow. Hold PJSM to discuss liner running procedure during flow check. Hole stable. LD drilling BHA. RU floor to run liner. MU 34 jts slotted (from derrick) & 35 jts solid liner (from pipe shed) with tapered guide shoe (2-3/8", L-80, 4.6#). Cementralizer on each joint. Get on well. RIH w/ liner at reduced speed to surge effects..stop at flag correct depth. RIH 19:40hrs setdown at 11502'. P/U wt 42k 11520', 11543' p/u 36k, 11545', p/u 37k, 11565'/39k, 11608'/40k, 11603'/40k, 11625'/36k, 11623'/35k/ 11623,137k, 11670'/36k,11676'/40k, 11675'/42k, 11680'/39k, 11683'/39k, 11688'/39k, 11685'/38k, 11690'/ , 11708'/44k, 11694'/40k/, 11724'/twice/45k, 11713'/40k, 11730'/42k, 11731 '/41 k, 11800'/45k, 11853'/41 k, 11860'/44k, 11832k/45k, 11860'/42k, X40min, 22:30hrs call for drill collars. 11910'/42k, 11920'/40k, 11926'/43k, 11935'/45k, 11955'/40k, 11972'/47k, 48k,(high dogleg area) 23.40hrs setting at 11952' disconnect from liner. (20.3k up weight w/o liner). Switch to 8.9ppg mud and displace 11.8ppg KMW from annulus Continue swapping KWM to 8.9ppg in annulus. Maintaining 700psi on wellhead. Latch on to liner wIGS. P/U wt 33k. TIH w/ liner setdown at 11985'. P/U 36k (better weight transfer seen both up and down) setdown 12016'/35k, 12022'/37k, 12032'/37k, 12040/35k, 12043'/35. Stop in tension and pump 10bbl mud. (displace KWM with 8.9ppg mud fromsolid part of liner and liner annulus. 12046'/36k, 12077'/30k it's going just a matter of time. Pump several times while in tension and make it down to 12133' based on flagged coil. TOP of LINER @ 9936'md. Pump at 1.6bpm while in compression and release from liner. P/U wt 22k. Displace 8.9ppg Flo-Pro mud from annulus with 8.6ppg 2% KCL f/ 9880'md. TOH while displacing to above SSSV. Close SSSV. FP tbg from1800' with diesel. Continue to Printed: 4/8/2003 11:52:04 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3N-18 3N-18 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/17/2003 Rig Release: Rig Number: 2 Spud Date: 3/3/1980 End: Date From - To Hours Task Code NPT Phase Descri ption· of Operations 4/1/2003 06:00 - 07:00 1.00 CASE C CaMP POOH. 07:00 - 09:00 2.00 CASE C CaMP At surface. Get off well. Test e-line. LO BHA. 09:00 - 13:30 4.50 RIGO P POST NO BOPS. NU tree cap & test same. Clean pits. Clean cuttings tank. Release rig at 1330 on 4/1/03 Printed: 4f8f2003 11 :52:04 AM ) C)03-0\C, IZ~'II . ..."il:. ........:..:..~~~ IN~tt~t.f .. .. ~ ~\') \\(\ ~ BP Baker Hughes INTEQ Survey Report Com!an~: Fi{'ld: Silt': \Vdl: Wcllpalh: Phillips Alaska. Inc. Kuparuk River Unit KRU 3N Pad 3N-18 3N· 18L 1 Dale: 4/29/2003 Time: 09:09:24 Page: Co-(rdinale(NE) Rereren~e: Well: 3N-18, True North 'h'r1ical (TYD) Refl'rencc: 3N-18 RKB 68.0 Section (\."S) Relhl'ncE': Well (O.OON.O.OOE.25.00Azi) Sun'{'~' Calculatjun l\Iethod: Minimum Curvature Db: Sybase 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 BGGM2002 Site: KRU 3N Pad UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013799.38 ft 518425.12 ft Latitude: Longitude: North Reference: Grid Convergence: 70 26 55.947 N 149 50 58.873 W True 0.14 deg Well: 3N-18 Slot Name: Well Position: +N/-S +E/-W Position Uncertainty: 0.00 ft Northing: 6013799.38 ft Latitude: 0.00 ft Easting: 518425.12 ft Longitude: 0.00 ft 70 26 55.947 N 149 50 58.873 W Wellpath: 3N-18L 1 500292159560 Current Datum: 3N-18 RKB Magnetic Data: 1/23/2003 Field Strength: 57491 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 3N-18L 1PB1 10330.00 ft Mean Sea Level 25.43 deg 80.79 deg Direction deg 25.00 Height 68.00 ft Survey Program for Definitive Well path Date: 4/28/2003 Validated: Yes Actual From To Survey ft ft 100.00 10006.00 10006.00 10330.00 10330.00 12133.00 Version: 2 Toolcode Tool Name Gyro (0) MWD (3) MWD SRG MWD MWD Conventional SRG single shots MWD - Standard MWD - Standard Annotation I\lD ft 10330.00 12133.00 T\"D ft 6463.45 6620.68 KOP TD Survey: MWD Start Date: 3/31/2003 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey l\1D Incl Aåm T\iD SST\'D N/S [)\\' M,apN MapE VS DLS ft deg deg ft ft ft ft ft ft ft OOg/1 GOft 10330.00 90.07 61.63 6463.45 6395.45 -5599.24 4675.18 6008212.27 523113.66 -3098.82 0.00 10362.71 83.70 65.84 6465.23 6397.23 -5584.80 4704.44 6008226.79 523142.89 -3073.36 23.32 10391.24 89.24 68.43 6466.99 6398.99 -5573.74 4730.67 6008237.91 523169.08 -3052.26 21.43 10428.09 88.25 61.66 6467.80 6399.80 -5558.21 4764.05 6008253.52 523202.42 -3024.07 18.56 10460.03 88.47 57.89 6468.71 6400.71 -5542.14 4791.63 6008269.66 523229.96 -2997.85 11.82 10502.66 87.88 51.44 6470.07 6402.07 -5517.51 4826.37 6008294.37 523264.64 -2960.85 15.19 10541.35 89.54 48.92 6470.94 6402.94 -5492.74 4856.08 6008319.21 523294.28 -2925.85 7.80 10581.12 91.96 44.44 6470.42 6402.42 -5465.47 4885.00 6008346.55 523323.13 -2888.90 12.80 10612.02 92.79 36.49 6469.14 6401.14 -5442.00 4905.02 6008370.07 523343.09 -2859.17 25.85 10643.00 88.74 32.63 6468.72 6400.72 -5416.50 4922.59 6008395.61 523360.59 -2828.64 18.06 10698.79 90.31 23.59 6469.19 6401.19 -5367.34 4948.84 6008444.82 523386.72 -2772.99 16.45 Rl:C~'VEU MAY 1 5 2003 AI~~ska Oi: (;. Gas Cons. C.ommiœ1on Al1r-110fÞ'J't1B ) BP ·rooI~· . .:. :.: Baker Hughes INTEQ Survey Report ..........:..~~~ ~.~·rEQ Corup¡¡n~: Phillips Alaska. Inc. Oat(': 4/29/2003 Tim(': 09:09:24 Page: Field: Kuparuk River Unit c.)-ordinaw(NE) Reference: Well: 3N-18, True North Site: KRU 3N Pad Vertical (TYO) Rl·{crencc: 3N-18 RKB 68.0 ,.veil: 3N-18 $(oction (VS) ReÈ'ft'nce: Well (O.OON.0.OOE.25.00Azi) Wellp<úh: 3N-18L 1 Sun'c) CalcuJaliun Metbod: Minimum Curvature Db: Sybase Survey 1\10 luet Azim TVO SSTVD N/S E/W MlI.pN !\IapE '·S DLS fl deg deg ft fr ft rt ft ft ft deg/100ft 10733.55 84.81 24.58 6470.67 6402.67 -5335.65 4963.01 6008476.55 523400.81 -2738.28 16.08 10764.30 80.26 26.54 6474.66 6406.66 -5308.15 4976.16 6008504.08 523413.89 -2707.80 16.09 10799.76 75.15 28.48 6482.21 6414.21 -5277 .43 4992.15 6008534.83 523429.80 -2673.20 15.37 10831.85 71.65 28.79 6491.38 6423.38 -5250.44 5006.89 6008561.85 523444.47 -2642.52 10.95 10866.74 70.06 21.99 6502.83 6434.83 -5220.69 5021.02 6008591.64 523458.53 -2609.58 18.97 10900.29 69.11 15.89 6514.54 6446.54 -5190.97 5031.22 6008621.38 523468.66 -2578.33 17.27 10934.30 68.25 12.22 6526.91 6458.91 -5160.25 5038.92 6008652.12 523476.27 -2547.23 10.37 10969.73 68.68 7.07 6539.92 6471.92 -5127.77 5044.43 6008684.61 523481.71 -2515.47 13.57 11000.79 71.64 5.86 6550.46 6482.46 -5098.74 5047.72 6008713.64 523484.93 -2487.77 10.21 11030.31 73.77 356.74 6559.26 6491.26 -5070.60 5048.35 6008741.78 523485.48 -2462.00 30.36 11060.43 77.38 354.94 6566.76 6498.76 -5041.51 5046.23 6008770.86 523483.29 -2436.53 13.31 11091.84 83.54 354.24 6571.96 6503.96 -5010.69 5043.30 6008801.67 523480.29 -2409.83 19.73 11120.02 89.39 352.39 6573.70 6505.70 -4982.77 5040.03 6008829.58 523476.95 -2385.91 21.77 11150.30 91.26 356.35 6573.53 6505.53 -4952.64 5037.06 6008859.70 523473.91 -2359.86 14.46 11179.37 90.74 1.46 6573.02 6505.02 -4923.59 5036.51 6008888.74 523473.28 -2333.77 17.67 11210.20 89.26 3.98 6573.02 6505.02 -4892.80 5037.97 6008919.54 523474.67 -2305.24 9.48 11240.46 85.58 2.85 6574.38 6506.38 -4862.63 5039.77 6008949.71 523476.39 -2277.14 12.72 11269.63 80.98 6.22 6577.80 6509.80 -4833.76 5042.06 6008978.58 523478.61 -2250.01 19.50 11299.65 77.69 8.39 6583.35 6515.35 -4804.51 5045.80 6009007.84 523482.28 -2221.91 13.06 11333.39 82.69 7.03 6589.10 6521.10 -4771.57 5050.26 6009040.78 523486.66 -2190.18 15.34 11364.78 84.19 7.19 6592.68 6524.68 -4740.63 5054.12 6009071.73 523490.44 -2160.50 4.81 11394.79 89.14 11.07 6594.43 6526.43 -4711.06 5058.87 6009101.31 523495.12 -2131.70 20.94 11427.47 92.08 9.68 6594.08 6526.08 -4678.92 5064.76 6009133.46 523500.92 -2100.09 9.95 11460.10 92.45 7.13 6592.79 6524.79 -4646.67 5069.52 6009165.72 523505.61 -2068.84 7.89 11494.44 92.94 17.32 6591.17 6523.17 -4613.19 5076.78 6009199.21 523512.78 -2035.43 29.68 11527.71 93.62 18.27 6589.27 6521.27 -4581 .57 5086.93 6009230.86 523522.85 -2002.48 3.51 11562.75 92.79 28.21 6587.31 6519.31 -4549.46 5100.71 6009263.00 523536.56 -1967.56 28.42 11593.28 90.83 30.46 6586.34 6518.34 -4522.86 5115.66 6009289.63 523551.44 -1937.13 9.77 11630.53 88.87 34.30 6586.44 6518.44 -4491.41 5135.61 6009321.13 523571.30 -1900.20 11.57 11663.81 90.03 40.20 6586.76 6518.76 -4464.93 5155.74 6009347.65 523591.37 -1867.69 18.07 11695.06 89.97 46.35 6586.76 6518.76 -4442.19 5177.15 6009370.44 523612.72 -1838.03 19.68 11728.11 89.63 48.26 6586.87 6518.87 -4419.78 5201.44 6009392.91 523636.95 -1807.46 5.87 11759.53 88.07 44.28 6587.51 6519.51 -4398.07 5224.14 6009414.67 523659.59 -1778.19 13.60 11796.06 87.54 42.70 6588.90 6520.90 -4371.59 5249.26 6009441.21 523684.65 -1743.57 4.56 11831.56 87.06 36.42 6590.58 6522.58 -4344.27 5271.83 6009468.59 523707.15 -1709.27 17.72 11863.09 89.08 29.59 6591.64 6523.64 -4317.86 5288.98 6009495.04 523724.23 -1678.09 22.58 11891.87 88.59 31.54 6592.23 6524.23 -4293.08 5303.62 6009519.85 523738.80 -1649.45 6.98 11922.00 85.15 28.96 6593.87 6525.87 -4267.10 5318.77 6009545.87 523753.89 -1619.50 14.26 11950.16 81.66 30.89 6597.11 6529.11 -4242.86 5332.72 6009570.14 523767.78 -1591.63 14.14 11974.43 79.11 34.88 6601.16 6533.16 -4222.77 5345.71 6009590.26 523780.72 -1567.94 19.32 12000.39 78.19 29.63 6606.27 6538.27 -4201.25 5359.29 6009611.81 523794.24 -1542.70 20.14 12030.03 82.10 35.24 6611.35 6543.35 -4176.63 5374.95 6009636.47 523809.84 -1513.76 22.84 12060.65 85.98 31.51 6614.53 6546.53 -4151.20 5391.69 6009661.93 523826.52 -1483.64 17.53 12100.75 84.81 20.67 6617.76 6549.76 -4115.36 5409.24 6009697.81 523843.98 -1443.74 27.10 12133.00 84.81 20.67 6620.68 6552.68 -4085.31 5420.58 6009727.89 523855.24 -1411.71 0.00 Phillips Alaska, Inc. WELlPATH DETAILS Parent Welpath: Tie on MD: 3N-18L1 500292159560 3N-18L1PB1 10330.00 Rig: Nordic 2 Ref. Datum: 3N-18 RKB 68.0Oft V.Section Origin Origin Starting Angle +NJ-S +E1-W From TVD 25.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordlnate (N/E) Reference: Well Centre: 3N-18, True North Vertical (TVO) Reference: System: Mean Sea Level Mea~~~~~~~ ~:~:~::~: ~~0\8 W&N,O,0608~¿0 Calculation Method: Minimum Curvature ANNOTATIONS NO þ'ID Annotalon g~ ~~~ =~ =~ o oa -U1C1 S) .crE2 71 Poytpn ~:~~~111 6395 45 1033000 KOP 655268 1213300 m 5850-:(: '::fIllt-- mälf B~ LEGEND T ~::g.3~!1~{Plar #1.1 /~\ M JIoj.1B!~-1BL1PB11 ¡ ~ JIoj·IBL1 : t 0/ {13' ;_'å~~J H'lgl~~ f~~~: ~~~tÆt~;'~~:ü~x~ Wellpath: (3N-1 Bl3N-1BL 1) Azimuths to True Ncrth Magnetic North: 25.43' Magnetic Field Strength: 57491nT Dip Angle: 80.79' Date: 1/2312003 Model: BGGM2002 3~~r?:··~ ~~~ . : H~·E~·~:::-:, ._........ ,'. ..' c.o",. ....::......::.'.-:-.'..;-;...... . - -. ... ... . ... ~~~{;~ti[~ Created By: Brtj Po1nis Date: 4/29/2003 :OOoOOPhillips J!\TfJì, C':-:(:~-;I;t k,ft,)::"~:ti('I: ---------------.-----------_._--- -400~::.:~~~Hl:~:,~~~~-~~~l+:~:H+,E::~l:~+~:,~::~~:H:~~:~~+l:~:::~:+~+:++:+,~::~~:~,+:::~¡:+~~:~:~~+l:~l:~::~Hl:+::~~:iHl~::,~~~i}~l,~:~:,¡:+il~~::~+:~l::,~~~+~+:+++:i::.~:~Hl~, a. I'J IIIII 1111_'.:at= ',1 - -4100-: j~PIII._11 11'11""II,_II:Ii-;III__' I..!U -4200-: -' .\(11' . , :ê" -I ~",",I'" ... ! ! õ -I,.',",' , ~ -4 70o--.{,:· .:., ". :.:.; ::.:.: .:.: .:.:. :.:.: .:., .:.,::..: .:.: .:.,:..:: .:', .:.::. .::: .:,: .'.; :::::"::'-";:::'-;"";"":"':::::.'::i~:;'::' "':'::;'.:-/-. -.:::.'.':".':".:::::.:::'.':;'.:::::',:.-;.':;'.:::::.':"'::;"::::"'::"':";":"':":':"".'::.'::::.:::".::;-.::;'::'.:::,:.':.:::".'.'.:::.:.':".::. - I I !:=4'#Urþi~m¥JmlJmW';¡t;¡tBt;p¡¡t¥jmlPjt;;~;¡;I¥.';;;mI¡;t;r;tfljmH;¡!4¡;i;k¡;iJj4;lMi;;;~t4 -- _:.;' H.t I,I, '''I,J~ 1111..._- \ ", , , . I I' :":' 'I..... , " I' I·i. 'I i :' 'I I" . 'I' : I , i I I I'. 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 - ~:I ': ~~,._""': ':'~'.'_.-~~;';~;~=:;;~;.;~~~~>~:,.:: ,- ,. .'.'.. ., -, - - .. .,-..... .... ......., ,....- .',.- -3300-3250 -3200 -3150 -31'00 -3050 -3Òoo -2950 -2900 -2850 -2800 -2750 -2700-2650 -2600 -2550 -2500-2450 -2400 -2350 -2300-2250-2200 -2150 -2100 -2050 -2ÒOO-1950 -1900 -1850 - 1£;00-1"750 -1700 -1650 -1600 -1550 -1500-1450-1400 -1350 Vertical Section at 25.00° [50ft/in] -1/29/2003 9: 18 AM Compäny: Field: Site: Wen:. Wellpatb: Phillips Alaska,lnc. Kuparuk River Unit KRU 3NPad 3N..:18 3N~18L1 PB1 ) ') BP Baker Hughes INTEQ Survey Report Hila s lNTßQ Date: 4/29/2003 Time: 09:07:03 Page: Co";ordinate(N~)Reference: Well:3N~18, True North Vertica.l (TVD) Reference: 3N~ 18 RKB68,0. . ~ection (VS) Reference: Well (O:OON;O;OOE: 127, 15Azi) Survey Calculation J\lethod: Minimum Curvature Db: Sybase 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 Site: KRU 3N Pad UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: 3N-18 6013799.38 ft 518425.12 ft Map Zone: Coordinate System: Geomagnetic Model: Latitude: Longitude: North Reference: Grid Convergence: Slot Name: Well Position: +N/-S +E/-W Position Uncertainty: 0.00 ft Northing: 6013799.38 ft Latitude: 0.00 ft Eastillg : 518425.12 ft Longitude: 0.00 ft Wellpath: 3N-18L1PB1 500292159570 Current Datum: 3N-18 RKB Magnetic Data: 4/28/2003 Field Strength: 57495 nT Vertical Section: Depth From (TVD) ft 0.00 Survey Program for Definitive Well path Date: 4/28/2003 Validated: Yes Actual From To Survey ft ft 100.00 10006.00 Gyro (0) 10006.00 12227.00 MWD Annotation MD ft 10006.00 12227.00 Survey: MWD TVD ft 6411.42 6603.12 KOP TD Height 68.00 ft +NI-S ft 0.00 Alaska, Zone 4 Well Centre BGGM2002 70 26 55.947 N 149 50 58.873 W True 0.14 deg 70 26 55.947 N 149 50 58.873 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 3N-18 10006.00 ft Mean Sea Level 25.33 deg 80.79 deg Direction deg 127.15 Version: Toolcode SRG MWD Tool Name Conventional SRG single shots MWD - Standard Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey MD ft 10006.00 10021.90 10050.95 10082.68 10111.41 10141.56 10171.13 10204.86 10230.22 10270.25 10300.53 10334.72 loci deg 53.35 61.03 65.34 66.60 74.06 81.57 89.63 88.96 89.79 90.67 92.61 89.66 Azim deg 138.80 132.00 119.00 104.62 98.49 88.53 77.74 73.43 70.03 63.03 63.09 61 .40 TVD ft 6411.42 6420.03 6433.18 6446.16 6455.83 6462.20 6464.48 6464.89 6465.17 6465.01 6464.14 6463.46 SSTVD ft 6343.42 6352.03 6365.18 6378.16 6387.83 6394.20 6396.48 6396.89 6397.17 6397.01 6396.14 6395.46 N/S ft -5620.14 -5629.61 -5644.57 -5655.28 -5660.66 -5662.43 -5658.90 -5650.50 -5642.55 -5626.62 -5612.91 -5596.99 Start Date: Engineer: Tied-to: E/W ft 4386.35 4395.74 4416.82 4443.63 4470.11 4499.47 4528.67 4561.33 4585.40 4622.10 4649.08 4679.33 3/25/2003 From: Definitive Path MapN ft 6008190.67 6008181.21 6008166.31 6008155.66 6008150.35 MapE ft 522824.92 522834.33 522855.44 522882.28 522908.76 6008148.66 6008152.26 6008160.73 6008168.74 6008184.76 522938.12 522967.31 522999.95 523024.00 523060.65 6008198.54 6008214.53 523087.60 523117.80 VS ft 6890.31 6903.52 6929.35 6957.19 6981.54 7006.01 7027.15 7048.11 7062.50 7082.12 7095.34 7109.84 DLS deg/100ft 0.00 60.16 42.57 41.56 32.82 40.76 45.44 12.93 13.80 17.62 6.41 9.94 ) ) BP Baker Hughes INTEQ Survey Report LNT.EQ Company: Phillips Alaska, .Inc. Date: 4/29/2003 Time: 09:07:03 Page: 2 Field: Kuparuk River Unit Co";ordinate(NE) Reference: Well: 3N~18, True North Sit~: KRU 3N Pad Vertical ('fVD) Refel'ence: .3N-18 RKB 68.0 Well: 3N-1 i3 Section (VS) Reference; Well (0.00N,O:00E,127.15Azi) Wellpath: 3N-18L 1 PB1 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD loCI Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 10365.90 86.69 53.26 6464.46 6396.46 -5580.19 4705.54 6008231.40 523143.97 7120.58 27.77 10396.33 85.34 48.35 6466.57 6398.57 -5561.01 4729.05 6008250.63 523167.44 7127.74 16.70 10430.87 87.06 45.10 6468.86 6400.86 -5537.39 4754.14 6008274.31 523192.46 7133.47 10.63 10461.82 91.65 43.16 6469.21 6401.21 -5515.18 4775.68 6008296.57 523213.95 7137.23 16.10 10496.98 92.18 37.31 6468.04 6400.04 -5488.37 4798.37 6008323.44 523236.57 7139.12 16.70 10530.43 90.34 41.82 6467.30 6399.30 -5462.59 4819.67 6008349.26 523257.80 7140.52 14.56 10566.10 86.47 39.91 6468.29 6400.29 -5435.64 4842.99 6008376.27 523281.05 7142.83 12.10 10608.50 81.26 34.41 6472.83 6404.83 -5402.07 4868.44 6008409.90 523306.42 7142.85 17.81 10646.50 75.90 31.57 6480.35 6412.35 -5370.85 4888.72 6008441 .17 523326.62 7140.15 15.89 10688.70 74.57 26.78 6491.11 6423.11 -5335.23 4908.61 6008476.83 523346.42 7134.49 11 .42 10721.14 73.88 25.46 6499.93 6431.93 -5307.20 4922.36 6008504.89 523360.09 7128.52 4.46 10752.91 70.94 23.04 6509.53 6441.53 -5279.60 4934.80 6008532.52 523372.46 7121.76 11.76 10786.12 68.29 21.20 6521.10 6453.10 -5250.77 4946.52 6008561.38 523384.11 7113.69 9.52 10820.79 68.59 15.80 6533.85 6465.85 -5220.20 4956.75 6008591.97 523394.26 7103.38 14.51 10853.21 68.36 12.23 6545.75 6477.75 -5190.95 4964.05 6008621.24 523401.49 7091.54 10.27 10892.42 69.68 8.67 6559.79 6491.79 -5154.95 4970.68 6008657.25 523408.04 7075.08 9.12 10924.76 70.36 3.77 6570.84 6502.84 -5124.75 4973.97 6008687.45 523411.25 7059.46 14.39 10955.70 75.24 2.69 6579.99 6511.99 -5095.25 4975.63 6008716.96 523412.84 7042.97 16.12 11001.09 80.20 0.90 6589.64 6521.64 -5050.93 4977.02 6008761.27 523414.11 7017.31 11.59 11030.41 87.45 357.66 6592.79 6524.79 -5021.81 4976.64 6008790.39 523413.67 6999.42 27.05 11061.18 92.57 358.22 6592.79 6524.79 -4991.07 4975.54 6008821.12 523412.49 6979.98 16.74 11091.17 95.25 351.39 6590.74 6522.74 -4961.29 4972.83 6008850.89 523409.71 6959.84 24.41 11125.62 93.99 347.33 6587.97 6519.97 -4927.55 4966.49 6008884.61 523403.29 6934.41 12.30 11166.31 94.14 339.20 6585.08 6517.08 -4888.72 4954.82 6008923.41 523391.51 6901.64 19.93 11200.26 92.61 332.92 6583.08 6515.08 -4857.76 4941.07 6008954.33 523377.69 6871.99 19.01 11232.95 95.01 335.84 6580.90 6512.90 -4828.35 4926.97 6008983.70 523363.52 6842.99 11.55 11265.16 96.76 337.92 6577.60 6509.60 -4798.89 4914.39 6009013.13 523350.87 6815.17 8.41 11299.49 96.36 342.08 6573.68 6505.68 -4766.85 4902.73 6009045.14 523339.13 6786.52 12.09 11340.20 93.99 351.21 6570.00 6502.00 -4727.44 4893.38 6009084.52 523329.68 6755.28 23.08 11375.59 93.07 353.08 6567.82 6499.82 -4692.46 4888.55 6009119.49 523324.77 6730.30 5.88 11410.46 89.88 355.02 6566.92 6498.92 -4657.79 4884.94 6009154.14 523321.07 6706.48 10.71 11447.32 86.84 0.17 6567.98 6499.98 -4620.99 4883.39 6009190.93 523319.43 6683.03 16.22 11485.18 89.60 1.00 6569.15 6501.15 -4583.16 4883.78 6009228.76 523319.73 6660.48 7.61 11515.32 89.42 7.40 6569.41 6501.41 -4553.12 4885.99 6009258.81 523321.86 6644.10 21.24 11552.46 87.49 8.63 6570.41 6502.41 -4516.36 4891.16 6009295.58 523326.94 6626.02 6.16 11580.38 88.53 11.07 6571.38 6503.38 -4488.87 4895.93 6009323.08 523331.65 6613.22 9.50 11612.56 86.81 14.89 6572.69 6504.69 -4457.54 4903.15 6009354.42 523338.79 6600.06 13.01 11642.32 85.40 19.17 6574.71 6506.71 -4429.16 4911.85 6009382.82 523347.41 6589.84 15.11 11677.38 85.64 21.66 6577.45 6509.45 -4396.40 4924.04 6009415.60 523359.52 6579.78 7.11 11708.65 86.17 26.71 6579.69 6511.69 -4367.96 4936.81 6009444.07 523372.22 6572.78 16.20 11745.25 87.85 32.17 6581.60 6513.60 -4336.14 4954.77 6009475.93 523390.10 6567.88 15.59 11780.09 87.45 38.99 6583.03 6515.03 -4307.85 4975.01 6009504.27 523410.27 6566.92 19.59 11813.95 87.52 42.27 6584.51 6516.51 -4282.18 4997.04 6009529.99 523432.23 6568.97 9.68 11846.00 89.72 45.16 6585.29 6517.29 -4259.03 5019.18 6009553.20 523454.31 6572.64 11.33 11882.88 87.67 50.79 6586.13 6518.13 -4234.35 5046.55 6009577.94 523481.62 6579.55 16.24 11912.40 85.52 55.04 6587.88 6519.88 -4216.59 5070.05 6009595.76 523505.08 6587.55 16.11 11948.08 84.54 55.95 6590.97 6522.97 -4196.45 5099.34 6009615.96 523534.31 6598.74 3.74 11982.28 83.85 58.48 6594.43 6526.43 -4178.03 5127.95 6009634.45 523562.87 6610.41 7.63 12014.28 85.64 60.31 6597.36 6529.36 -4161.81 5155.37 6009650.74 523590.25 6622.47 7.98 12051.75 92.92 58.77 6597.83 6529.83 -4142.83 5187.64 6009669.80 523622.47 6636.73 19.86 12081.13 92.30 57.28 6596.49 6528.49 -4127.29 5212.54 6009685.40 523647.33 6647.19 5.49 12116.67 87.48 53.10 6596.56 6528.56 -4107.01 5241.71 6009705.75 523676.44 6658.18 17.95 12147.68 86.02 52.21 6598.32 6530.32 -4088.23 5266.32 6009724.59 523701.00 6666.46 5.51 ) ') BP Baker Hughes INTEQ Survey Report ....,'......,....................... INTEQ Comp~ny: Field: Site: Well: Wellpath: Phillips Alaska, Inc. Kuparuk River Unit KRU 3N Pad 3N-18 3N~ 18L 1 PB 1 Date: . 4/29/2003 Time: 09:07:03 Page: 3 Co-ordinate(NE) Reference: Well: 3N~18, True North Vel;tical (TVD) Reference: 3N-18 RKB 68.0 Section (VS) Reference: Well (0.00N,0.00E,127.15Azi) SUI;vey Calculation Method: Minimum Curvature Db: Sybase Survey MD J nel Azim TVD ft deg deg ft 12171.33 86.62 47.04 6599.84 12227.00 86.62 47.04 6603.12 SSTVD N/S E/W MapN MapE VS DLS ft ft ft ft ft ft deg/100ft 6531.84 -4072.95 5284.29 6009739.92 523718.94 6671.55 21.96 6535.12 -4035.07 5324.96 6009777.88 523759.51 6681.09 0.00 Phillips Alaska, Inc. WELLPATH DETAILS 3N·18L 1 500292159560 Parent Wellpath: 3N-18L 1PB1 Tie on MD: 10330.00 Rig: Nordic 2 Ref. Datum: 3N-18 RKB 68.0Oft V.Sectlon Origin Origin Starting Angie +N/-S +E/-W From TVD 25.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E! Reference: Well Centre: 3N-18, True North Vertical (tvo Reference: System: Mean Sea Level Section (VS Reference: Slot - (O.OON,O.DOE) Measured Depth Reference: 3N-18 RKB 68.00 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Annotation ~-w Shape 000 -4foooo :)05000 PoÞJ'9Of1 o 00 ~2St 19 45õO 36 PdygJn 000 "')1060 4162 71 Pdy~ 6395.45 10330.00 KOP 6552.68 12133.00 TO ~H~~ Æ:f111 5850 5900 5950 ?OOO æ 6050 o &I) ~100 .c ~ aJ)150 G) Q 6200 -¡ .!:! 6250 1:: ~ 6300 26350 to- 6400 6450 6500 6550 lB.. Conoc~illips BLIII.. INTßQ LEGEND T ~~:1nNÑ!t}¡I.Pla~;;1.1 It.. M 3N-18 (3N-18L1PB1} A 3N-18L1 ' . r ! if C:.::::Üad ¡r:fGf:'Tialior:. Well path: (3N-18/3N-18l1) Azimuths to True North Magnetic North: 25.43' Magnetic Field Strength: 57491nT Dip Angle: 80.79" Date: 1123/2003 Modei: BGGM2002 Created By: Brij Potnis Date: 4/29/2003 ~. ~o ~ ~o .' .' ;....... ~\~~~ ~ ,..:"'-/ D¡r€{;t (gO?) 2fJ7 -6613 E-~n3i¡: t!:il.p.otn1;:4à?¡ntBq.r-.QfH 8a?t:er Hughes ¡NTE(J.: i9G7} 767-660D -40OO·J ....... . ... . ; IJ/ // . ..~ 0 · . · · nn . VV . ..... l~~ · .... . . · . I " · -42oo"~ . ..... · ........ . ... '. . ..... //7/ .. 1 .............. ........mm. ... · · · · · ... · .... -43oo'~ ... .... ............. m .... · .... j! (... ... ..... . ........... . ... · ... . . . j/ · '. '.. .-- · · · "TVV · 0 · · '/ /í · . · · ~ . .... · .. .m.m. ...'. . . .............. .... .. >mm........ ..... .. ....... !: ,,",vv . · f ! · · · ì ~ -4600'~ · ... .. m' . .. ... · · .. g · · · . · / . · · · . · · · ~ tlVV . · ! .. .. · .~ ... 'r ......\ · . · · .. .... ..... .. ., ... .... ... · ......... ..... .:-- .uvv !\ · . · \\. · · · · . · · 0 .:= ,~^^ " · · · · · · · . · .""vv ... .'\ ... .... .m ...... .' .'.. ........ .... ..' · ....0.............. .. · 0" ..... ; · · . · . · . · .. '. · · .' .. · · ..-...vvv N ..... .'. '. '. "m ....... '. .......... m... ..' ..... . . . · . -,^^ · · · . · · · · . -... vv .... . . ......... .... . · · '.. ..... . · · .... '\ · o . .- · · · . · . · · · ~ -.....vv m "" · ... ..... " ... · .... /! .................... .. · .... m' .... ..; .. . · · · .' . · · -..."vv "' ... ..' '" ...... m... ... .'. · ... (m.. Ill. ... . . . .. ... \. · · · . · · · · -.....vv · . " . · // I · . · : · · : · . . · . .~. /// .' · · ....... ... ........ · .... ..' ... .' · . · · ... -¡)¡)UU .. ........ ..m ~'. ~ ? ... ............. · · . · · -5600--::: . '. · · · . · ... . '\: =. .. ......... m · · ..... ... · · . · -.." vv ... .' ... -, . 'c.........\ · . . ..... · .. · · '. .... '.' . . . . . . . . ¡ · ~3·00 .. . , , . .. · ~~b'~ . .. , oon.-. ': · '5900 ôOOO : ~? ~O K!10 37 00 38 ()() 39 :>040 :>0 42'00 4700 4800 5000 51 DO 5300 55 Vertical Section at 25.00° [50ft/in] "1/29/2003 9:18 AM -' .-- I '\ I~ If ~ 1~!Ær;-p E ~ ¡ lJ. '. , U I..J' ;;:::'\ f ~~~~~~!Æ FRANK H. MURKOWSKI, GOVERNOR I ~ AItA.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer Phillips Alaska Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk River Unit 3N-18Ll Phillips Alaska Inc. Permit No: 203-019 Surface Location: 1561' NSL, 20' EWL, SEC. 28, TI3N, R09E, UM . Bottomhole Location: 2607' SNL, 5179' EWL, SEC. 33, TI3N, R09E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. 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. The permit is for a new wellbore segment of existing well 3N-18, Permit No 186-043, API 50- 029-21595. Production should continue to be reported as a function of the original API number stated above. 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 North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ -<,,/?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 7(:!- day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. vJC, A- Z-/ i./ I () "5 12. Distance to nearest property line 13. Distance to nearest well/, ADL 025630, 26731 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 100061 MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize CasinQ WeiQht Grade CouDlinQ 2-3/8" 4.6# L-80 ST-L Hole 3" ') STATE OF ALASKA ") ALASKI""\ JIL AND GAS CONSERVATION COMhfl.ðSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory D Stratigraphic Test II Development Oil D Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool ./ RKB = 68' MD Kuparuk River Field / Oil Pool 6. Property Designation ADL 025520 7. Unit or Property Name Kuparuk River Unit 8. Well Number / 3N-18L 1 9. Approximate spud date 03/01/03/ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 120001 MD / 6495' TVD o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 90 Maximum surface 3150 psig, At total depth (TVD) 6568' / 3800 psig Setting Depth TQP Rotom Quantity of Cement Lenath NlD TVD MD TVD (jncl4de staQe data) 1120' 10880' 6477' 12000' 6495' Uncemented Slotted Liner /' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work· D Drill II Redrill D Re-Entry D Deepen 2~amEfÕfõperator Phi.rr!p8"'Álaska Inc. 3. ddress P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 518422, Y = 6013800 1561' NSL, 20' EWL, SEC. 28, T13N, R09E, UM At top of productive interval x = 522756. Y = 6008238 4013' SNL, 4326' EWL, SEC. 33, T13N, R09E, UM At total depth x = 523602, Y = 6009646 26071 SNL, 5179' EWL, SEC. 33, T13N, R09E, UM Number U-630610 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10630 feet Plugs (measured) true vertical 6826 feet 'Effective depth: measured 10517 feet Junk (measured) true vertical 6746 feet Casing Length Size Cemented R E' (, ,,, [ i \./. F:;''''I\ "., [~ ~. &".", lJ J) '7 f). Dn~ i._ , [J u "~, Alaska Oil & Gas Gons. Commission Anch'MrPe TVD Structural Conductor Surface Intermediate Production Liner 115' 5144' 16" 9-5/8" 242 sx Coldset II 1500 sx AS III, 400 sx Class 'G' 115' 5144' 115' 3621' 105991 7" 400 sx Class 'G', 175 sx PF 'C' 105991 6804' Perforation depth: measured 9983' - 10001', 10179' - 10201', 10221' - 10247', 10256' - 10278', 10325' - 103291, 10333' - 103421 true vertical 63981 - 6408', 6518' - 6532', 65451 - 65621, 6567' - 6582', 66131 - 6616', 6618' - 66251 20. Attachments II Filing Fee D Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Kara, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 21. Is~;~:Y ::i~::~t O~Oi~~ correct t~the b;;:~Of~~~~~:;~g~::~~~:~::':..>:i'::'... . Date I / ~7 /03 ':. "",;,' ....... ,..... .'<. . '. .,.,.~m~~i~·QM:Ø.~.)1¡:. .:.:. ',< ,'., ':<'·"·1..···"·,.':··. ".., ".' , :;.r,.,···:·",·,,·· Permit Number API Number APproral ~~ See cover letter 2 CJ.3 - 0/ 7' 50- 029-21595-60 J '7/(J ./ for otherreQuirements Conditions of Approval: Samples Required 0 Yes rs No Mud Log Re uired 0 Yes IS No Hydrogen Sulfide Measures III Yes l"~ No Directional Survey Required RI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU OtbW-: T~~ t- Eo P¡; fc '-I~oo f~l. Ot<IGINAl SIGNED BY by order of M l. 8m Commissione~ the commission , h Approved By Form 10-401 Rev. 12-01-85 L,....., Date :Jh {; '7 SUbm'l~ Triplicate ) .1u 3N-18L1&L2 Sidetrack- Coiledlúbing Drilling Summary of Operations: Coiled tubing drilling will sidetrack KRU 3N-18 using the dynamically overbalanced coiled tubing drilling /'" (DOCTD) technique (see description below). This horizontal laterals (3N-18Ll & L2) will target Kuparuk A / sand reserves for production. The Kuparuk A Sand perforation in the existing well, 3N-18 will not be abandoned and will be open to flow post CTD. Prior to CTD arrival, service coil will isolate with cement the existing C Sand perforations in the straddle interval of 3N-18 (sundry form 10-403 submitted) and set a flow-through whipstock. The existing A Sand perforations in 3N-18 can produce past the whipstock post CTD. CTD Drill and Complete 3N-18Ll & L2 pr02ram: Planned for March 01, 2003 ,- 1. Mill 2.80" dual string window at 10012' md (10006' ELM) and 10' of openhole. /' 2. DriIl2.7"x3" bicenter hole horizontal sidetrack 3N-18Ll from window to -12000' TD targeting Kuparuk A3 sand interval. / 3. Run and drop a slotted (pre-drilled) liner from TD of 12000', up to 10880' md. 4. Openhole sidetrack at 10875' in Ll, above the 2-3/8" liner. 5. DriIl2.7"x3" bicenter hole horizontal sidetrack 3N-18L2 from open-hole side track to -11975' TD targeting Kuparuk A2 sand interval. ./ 6. Complete with 2 3/8" pre-drilled liner from the TD of L2 at 11975', up into the 3-112" tubing to -9950'. 7. Post CTD rig -Run GL V s. Bring on production. Mud Program: · Steps 1: 8.5 ppg Potassium-Formate biozan brine · Steps 2-3: Potassium-Formate based Flo-Pro (8.5 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: / · Ll: 23/8",4.6#, L-80, STL slotted liner from 10880' md - 12000' md · L2: 23/8",4.6#, L-80, STL~otted liner from 10700' md - 11975' md Solid liner from 9950' md - 10700' md. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 3N-18L 1 & L2 · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. Kara 564-5667 office, 240-8047 cell 1/3 ) ) ",Áu 3N-18L 1 &L2 Sidetrack - Coiled Tubing Drilling Hazards . Two faults are expected to be crossed, one in the B sand/shale and one in the A sand, lost circulation risk j is low. Res. pressure is estimated to be 11.1 ppg in the fault blocks. We1l3N-18 has a H2S reading of 110 ppm (measured 12/30/02). The highest H2S on 3N pad was measured at 156 ppm (3N-02, 12/31/02). 3N is an H2S pad. All H2S monitoring equipment will be operational. Reservoir Pressure /) . Res. pressure is approx. 3800 psi at 65,9-8' TVD (6500' ss)~ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 3150 psi. Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 8.5 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. 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 with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular pre venter will act as a secondary containment during deployment and not ~'. as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the production liner will be deployed into the wellbore after killing the well with kill weight fluid. Estimated reservoir pressure: 3800 psi at 6500' ss, 6568' TVD, 11.1 ppg EMW. Expected annular friction losses while circulating (ECD): 1000 psi vJ4i\ Planned mud density: 8.5 ppg equates to 2900 psi hydrostatic bottom hole pressure. ~qO(,? While circulating 8.5 ppg fluid, bottom hole circulating pressure is estimated to b~)..ge((psi, or 100 psi over- balanced to the reservoir. When circulation is stopped, a minimum of 900 psi surface pressure will be applied to balance the reservoir. Operating parameters will be adjusted based on real-time bottom hole pressure measurements while drilling. Kara 564-5667 office, 240-8047 cell 2/3 t...Ju 3N-18L1&L2 Sidetrack - Coiled TU~ng Drilling Kuparuk 3N-18Ll&L2 Potential Drilling Hazards POST ON RIG 1. Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S - We1l3N-18 produces H2S at 110 ppm (measured 12/30/02). The highest H2S on 3N pad was measured at 156 ppm (3N-02, 12/31/02). 3N is an H2S pad. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in the pit area, although KRU CTD sidetracks have not seen this in the past. The Pit watcher should always carry a calibrated personal H2S monitor. -- 3. Reservoir pressure - Reservoir. pressure is estimated at 3800 psi @ 6500'ss, 6568' TVD (11.1 ppg) in the adjacent fault blocks that will be penetrated with this well plan. Max. surface pressure with gas (0.1 psi/ft) to surface is 3150 psi. Reservoir frac gradient is -0.7 psi/ft or 13.5 EMW, 4600 psi. 4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used. Drilling will be done with a less than kill-weight fluid (8.5 ppg Flo-Pro). While drilling and circulating at 1.5 BPM, hydrostatic head from the 8.5 ppg mud (2900 psi), plus 1000 psi of annular, friction, plus 0 psi choked backpressure held on the return side will provide a 3900 psi BHP and /' overbalance the reservoir by -100 psi. However, when circulation is shut down, the reservoir could be underbalanced by -900 psi. Maintain at least 900 psi WHP when not circulating to prevent reservoir in-flux and to maintain formation stability by keeping static BHP close to circulating BHP seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return- line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event occurred), divert those returns to an outside tank. 5. No gas saturated intervals are expected. However, always be prepared for the potential for gas influx. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit volume continuously. 6. Lost circulation is not expected. Two faults are expected to be encountered along the wellbore trajectory. The faults are sealing and lost circulation is considered low risk. If lost circulation occurs plan to control it with adjustments to the DOCTD parameters. Lower circulation rate (1 BPM minimum) would be utilized prior to LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill could be mixed quickly if required. Pump only Liquid Casing or OM Seal fine through a slimhole drilling BHA. Do not pump MI Seal through a drilling BHA due to plugging potential. Kara 564-5667 office, 240-8047 cell 3/3 ) ) :SrJ'·18 L 1 L2 Proposed Completion Tally JÆlg1h Dmh .ELM X X Baker FHL 8.52' 9902' 9984' Packer 1 jt 3-1/2" tbg 31.53' 9910' 9902' Cameo GLM 6.55' 9942' ~ I I I I IL 9934' 1 jt 3-1/2" tbg 9941' 31.03' 9949' 3-1/2" Blast 30.87 9980' 9972' Joint 3-1/2" Joint 31.50' I I I 10010' 10004' ~ . IJ¡ 10042' 10035' I I 10045' 1 0038' ~ 10057' 1 0050' ~ AVA BPL 2.95' 3-1/2"PupJt 10.10 Baker FB-1 Packer 9.08' " 2-7/8" Pup Jt 6.09' 1 0066' 1 0059' Cameo 0 Nippe 2-7/8" Pup Jt 2-7/8" Tail 1 .43' 10072' 10065' 6.12' 10073' 10066' 1 0080' 10073' A-sand Perforations ~ 7400' -7448 ELM '" I I )1 I II I I / / Perfs to remain open to flow, post CTO Kara ¿, fit.. 7" 26# Shoe @ 7670' 2-3/8" Top of liner 9950' ILtP? L 2-String Window at 11 006' ELM ~ 2-3/8" Slotted liner inside 3" openhole \ \ L 1: Compete 2-3/8" liner from TO to 10880' L 1 TO 120C L2: Compete 2-3/8" liner from TO to QQc;n' L2 TO 1197 SSSV (1801-1802, OD:3.500) PBR 1IIIIIIIIIIIllllllilf 1~·llllli (9888-9889, OD:3.500) PKR (9902-9903, OD:6.151) / Perf (9983-10001) SLEEVE-O (10042-10043, OD:2.310) PKR (10057-10058, OD:6.151) NIP (10072-10073, OD:2.875) :.~ :r: Perf (10179-10201 ) Perf (10256-10278) Perf (10325-10329) Perf (10333-10342) API: 500292159500 SSSV Type: TRDP Well Type: PROD Orig 6/4/1986 Completion: Last W/O: Annular Fluid: Reference Log: Last Tag: 10170 Last Tag Date: 7/7/2002 Casing String - CASINGS - ALL Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String - TUBING Size Top 3.500 0 2.875 10067 Peñorations Summary Interval TVD 9983 - 10001 6398 - 6408 ) KRU 3N-18 Angle (â>. TS: 54 deg @ 9909 Angle @ TD: 45 deg @ 10630 Ref Log Date: TD: 10630 ftKB Max Hole Angle: 59 deg @ 2300 Rev Reason: Drift & Tag, set OV bylmO Last Update: 7/8/2002 Top Bottom TVD Wt Grade Thread 0 116 116 62.50 H-40 0 5144 3621 36.00 J-55 0 10599 6804 26.00 J-55 TVD Wt Grade Thread 6448 9.20 J-55 8RD EUE ABM 6456 6.50 J-55 8RD ABM Status Ft SPF Date Type Comment 18 12 7/21/1986 IPERF 4" Jumbo Jet II, 120 deg ph 10179-10197 6518-6529 10197 - 10197 6529 - 6529 10197 - 10199 6529 - 6530 10199 -10199 6530 - 6530 10199 -10201 6530 - 6532 10201 - 10201 6532 - 6532 10221-10241 6545·6558 10241-10241 6558-6558 10241 - 10243 6558 - 6559 10243 - 10243 6559 - 6559 10243 - 10245 6559 - 6560 10245 - 10245 6560 - 6560 10245 - 10246 6560 - 6561 10247 - 10247 6562 - 6562 10256 - 10278 6567 - 6582 10325-10329 6613-6616 10333 - 10342 6618 - 6625 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2749 2269 Cameo KBUG 2 5546 3849 Cameo KBUG 3 7296 4862 Cameo KBUG 4 8333 5455 Cameo KBUG 5 8871 5764 Cameo KBUG 6 9369 6044 Cameo KBUG 7 9841 6315 Merla TPDX Production MandrelsNalves St MD TVD Man Man Mfr Type 8 9942 6374 KBUG Other Vlugs, equip., etc.' - JEWELRY Depth TVD Type 1801 1711 SSSV 9888 6342 PBR 9902 6350 PKR 10042 6433 SLEEVE-O 10042 6433 NIP 10057 6442 PKR 10072 6451 NIP 10079 6456 SOS 10080 6456 TTL General Notes Date Note 10/9/1998 LOST RUNNING TOOL CORE IN TBG. 3/6/2002 E-LlNE CALIPERS INDICATE GAUGE PROBLEM AT TBG COLLARS - POSSIBLE CORKSCREW OR BALLOONED TBG ?? 7/7/2002 DRIFTED TBG W/25.6' X 2.7' WEATHERFORD WHIPSTOCK DMY DRIFT TO 10042 RKB; NO PROBLEMS Bottom 10067 10080 Zone C-1,UNIT B A-3 A-3 A-3 A-3 A-3 A-3 A-2 A-2 A-2 A-2 A-2 , A-2 A-2 A-2 A-2 A-1 A-1 VMfr VMfr Cameo'TRDP-1A-SSA' Baker Baker 'FHL' AVA; BPC SLEEVE set 8/8/99. AVA PORTED NIP Baker'FB-1' Cameo 'D' Nipple NO GO Brown 18 o 2 o 2 o 20 o 2 o 2 o 1 o 22 4 9 8 1/6/1989 9 1/6/1989 8 1/6/1989 9 1/6/1989 8 1/6/1989 1 7/21/1986 8 1/6/1989 9 1/6/1989 8 1/6/1989 9 1/6/1989 8 1/6/1989 9 1/6/1989 8 1/6/1989 1 7/21/1986 1 7/21/1986 4 7/21/1986 4 7/21/1986 RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 2 1/8" EnerJet, 60 deg. ph IPERF 4" Jumbo Jet II, 120 deg ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph RPERF 2 1/8" EnerJet, 60 deg. ph RPERF 21/8" EnerJet, 60 deg. ph IPERF 4" Jumbo Jet II, 120 deg ph IPERF 4" Jumbo Jet II, 120 deg ph IPERF 4" Jumbo Jet II, 120 deg ph IPERF 4" Jumbo Jet II, 120 deg ph. V Type V OD Latch Port TRO Date Run 1371 8/7/1999 1360 3/22/1998 o 3/15/1998 1381 3/22/1998 o 7/22/1986 o 3/15/1998 o 7/7/2002 Vlv Cmnt GLV GLV DMY GLV DMY DMY OV BK BK BK BK BK BK RM 0.125 0.156 0.000 0.188 0.000 0.000 0.156 1.0 1.0 1.0 1.0 1.0 1.0 1.5 V Type V OD Latch Port TRO DMY BTM Date Vlv Run Cmnt o 10/17/1998 Closed 1.0 0.000 Description ID 2.810 3.000 3.000 2.300 2.750 2.992 2.250 2.441 2.441 WliLLPATH aTAlLS '''.~.1 ~H·111.1 _.211..10 ,._W~I JIM, TIe .. M02 1??oo"- IU. 110'. D._ J....,. IIK8 ....Oft V--= ~'It: ~~ :~ 2'.-0· .... 0.00 .- REFERENCE INFORMATION Co-ordinate (NIE Reference: Well Centre: 3N-18, True North Vertical (TVO Reference: s¡:em: Mean Sea Level M~~h~==: ~1-8~,O'~60 Calculation Method: Minmum Curvature IKTlOIiI Dn..... See _ 1M Ad 1YD +NJ.a +&J.II eul TFace vaec T.,...t .. 1??oo.00 a.U U...2 u.ae.... ........... a.u.U G.DG 0..00 ..JU7... 2 toooa.oa a.SI ua.aa u.a.a .......4 a...u ..J1! ..at.M ..uae..a2 ~ ~ml-= :::= t:t.u =1: :=:n ===~= == :=:= · 1OU". 10.00 K.OO a"'.10 ~ ..22.AO 12.00 21'0.00 .zu7.... · 10ftG.27 70.00 11..00 .....U ·unAI .21.71 12,00 20"1" ·2'117.71 7 U77'72.... 7D.OD 10.00 ....... ........0 .....a '''00 2M.U ........ · tOH&.... ".M 7.00 .......20 ....... ....» 12.00 us,U ·251J...21' · 1'2~" ...IO:au.oo ....,..H ......A. --.08 12.00 211.... -22N.01 10 tt.IO.M M.IO a.oo 104e1A7 ~tt ....oe 12.00 _23 ·te..s.t t1 ttlfl.ei..... JO.oo -..et.M .......t7 ..-r.B 11.00 _01 .""'.n 12 ......., ".10 10.00 .......I-t ...aft,..1 eon-aT 12.00 ..oe ·1727.57' u neoo.oo...tt ø.oJ .....OJ ~,...... .117.n 12.00..... ....S82AI Plan: Plan #1.1 (3N-1BlPlan#1.1 3N-18L Created By: Brij Potnis Dale: 112: Contact Information: Direct: (907) 267-6613 E-mail: brij.potnis@ínteq.com Baker Hughes INTEG: (907) 267-ß600 Azimuths to True North Magnetic North: 25.43° Magnetic Field Strength: 57491nT Dip Angle: 80.79° Date: 1/2312003 Mcxlel: BGGM2oo2 T ^M I é LEGEND 3N-18 (3N-18) PIan#1.1 3N-18 Plan #1-1 ~ ~ "'-, " .- .- " ~ ~ .~.#., .&> Inc. (PlfIWPS'~- ... Mil. r¡r¡J...... ~ h'ITEQ .. - Î Phillips Alaska, ~ ----- ----- 6100 6200 6300 6400 6500 -.- -~ 3900 4000 5700 5800 5900 6000 -- 3N-18 (3N-18) ~ ===~-- _:-_~~=--===----- 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 West(-)/East(+) [100ft/in] -4100 -4200 -~- - -4300 ::-. _~_ -4400 -4500 -.--- - I: -4600 ~ -4700 o 'P- _ -4800 ----.--_=___ t:-4900 .c 1:: o -5000 ~ "i'-51 00- - .c '5 -5200 o U) -5300- -5700- -5800 -=- -=- T~DET"'LS TW .-NI-S tÐW ~ Hono / / I /// / / ! ;' / .' AHNOTATlDN. TVD liD AaIlOIllIIoa .n.... "_.00 TIP 'UJAa 1__ KO' .UI'" 11121... J .UM' ,.u.... . 'U7.1' ,..u.e. . _,.201 1'71'.27 . _... 1.772..1 7 .....zo ,._... . "'7'" 1t1n'" . ...,..17,11141.201 10 ...1... I1nl.411 11 ...J.J1 11.....7 12 """J 12_'" TD ----. PIan"1.13N-18L1i 'TDl ------ ,Œ-; ,;£ ) l';'ri.J ~ c~~:~ 5900 5950 6000 -W50 I: ~ 6100 1!!.6150 .s: ;, 6200 · a 6250 ß 6300 1:: · 6350 > · 6400 e t- 6450 6500 -- ---- - 6550 6600 12-J2M- ----- -- -. ----- -3350 -3300 -3250 -3200 -3150 -3100 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1950 -1900 -1850 -1800 -1750 -1700 -1650 -1600 -1550 -1500 -1450 Vertical Section at 25.00° [50ft/in] -1 1/23/2003 ----- ,:}~18~1!I: ) ) ri·· .... IN':'[ EQ BP Baker Hughes INTEQ Planning Report . .. ,......~.. ~.__._......._.,-,_.~¥.._.....-....-..,--_._.._--_..,._,._..-...".-,-......-..-..".".,. .."_.._"__..____',_.,,._."...~.__.~__...._'_."."_."h_.._..~.___._.._'__..,._.._.._:'..-.,-'-,_......._.~__'._."___._.'._'--.._.....,__,'_.__~___"_...._._". ...___n___....__.._,~....w_,"_.,,___.__..,._...____.,_ . C~mpany: PhiU¡ps~la$kå.lnc. DI1~:> 1123/20Ó3 ..i1irne:'1'6:13:Q4 ....... .... ..... .....,. .... .,. ... ....... · ,Flèld: Kop~ruk8iyer Unit Ço~rdlnate(N:a¡;lJlefer~nçe: VV~II:3\J~1 ß..Trufj..North, Site: KRlJ3N,pad 'V~r~ica' (TVD)Jl~fe~.nee: ...Systern:MeanSe~ LfJvel Well: 3N,;t8 See~ion(V~)Re(e~nc~: ......... ·'WfJlI(9,90N.O~90E.25.00Azi) ,....' Wellpat~:Plan#tt3N-18L1 .......... ..' ........ .. ....... ... .SurveyÇalcu~atioJ1M~tbod:Minil"l1~rnCurvatu~fJ > .... Db:Sxb~se .. . :. c _'.. :co ::::.,c.,c. _",-.:2C:::::::.=_~C.::::::::-~ ::~..~.:::::c :.::::::=_-::-.::=:.::.=:.:=.:.~' ::::':.:::.::'::':,:.: :.;_: :.":..::·::_:.::"::::::::':::..::'::'::.:·.":.~:.:.::.C:::.::::. ::::::::.:.'.='.:.:: :'::::__.:::=:::.::C.::::'::::.:.: ::::::::::::::.:_:::: ::::.:.:':::":::",-~:::.:'..:::'.::::::::=:~-:::.::::::: ::.::..:::::.::..:'.:=.=-.:: ':;:.:.=:::.::::-.::..:.' :.:: '" ..:~.:::"..-:: ::::::o:c_::¡.. Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: -,._,~..~.....".....,..- - -" -..-. -,.........,.--.......--...-.--.-".---.....".. -,,_.-..........- ..."..,,---,....__..,......_'....,. '... Alaska I Zone 4 Well Centre BGGM2002 .._"·..'___......__·u....._..._ .',.. ."__..,, .._____~......_..."...~,.._._____,_. ,.." ,.~._,_.._. .. - ____.n.""··· , .._.. _ "_"."__.'__."" _.._.,~....,,,,,_,.,,___,,..__ _"..".__,_.._.___",._....,_., .......,_. _ '._...~_" _'" ,_ _,._._._,',_."....,,",,·,.._.·,..~...___·...n_. ..~,_..._". ._."_ _.. ~ . __..__.", ...,... _ .,_ . . m ..,_ .", _"....". ,_"'_'_"'__~" _...._,'.__.. ___.......~,,_...._,__.._ .._,. Site: KRU 3N Pad UNITED STATES - North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013799.38 ft Latitude: 70 26 55.947 N 518425.12 ft Longitude: 149 50 58.873 W North Reference: True Grid Convergence: 0.14 deg ._.""_....,~_,, .___.._...~.... 'C.""""'_'"'' . ._,_ __.....",._ '...~~,.. .__...__ .,_. ,_, ,....._.... ... ,~...., ........_ .__.__,__._._.__,_...___..._._.___._.~_.._.__._' H.____. _...._~,___.. - .,.... -"..",...",,-.",-.. . ~,_ _.,...... ......._' ~""'H ..._ . "' .." ..,...._.,....,. _...," '.'h .._ . _,.'. Well: 3N-18 Slot Name: Well Position: 0.00 ft Northing: 6013799.38 ft Latitude: 0.00 ft Easting: 518425.12 ft Longitude: 0.00 ft +N/-S +E/-W Position Well path: Plan#1.1 3N-18L1 500292159560 Current Datum: 3N-18 RKB Magnetic Data: 1/2312003 Field Strength: 57491 nT Vertical Section: Depth From (TVD) ft 0.00 Height 68.00 ft Drilled From: Tie..on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 _u..__ _,..,_,________n__. n_ 70 26 55.947 N 149 50 58.873 W 3N-18 10000.00 ft Mean Sea Level 25.43 deg 80.79 deg Direction 25.00 ..'. ,._. . '_'_"_..u.._ ,,""'__, n__' ,,,__,,,,_,"'_.'...___._.. ...,_"."._,_..__"._,~,_~___ ~. __··__"·_'_·n"'···~· ~"'_.._ ~_~~___..____,.."'__..~_....___. ___.._ ..'.~._..~.'-"".... ." .-..,,,.-...,-.--,..-,-.,". .,._., ._ ._."...,"..~h."".._ ,.....___ Targets Name ...._~., .... n "¥". '_".".~'~'~'_"'"'' _._ ~_"'¥_.,_' .".___'" .,_,",_,_..,._......~,,,.....__.~..~~,.....-:_... ....,,___...._. ",~.__........ . __.__,.....~ "..._.__..~:-..'".".,.._.......·___.__......,'_'_.~_..~__~I~.....____~",..".~..:".-:..."--'.,....,'P..,-"'~_._,,..~...".,--.,...~-...-..'7-:._"._~'___....,~ __~_-;'_".._........__._:'"..".._'_":"__".~.~"R_..":"....,..."__..".,,~_'":""~' '--- , ........... .. M~p,Map, '.., ~."7'~.J;;adt~de---> ....·.~:-.·~p..gi~ud~~--> Des~ripti6n TVD +Nl.~ +El.W Northilig· £asting DegMhl.·. S~c peg· Min Sec . .._.R___,....'_._._c._~~!P~:-".~...._.~_..",..,,';...~,~~"·....u,....._'...~,.... :::.: ',:, ,",:''-",:': ",:' ,', ",' :,' __:-:::_~::~-:~:.._".~~.~:.~::~:.::::~~:~~~~..::_".::":._~_-._...,---..---.....c.--.'::.:..~~._:~~..::~..:_--:..=....~~-.~..:.:::-.:.--:.--_.:-.~:-.-._=....-.:.......:....=.:=-~.:-.:=__..~=·.:-=····:-:---·:1 ....,.~..~"-"",, ,..,:'-- "....~..,".".._- .... ..., .~_. '~_"'~.'."'__'''~'' ".,_.d~.-'-_ 10000.00 6339.84 TIP 10006.00 6343.42 KOP 10021.00 6351.88 3 10174.69 6397.10 4 10524.69 6397.10 5 10710.27 6429.24 6 10772.91 6450.69 7 10966.94 6485.20 8 11233.59 6487.59 9 11650.24 6491.47 10 11691.91 6491.84 11 11858.57 6493.31 12 12000.00 6495.03 TD - -- - .-- ."'-.- -"--' ----.-- ------.. ._-._~ ..--~ -- Pian: Plan #1.1 Similar to 3N-18A Version #4 Principal: Yes . ...-....-- - -.--. . .- ---.. ._.--."-,_._-,,--~.----,,,.-.---.- ~--,----------- Date Composed: Version: Tied-to: Plan Section Information 1123/2003 1 From: Definitive Path ., __,_.' .____.______ ·___"h_ .,____ .___ __._ ____._5.5._._______.____._____.__..__ ________ - ____.._____.______-. -----.------.--- ----.-.---.--- -' -------.----.- --.------- -.-.-----.-- - - -.- Target MD Incl Azim TVD +Nl·S +EI-W DLS Build Turn TFO ,__.__ __ ~__. _____ __ __~~.__.___._~~__.___._ __ _.___~. _.___.n ._____~__________ ~_____.____~~~~0E!t __ ~~~.~~~_~~!.~~~____ _~~___ I 10000.00 53.43 138.82 6339.84 -5616.51 4383.18 0.00 0.00 0.00 0.00 10006.00 53.35 138.80 6343.42 -5620.14 4386.35 1.36 -1.33 -0.33 191.34 10021.00 57.94 135.71 6351.88 -5629.22 4394.76 35.00 30.58 -20.63 -30.00 10174.69 90.00 80.00 6397.10 -5666.10 4529.06 40.00 20.86 -36.24 289.90 ----.---.,---,-- .- ..-- ._-----. ~ _, _._,_n._ _._.__..._.' .__ _,__.._ .._____". .____, ..___~._ ) ) ... .....~ ~.-.,.__..,~.,-~,-, ,.._.~.- --....-- INI EQ BP Baker Hughes INTEQ Planning Report .. . "~'"":,"..,;,,,,~,.uì'·in'.'~"ri~'~::-'-:'~""_"'_~'''''-:-''''_~~;-_'''':''''___~"'~"""--"-"':""""-'--~"'-"'''''--:-~'''----:'~''':~-~'-:----~'''''-~'~~'.~'--"~":'--:""''''7'''"''''''''-'''~''"':'~'~~'I';'''--,-;-'''''''''''''~-'-,:,",.-,..··,··:.......-~"""!'·_~-::_..":7~-ï,..··...~-""';'·I-·---'''"',.'''T':'''-·.·~·,.·-.---;--.-_.~.':"'~.-:-..,-,_."--~:':"'._,.__._-'."..-:-:'--...,_._....".-'l C()mpany: PhiIliÞs~laska,'ll'\c. 'Da~:,<112~/2oo3, ."TilDe:·.:..16,:13:04 ,i .......................¡.¡ ~åge: 2 Fiéld: KuÞaruk,~iverlJnit, ç~~~~iß~te(N~)~~fere~~~: . VV~II:.3~-18, JruEi Nortry ,. 'Si~e: .K~Ll3r,J'.~a~ y¢r.t~c~I:~Yp>.:Refer~l~ce: ,.. ',~yst~rrI:.tv1e~~Sea.Level. . Well: ,3N-18i S~tiè)~(VS)Refer~nc~:·.' ... ... ,'·WEtIl (Q.O()N,O..()O~,~§.IOOAzi)'. ....... . .. ....... ' ".~~!~.~~!~.~_.. E~~~~~.:.1~~~;~_1~~~.._..__."c..__......_.."....,."_-2_._-';..~_-c~~_~~~__"_C".___~Ury~!£~l~c~~t!!.~~etb~~!_~__~}~~T~~~~£~~~U.f!_______1?~.:__~~~~~~..·...__...... Plan Sedion Information I·:··:··:'··:······:·:·:··--·····--~··:::-_·C"··.::··::;-:··ë-__:.·:-'''':·"·-·:·:-:-·~-·:·- :--·"-''':--··-~·'-''''''::-::-::-:-·--···::-.-:-~-::~'--:--'·-::-C''''---·-··-- ...:-..._._._.__._h._-:-.___.,--.__--:-.._,..____~...-.-.__,_-..--.-_:_.--,--:----,-. .....-.--..-..-..-.--.~- --...,.. MD :..lgCJAzirn.I1VD . ' . i+N'/-S'+IU-WDLS Build .. . Turn .TFO T~rget . ............ ...._f}~._._......,.___".~~~__..___ _~.'-c._1'~~~ .-~~._~L._~~...~~_~:.:.~~.~_.1!..L.2."~___.._.~~~_._.~._._~~~~~.~~~1B~.~!~~~~g2~'_~,!~t~~L._.~~~~~_...;.~_;~·..._,_.;-2_..~._.....L___..__..__. 10524.69 90.00 38.00 6397.10 -5489.84 4822.40 12.00 0.00 -12.00 270.00 10710.27 70.00 28.00 6429.24 -5337.82 4921.71 12.00 -10.78 -5.39 205.51 10772.91 70.00 20.00 6450.69 -5284.10 4945.62 12.00 0.00 -12.77 268.63 10966.94 89.50 7.00 6485.20 -5099.60 4989.23 12.00 10.05 -6.70 325.32 11233.59 89.50 335.00 6487.59 -4839.65 4948.06 12.00 0.00 -12.00 269.86 11650.24 89.50 25.00 6491.47 -4436.11 4948.06 12.00 0.00 12.00 90.23 11691.91 89.50 30.00 6491.84 -4399.17 4967.29 12.00 0.00 12.00 90.02 11858.57 89.50 50.00 6493.31 -4272.15 5073.87 12.00 0.00 12.00 90.09 12000.00 89.11 33.03 6495.03 -4166.64 12.00 -0.28 -12.00 268.59 10000.00 53.43 138.82 6339.84 -5616.51 4383.18 6008194.28 522821.73 -3237.88 0.00 0.00 TIP 10006.00 53.35 138.80 6343.42 -5620.14 4386.35 6008190.66 522824.91 -3239.82 1.36 191.34 KOP 10021.00 57.94 135.71 6351.88 -5629.22 4394.76 6008181.60 522833.34 -3244.50 35.00 330.00 3 10025.00 58.49 133.94 6353.99 -5631.61 4397.17 6008179.21 522835.76 -3245.65 40.00 289.90 MWD 10050.00 62.48 123.40 6366.33 -5645.15 4414.14 6008165.72 522852.77 -3250.74 40.00 290.83 MWD 10075.00 67.21 113.65 6376.97 -5655.90 4434.01 6008155.02 522872.65 -3252.09 40.00 296.04 MWD 10100.00 72.48 104.60 6385.60 -5663.55 4456.15 6008147.43 522894.82 -3249.66 40.00 300.19 MWD 10125.00 78.15 96.07 6391.94 -5667.86 4479.92 6008143.18 522918.59 -3243.53 40.00 303.32 MWD 10150.00 84.05 87.90 6395.82 -5668.70 4504.57 6008142.40 522943.24 -3233.87 40.00 305.49 MWD 10174.69 90.00 80.00 6397.10 -5666.10 4529.06 6008145.06 522967.72 -3221.17 40.00 306.76 4 10175.00 90.00 79.96 6397.10 -5666.04 4529.36 6008145.12 522968.02 -3220.99 12.23 271.29 MWD 10200.00 90.00 76.96 6397.10 -5661.04 4553.85 6008150.18 522992.50 -3206.11 12.00 270.00 MWD 10225.00 90.00 73.96 6397.10 -5654.77 4578.05 6008156.51 523016.68 -3190.19 12.00 270.00 MWD 10250.00 90.00 70.96 6397.10 -5647.24 4601.88 6008164.10 523040.49 -3173.29 12.00 270.00 MWD 10275.00 90.00 67.96 6397.10 -5638.4 7 4625.29 6008172.93 523063.88 -3155.45 12.00 270.00 MWD 10300.00 90.00 64.96 6397.10 -5628.49 4648.21 6008182.96 523086.77 -3136.72 12.00 270.00 MWD 10325.00 90.00 61.96 6397.10 -5617.32 4670.57 6008194.19 523109.10 -3117.15 12.00 270.00 MWD 10350.00 90.00 58.96 6397.10 -5604.99 4692.32 6008206.56 523130.82 -3096.79 12.00 270.00 MWD 10375.00 90.00 55.96 6397.10 -5591.55 4713.40 6008220.06 523151.86 -3075.70 12.00 270.00 MWD 10400.00 90.00 52.96 6397.10 -5577.02 4733.74 6008234.63 523172.16 -3053.93 12.00 270.00 MWD 10425.00 90.00 49.96 6397.10 -5561.45 4753.29 6008250.25 523191.67 -3031.56 12.00 270.00 MWD 10450.00 90.00 46.96 6397.10 -5544.87 4772.00 6008266.87 523210.34 -3008.62 12.00 270.00 MWD 10475.00 90.00 43.96 6397.10 -5527.34 4789.82 6008284.45 523228.11 -2985.21 12.00 270.00 MWD 10500.00 90.00 40.96 6397.10 -5508.90 4806.70 6008302.93 523244.94 -2961.36 12.00 270.00 MWD 10524.69 90.00 38.00 6397.10 -5489.84 4822.39 6008322.02 523260.59 -2937.46 12.00 270.00 5 10525.00 89.97 37.98 6397.10 -5489.60 4822.58 6008322.27 523260.78 -2937.16 11.92 206.10 MWD 10550.00 87.26 36.69 6397.70 -5469.73 4837.74 6008342.17 523275.89 -2912.74 12.00 205.51 MWD 10575.00 84.55 35.39 6399.49 -5449.57 4852.41 6008362.36 523290.50 -2888.27 12.00 205.54 MWD 10600.00 81.85 34.08 6402.45 -5429.17 4866.56 6008382.79 523304.60 -2863.81 12.00 205.63 MWD 10625.00 79.15 32.75 6406.57 -5408.60 4880.13 6008403.40 523318.12 -2839.42 12.00 205.78 MWD 10650.00 76.46 31.40 6411.85 -5387.89 4893.11 6008424.13 523331.05 -2815.17 12.00 206.00 MWD 10675.00 73.77 30.02 6418.28 -5367.12 4905.45 6008444.93 523343.33 -2791.13 12.00 206.29 MWD 10700.00 71.10 28.60 6425.82 -5346.34 4917.12 6008465.74 523354.95 -2767.37 12.00 206.65 MWD 10710.27 70.00 28.00 6429.24 -5337.82 4921.71 6008474.27 523359.52 -2757.71 12.00 207.07 6 10725.00 69.97 26.12 6434.28 -5325.49 4928.00 6008486.61 523365.78 -2743.87 12.00 268.63 MWD 10750.00 69.96 22.93 6442.85 -5304.13 4937.75 6008508.00 523375.48 -2720.39 12.00 269.27 MWD 10772.91 70.00 20.00 6450.69 -5284.10 4945.62 6008528.05 523383.30 -2698.91 12.00 270.37 7 10775.00 70.21 19.85 6451.41 -5282.25 4946.30 6008529.90 523383.97 -2696.95 12.00 325.32 MWD 10800.00 72.68 18.06 6459.36 -5259.84 4953.99 6008552.33 523391.60 -2673.39 12.00 325.37 MWD 10825.00 75.18 16.32 6466.28 -5236.89 4961.09 6008575.29 523398.65 -2649.59 12.00 325.94 MWD 10850.00 77.68 14.63 6472.15 -5213.47 4967.57 6008598.72 523405.07 -2625.62 12.00 326.42 MWD _. _., _.. .....___.___. _0__- _ _ '\ J BP Baker Hughes INTEQ Planning Report « ÎN"[a,Q 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C~mpany: PhilliP$"Ala~~å,lnc. J)ate:,1/23/20g3..··...·.·...·'·.··.i.Jime:,16.:13:04. P~ge:, 3·.. FJeld:... ' KUþaru~RiyerUOit ÇQ-:ord~atl!(~~J RefeJ;~nce: .... ' '\IV~II:,3N..1å,JrUe~~rth ..... Site: KRU3NPad '.' , Vertical (T~) Reference: ~ys~~rh:Meå"l$~élJ.:evél Well:'. 3N"18 S"tion(VS)ReCerence: Wèll(Q.OON,0.OOf;,'25.00Azi), .. ~!~IR~_~_~_:..~__~~~~!~.;1:.!~:~.~~~____~c~,.~__:..._.._.~..'-___:..:~._."_:_.~_.___~'-_.,~.L...._.~_!~~~£~~~I!:.t!~~~!.!~~!!:_~.:.._~t~~.~~~~_2~!}'.~.t_~r!_._~,____.~~~.~.._§~P!:~~ __.. .~..". Survey w_~_·":'····"__"_·_·~'~··_····T.....'_·"··.__·,·.._._....'..'~..._._".~.._..._~".....~,__.__..._.__,,___._,__,....._..,....,___ ._ _'_'_~__'_'~___'_'__'_'._~'~"___'_'_'__"__"""__'-"'-_._ MD J¡Içl Azlln SSTVI) N/S JirW MåpN l\fap)i: VS .. DLS 'TFO Tool ..______:..~.._.~.___.._.~~~__..._....c_..:_~_~~...~__.::.,......___:~.~___...."......~_,._.~...:.:_._~--'__..._... ."..~.:._..;..--'.:.c,.,,_.;..,_:~...,.__,..;~.:.",.....:.__'~~...:.L.,....-'c;.:..,_:...~_.~.~:_.._...._}..:~~~.~~~_.:__.....:~.~~___._:;c_..;......_..._. ..c..... 10875.00 80.20 12.96 6476.94 -5189.65 4973.42 6008622.56 523410.86 -2601.56 12.00 326.81 MWD 10900.00 82.72 11.32 6480.66 -5165.48 4978.62 6008646.74 523415.99 -2577.46 12.00 327.13 MWD 10925.00 85.25 9.70 6483.28 -5141.04 4983.15 6008671.19 523420.47 -2553.39 12.00 327.38 MWD 10950.00 87.78 8.09 6484.80 -5116.39 4987.01 6008695.85 523424.26 -2529.42 12.00 327.55 MWD 10966.94 10975.00 11000.00 11025.00 11050.00 11075.00 11100.00 11125.00 11150.00 11175.00 11200.00 11225.00 11233.59 11250.00 11275.00 11300.00 11325.00 11350.00 11375.00 11400.00 11425.00 11450.00 11475.00 11500.00 11525.00 11550.00 11575.00 11600.00 11625.00 11650.00 11650.24 11675.00 11691.91 11700.00 11725.00 11750.00 11775.00 11800.00 11825.00 11850.00 11858.57 11875.00 11900.00 11925.00 11950.00 11975.00 12000.00 89.50 89.50 89.49 89.49 89.48 89.48 89.48 89.48 89.48 89.49 89.49 89.50 89.50 89.49 89.48 89.47 89.46 89.46 89.45 89.45 89.45 89.45 89.45 89.45 89.46 89.46 89.47 89.48 89.49 89.50 89.50 89.50 89.50 89.50 89.50 89.49 89.49 89.49 89.50 89.50 89.50 89.45 89.38 89.31 89.24 89.17 89.11 7.00 6.03 3.03 0.03 357.03 354.03 351.03 348.03 345.03 342.03 339.03 336.03 335.00 336.97 339.97 342.97 345.97 348.97 351.97 354.97 357.97 0.97 3.97 6.97 9.97 12.97 15.97 18.97 21.97 24.97 25.00 27.97 30.00 30.97 33.97 36.97 39.97 42.97 45.97 48.97 50.00 48.03 45.03 42.03 39.03 36.03 33.03 6485.20 6485.27 6485.49 6485.71 6485.94 6486.16 6486.39 6486.62 6486.84 6487.07 6487.29 6487.51 6487.59 6487.73 6487.96 6488.18 6488.42 6488.65 6488.89 6489.13 6489.37 6489.61 6489.85 6490.09 6490.33 6490.56 6490.79 6491.02 6491.25 6491.47 6491.47 6491.69 6491.84 6491.91 6492.13 6492.35 6492.57 6492.79 6493.01 6493.23 6493.31 6493.46 6493.71 6494.00 6494.31 6494.66 6495.03 -5099.60 -5091.59 -5066.67 -5041.68 -5016.70 -4991.78 -4966.99 -4942.41 -4918.10 -4894.13 -4870.57 -4847.47 -4839.65 -4824.66 -4801.41 -4777.71 -4753.63 -4729.23 -4704.58 -4679.74 -4654.79 -4629.80 -4604.83 -4579.94 -4555.22 -4530.72 -4506.52 -4482.68 -4459.26 -4436.33 -4436.11 -4413.96 -4399.17 -4392.19 -4371.11 -4350.75 -4331.18 -4312.45 -4294.61 -4277.72 -4272.15 -4261.37 -4244.18 -4226.05 -4207.06 -4187.23 -4166.64 4989.23 4990.14 4992.12 4992.79 4992.15 4990.20 4986.95 4982.41 4976.59 4969.50 4961.17 4951.62 4948.06 4941.38 4932.21 4924.26 4917.57 4912.15 4908.01 4905.16 4903.63 4903.39 4904.47 4906.85 4910.54 4915.51 4921.75 4929.26 4938.00 4947.95 4948.06 4959.10 4967.29 4971.39 4984.81 4999.32 5014.87 5031.42 5048.93 5067.35 5073.87 5086.27 5104.41 5121.63 5137.87 5153.09 5167.26 6008712.64 6008720.65 6008745.57 6008770.55 6008795.54 6008820.45 6008845.22 6008869.79 6008894.08 6008918.03 6008941.58 6008964.65 6008972.46 6008987.43 6009010.65 6009034.33 6009058.40 6009082.78 6009107.42 6009132.24 6009157.19 6009182.18 6009207.15 6009232.04 6009256.77 6009281.27 6009305.49 6009329.35 6009352.79 6009375.74 6009375.95 6009398.14 6009412.95 6009419.93 6009441.05 6009461.44 6009481.04 6009499.81 6009517.69 6009534.63 6009540.21 6009551.02 6009568.26 6009586.42 6009605.46 6009625.31 6009645.94 523426.44 523427.34 523429.25 523429.86 523429.16 523427.15 523423.84 523419.24 523413.36 523406.21 523397.82 523388.21 523384.63 523377.92 523368.69 523360.69 523353.94 523348.45 523344.25 523341.35 523339.75 523339.46 523340.47 523342.79 523346.41 523351.32 523357.51 523364.95 523373.63 523383.53 523383.63 523394.62 523402.77 523406.86 523420.23 523434.68 523450.18 523466.69 523484.15 523502.53 523509.03 523521.40 523539.50 523556.67 523572.86 523588.04 523602.15 -.-..,-.,"--- ._._---~."._,_.,.._-- ------- -_._---_._-----_.--_.~---- -2513.27 -2505.62 -2482.20 -2459.27 -2436.90 -2415.14 -2394.05 -2373.69 -2354.12 -2335.39 -2317.55 -2300.65 -2295.07 -2284.31 -2267.11 -2248.99 -2229.99 -2210.17 -2189.58 -2168.27 -2146.31 -2123.76 -2100.67 -2077.11 -2053.15 -2028.85 -2004.27 -1979.49 -1954.57 -1929.59 -1929.35 -1904.60 -1887.73 -1879.68 -1854.89 -1830.31 -1806.01 -1782.03 -1758.47 -1735.37 -1727.57 -1712.56 -1689.31 -1665.61 -1641.53 -1617.13 -1592.48 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 327.65 8 269.86 MWD 269.87 MWD 269.89 MWD 269.92 MWD 269.95 MWD 269.97 MWD 270.00 MWD 270.03 MWD 270.05 MWD 270.08 MWD 270.11 MWD 270.13 9 90.23 MWD 90.22 MWD 90.19 MWD 90.16 MWD 90.13 MWD 90.11 MWD 90.08 MWD 90.05 MWD 90.02 MWD 89.99 MWD 89.96 MWD 89.93 MWD 89.90 MWD 89.88 MWD 89.85 MWD 89.82 MWD 89.79 MWD 89.77 10 90.02 MWD 90.00 11 90.09 MWD 90.08 MWD 90.05 MWD 90.03 MWD 90.00 MWD 89.97 MWD 89.95 MWD 89.92 12 268.59 MWD 268.61 MWD 268.64 MWD 268.67 MWD 268.71 MWD 268.75 TD \ l BOP-Tree f .) . Rig Floor KB Elevation I Well I, I Lubricator ID = 6.375" with 6" Otis Unions I , ~'71/16" 5000 psi BOP's. ID = 7.06" I I v 13" 5000 psi /11/4 Turn L T Valve I I I I I~ 1/16" 5000 psi, RX-24 I / 7 1/16" 5000 psi (RX-46) or 41/16" 5000 psi (RX-39) I Swab Valve I Tree Size I --+ SSV I I Master Valve I I Base Flanue I I Page 1 WELLPERMITCHECKLlST COMPAN~.,....)5~.#'þJWELLNAME.tk'4 5)J-/?¿j PROGRAM: Exp_ Dev_ Redrll_ Re-Enter_ Serv_ Wellboreseg~ FIELD & POOL y/o/~o INITCLASS j)~ /-G'// GEOLAREA ¡7C UNIT# /j/~I""J ON/OFFSHORE~.-u ADMINISTRATION 1. Perm~ fee attached. . . . . . . . . . . . . . . . . . . . . . . :/'.,. N \If. A.J.-> f': - '--"l ¿/y-" -I' <'"> ~ < ~..6'.,., ;:1~ I: 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . , . Y N 4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. W ell located proper distance from drilling unit boundary. . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . :f.) N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ X Y.AJ.. 4. (Service Well Only) 14. All wells wlin % mile area of review identified. . . . . . . . .. 'Y N ENGINEERING 15. Conductor string provided. . .. . . . . . . . . . . . . . . . ¥.-N- 16. Surface casing protects all known USDWs. . . . . . . . . . . -¥-N- ¡ / 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥-N- tJ/Æ- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥--N"" ~/'d 19. CMT will cover all known productive horizons. . . . . . . .. . .~ s¡~ If{, 20. Casing designs adequate for C, T, B & permafrost. . . . . . . j N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N CI--1D (,{ . 22. If a re-drill, has a 10-403 for abandonment been approved. . . ". NN -¿ .~ 05 . 23. Adequate wellbore separation proposed.. . .. . . . . . . . . . 24. If diverter required, does "it meet regulations. .. . . . . .. . b N- I'IIA- ¡ D ¡ 6 / 25, Drilling fluid program schematic & equip list adequate. . . . . ~ NN 8· S f P Î ---i'" II. r? f í' ~ Kttlt-« C. ðlAl e,.¡ r;t{4A-1LQ 26. BOPEs, do they meet regulation. . . . . '. i . . . . . . . . . I 27. BOPE press rating appropriate; test to 'is' 00 psig. N 28·. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . "~ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . . N 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥---N- !\JIlt- v@ ~ ;[. NNI/:¡. A~ APPR DATE ~ ~/h3 APPR DATE \tJC¡ir 4 ï.fl (1 ~ (Service Well Only) GEOLOGY APPR DATE ~- fih (Exploratory Only) (' 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (ifoff-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsll nstructions: RP~ TEM JDH JBR COT DTS GGJ O~ / MJW MLB é>3/0,;-/03 SFD WGA Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ) Per Alaska Oil and Gas Conservation Commission Regulation 20 AA 25.005 Permit to Drill sub section 14 (e) if a well has nlultiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface or production casing, the applicant shall designate one branch as the primary Well bore and include all information required under (c) of this section that is unique to that branch and need not include the $100 fee. Rev: 07/10/02 C\jody\templates ') ,) TRANSMIT AL LETTER· CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK WHAT APPLIES v WELL NAME /)R (.{ . ~ ¡J oJ /'6'!-. I PTD# Zoð -ole¡ ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well.':¡ /f.)-'¡<¡ Permit No(P€... ò -µ API No. .J~ -0..2.9- 2..1.)"1'..s Production should continue to be reported as . a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25~055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ;<V')-OíC( # I ~ S-ð ( **** REEL HEADER **** MWD 04/04/29 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/04/29 447715 01 2.375" 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 9981.0000: STOP.FT 12133.0000: STEP.FT 0.5000: 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 #--------- ------------------------- SECT. 28 TOWN.N 13N RANG. 09E PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 68 DMF KB E KB . F 68 EDF . F N/A EGL .F N/A CASE.F N/A OS1 . DIRECTIONAL -Remarks 1. All depths are Bit Depths unless otherwise noted 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. 3N-18L1 Kuparuk River Unit 70 deg 26' 55.947" N, 149 deg 50' 58.873" W. North Slope Alaska Baker Hughes INTEQ 2.375" CoilTrak 31-Mar-03 500292159560 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 2. All depths are Measure Depths (MD) unless otherwise noted. 3. All Gamma Ray data is Realtime data. 4. This wellbore, 3N-18L1, was sidetracked from the existing wellbore 3N-18L1PB1 at 10345 ft. MD (6395 ft. TVD) and drilled to 12133 ft. MD (6552 ft. TVD). 3N-18L1PB1 was kicked off from 3N-18 through a milled window in the 7" liner at 10006 ft. MD (6343 ft. SSTVD). 5. Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE Surface System. 6. Tool ran in the string included CCL, Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole preasure, downhole weight on bit, downhole temperature), a Gamma and Directional sub, and an Orienting sub with a near bit inclination sensor. 7. The data presented here is final and has been depth matched to a PDC (Primary Depth Control) supplied by ConocoPhillips Alaska (SWS, log date unavailable). The PDC was run in the parent wellbore, 3N-18, and as such only the interval above the KOP at 10006 MD is shared between both boreholes. Due to the limited depth overlap, a single tie-in was used and the data from this wellbore was block shifted down 0.5 ft. 8. The interval from 12104 ft. to 12133 ft. MD (6550 ft. to 6552. ft TVD) was not logged due to bit to sensor offset. 9. Tied into RA tag on 3N-18 at 10012 ft. MD MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT Tape Subfile: 1 71 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 3n-18l1 5.xtf 150 ConocoPhillips Alaska Inc. 3N-18L1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! ! !!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth matched to a PDC (Primary Depth Control) supplied by ConocoPhillips Alaska (SWS, log date unavailable). The PDC was run in the parent wellbore, 3N-18, and as such only the interval above the KOP at 10006 MD is shared between both boreholes. Due to the limited depth overlap, a single tie-in was used and the data from this wellbore was block shifted down 0.5 ft. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR 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: 0.500000 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 10: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Size Length 4 4 4 4 ------- 8 Total Data Records: 52 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9981.000000 12133.000000 0.500000 feet **** FILE TRAILER **** Tape Sub file: 2 61 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS **** TAPE TRAILER **** 54 bytes 4124 bytes Minimum record length: Maximum record length: 112 records... Tape Sub file: 3 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9981.000000 12132.500000 0.250000 103 Total Data Records: 8 ------- 4 4 4 4 ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROPA MWD 68 1 F/HR Size Length 0.250 * F FRAME SPACE = 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 * FORMAT RECORD (TYPE# 64) 0.0 0.0 GRAX ROPA GRAX ROPA GRAX ROPA ---------------------------------------------------- ODEP *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** LIS COMMENT RECORD *** 3n-18l1.xtf 150 ConocoPhillips Alaska In 3N-18Ll Kuparuk River Unit North Slope Alaska WDFN LCC CN WN FN COUN STAT -------------------------------- MNEM VALU MWD 04/04/29 447715 01 **** REEL TRAILER **** MWD 04/04/29 BHI 01 Tape Sub file : 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes I' ",\ Tape Subfile 2 is type: LIS DEPTH GR ROP 9981. 0000 18.5900 -999.2500 9981. 5000 26.1600 -999.2500 10000.0000 17.9200 -999.2500 10050.0000 120.8000 40.0400 10100.0000 138.8000 48.8800 10150.0000 138.2000 15.1900 10200.0000 114.3000 82.0500 10250.0000 139.1000 27.2700 10300.0000 139.3100 22.0600 10350.0000 152.4900 9.4000 10400.0000 120.8900 33.7000 10450.0000 108.4200 94.1500 10500.0000 131.5000 53.9500 10550.0000 133.0100 60.5400 10600.0000 144.2000 43.2200 10650.0000 148.2100 37.8600 10700.0000 118.3400 127.5700 10750.0000 83.9700 137.0800 10800.0000 146.0500 78.8100 10850.0000 144.8600 119.6100 10900.0000 139.7700 63.1600 10950.0000 144.2400 56.4500 11000.0000 161.1000 61. 6300 11050.0000 130.3900 69.8700 11100.0000 88.9800 120.2000 11150.0000 90.1500 120.5700 11200.0000 121. 6800 93.1100 11250.0000 130.1800 99.2700 11300.0000 84.8350 102.3400 11350.0000 82.1300 87.3100 11400.0000 121.1600 84.4600 11450.0000 112.3800 29.5100 11500.0000 122.1200 158.9400 11550.0000 96.7700 110.3300 11600.0000 117.8400 114.5000 11650.0000 128.3400 125.5000 11700.0000 58.8200 76.5000 11750.0000 110.9400 68.9200 11800.0000 104.4900 123.6400 11850.0000 97.4900 82.0000 11900.0000 77.4800 90.1100 11950.0000 121.4700 98.7200 12000.0000 126.2425 101.0100 12050.0000 127.4400 72.6000 12100.0000 149.1900 65.4100 12133.0000 -999.2500 -999.2500 Tape File Start Depth 9981.000000 Tape File End Depth 12133.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet Tape Sub file 3 is type: LIS DEPTH GRAX ROPA 9981. 0000 26.1600 -999.2500 9981.2500 25.9100 -999.2500 10000.0000 27.9000 -999.2500 10050.0000 107.0400 41.6500 10100.0000 138.4100 48.9600 10150.0000 134.2400 21. 8000 10200.0000 124.4400 79.5600 10250.0000 132.0900 51.9300 10300.0000 136.3200 38.9500 10350.0000 128.9900 8.2600 10400.0000 132.0100 31.6100 10450.0000 105.3100 94.4500 10500.0000 136.2300 48.4300 10550.0000 139.9200 2.8700 10600.0000 137.7500 48.8300 10650.0000 153.7600 36.4700 10700.0000 117.1000 136.0800 10750.0000 80.8100 136.7500 10800.0000 138.4800 78.9900 10850.0000 140.2700 119.8100 10900.0000 147.8400 73.4500 10950.0000 138.7000 30.2600 11000.0000 159.8300 34.1000 11050.0000 133.0100 69.5200 11100.0000 83.1200 120.3900 11150.0000 107.8300 120.0500 11200.0000 117.7700 92.9200 11250.0000 124.8200 99.1500 11300.0000 83.0000 102.1700 11350.0000 88.6300 86.0800 11400.0000 108.8800 70.6700 11450.0000 116.5<800 27.8700 11500.0000 120.5000 163.5000 11550.0000 87.6700 110.4800 11600.0000 113.5900 110.4900 11650.0000 128.0500 123.2400 11700.0000 63.5100 77.3700 11750.0000 113.7700 78.2200 11800.0000 105.8500 125.0100 11850.0000 114.1700 81.7100 11900.0000 83.7500 88.9100 11950.0000 116.5500 99.0800 12000.0000 125.0800 69.8600 12050.0000 128.4200 72.0700 12100.0000 142.6000 66.9600 12132.5000 -999.2500 -999.2500 Tape File Start Depth 9981.000000 Tape File End Depth 12132.500000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) tJð3-0 Ii ) À t{( ~ - RECEIVED **** REEL HEADER **** MWD 04/02/17 BHI 01 FEB 1 82004 AJa~80U&GasCons.Comm_n An~ LIS Customer Format Tape **** TAPE HEADER **** MWD 04/02/17 447715 01 2.375" 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 9981.0000: STOP.FT 12227.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCAT I ON : CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 28 TOWN.N 13N RANG. 09E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 68 DMF KB EKB . F 68 EDF .F N/A EGL .F N/A CASE.F N/A OSI . DIRECTIONAL -Remarks 1. All depth are Bit Depth unless otherwise noted 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. 3N-18L1PB1 Kuparuk River Unit 70 deg 26' 55.947" N, 149 deg 50' 58.873" W. North Slope Alaska Baker Hughes INTEQ 2.375" CoilTrak 25-Mar-03 500292159570 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"\, ~ 2. All depths are Measure Depths (MD) unless otherwise noted. 3. All Gamma Ray data is Realtime data. 4. The 3N-18L1PB1 was kicked off from 3N-18 through 3" window milled in 7" liner @ 10006 ft. MD (6343 ft. SSTVD) and drilled to 12227 ft MD (6535 ft SSTVD). 5. Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE Surface System. 6. Tool ran in the string included CCL, Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole preasure, downhole weight on bit, downhole temperature), a Gamma and Directional sub, and an Orienting sub. with a near bit inclination sensor. 7. The data presented here is final and has been depth matched to a PDC (Primary Depth Control) supplied by ConocoPhillips Alaska (SWS, log date unavailable). The PDC was run in the parent wellbore, 3N-18, and as such only the interval above the KOP at 10006 MD is shared between both boreholes. Due to the limited depth overlap, a single tie-in was used and the data from this wellbore was block shifted down 0.5 ft. 8. The interval from 12198 ft. to 12227 ft. MD (6535 ft. to 6535. ft TVD) was not logged due to bit to sensor offset. 9. Tied into RA tag on 3N-18 at 10012 ft. MD MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT Tape Subfile: 1 70 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VAL U ---------------------------------- WDFN LCC CN WN FN COUN STAT 3n-1811pb1 5.xtf 150 ConocoPhillips Alaska Inc. 3N-18L1PB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth matched to a PDC (Primary Depth Control) supplied by ConocoPhillips Alaska (SWS, log date unavailable). The PDC was run in the parent wellbore, 3N-18, and as such only the interval above the KOP at 10006 MD is shared between both boreholes. Due to the limited depth overlap, a single tie-in was used and the data from this wellbore was block ') shifted down 0.5 ft. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR 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: 0.500000 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 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 54 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9981.000000 12227.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 63 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MlJEM VAL U ) -------------------------------- WDFN LCC CN WN FN COUN STAT 3n-18l1pbl.xtf 150 ConocoPhillips Alaska In 3N-18LIPBl 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 ROPA ---------------------------------------------------- GRAX ROPA 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 68 68 4 4 4 4 1 1 AAPI F/HR GRAX MWD ROPA MWD ------- 8 Total Data Records: 107 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9981.000000 12227.000000 0.250000 **** FILE TRAILER **** feet Tape Subfile: 3 116 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/02/17 447715 01 **** REEL TRAILER **** MWD 04/02/17 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: :) ) 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS DEPTH 9981. 0000 9981.5000 10000.0000 10050.0000 10100.0000 10150.0000 10200.0000 10250.0000 10300.0000 10350.0000 10400.0000 10450.0000 10500.0000 10550.0000 10600.0000 10650.0000 10700.0000 10750.0000 10800.0000 10850.0000 10900.0000 10950.0000 11000.0000 11050.0000 11100.0000 11150.0000 11200.0000 11250.0000 11300.0000 11350.0000 11400.0000 11450.0000 11500.0000 11550.0000 11600.0000 11650.0000 11700.0000 11750.0000 11800.0000 11850.0000 11900.0000 11950.0000 12000.0000 12050.0000 12100.0000 12150.0000 12200.0000 12227.0000 GR 18.5900 26.1600 17.9200 120.8000 138.8000 138.2000 114.3000 140.3900 139.3100 121. 8800 130.2300 133.6200 121.4600 125.8300 118.0467 145.5100 135.6100 131.5200 135.9200 145.6100 140.1600 131. 0100 113.6200 139.4200 118.3600 129.0200 137.7300 138.0100 93.0700 80.0400 124.1600 131.9900 159.8300 130.1600 84.4400 75.4400 117.9500 115.6000 100.2600 157.4200 141.0050 142.5100 123.9000 104.6500 109.9100 111. 0300 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ) ) ROP -999.2500 -999.2500 -999.2500 41.6500 48.9600 21. 8000 79.5600 51.9300 38.9500 15.7800 58.6000 63.7700 42.0700 24.7000 49.5800 66.0000 70.1700 69.3600 52.2000 21.2100 13.3200 32.7900 53.8100 75.7400 99.9300 139.6100 59.3300 119.0700 65.3800 91. 1900 90.7300 97.9100 59.7800 62.3100 92.2000 97.5300 64.0400 56.4900 88.2700 67.7100 10.9600 79.3900 48.3100 134.3200 141.5100 114.8100 110.8800 -999.2500 9981.000000 12227.000000 0.500000 feet ) ) Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 9981.0000 26.1600 -999.2500 9981.2500 26.4600 -999.2500 10000.0000 27.9000 -999.2500 10050.0000 107.0400 41.6500 10100.0000 138.4100 48.9600 10150.0000 134.2400 21. 8000 10200.0000 124.4400 79.5600 10250.0000 132.0900 51.9300 10300.0000 136.3200 38.9500 10350.0000 122.5400 15.7800 10400.0000 148.3600 58.6000 10450.0000 130.1100 63.7700 10500.0000 124.8000 42.0700 10550.0000 133.4000 24.7000 10600.0000 115.1000 49.5800 10650.0000 140.5900 66.0000 10700.0000 130.2600 70.1700 10750.0000 119.9600 69.3600 10800.0000 137.2200 52.2000 10850.0000 155.5700 21.2100 10900.0000 145.9100 13.3200 10950.0000 120.1200 32.7900 11000.0000 114.0200 53.8100 11050.0000 128.0500 75.7400 11100.0000 115.2200 99.9300 11150.0000 124.8200 139.6100 11200.0000 137.6100 59.3300 11250.0000 135.2450 119.0700 11300.0000 125.0600 65.3800 11350.0000 97.4200 91.1900 11400.0000 131. 3000 90.7300 11450.0000 128.7600 97.9100 11500.0000 140.2500 59.7800 11550.0000 128.9000 62.3100 11600.0000 86.5700 92.2000 11650.0000 74.2200 97.5300 11700.0000 113.9200 64.0400 11750.0000 109.0000 56.4900 11800.0000 109.4300 88.2700 11850.0000 156.4800 67.7100 11900.0000 143.0300 10.9600 11950.0000 136.0500 79.3900 12000.0000 119.0600 48.3100 12050.0000 98.4850 134.3200 12100.0000 129.8400 141.5100 12150.0000 106.7400 114.8100 12200.0000 -999.2500 110.8800 12227.0000 -999.2500 -999.2500 Tape File Start Depth 9981.000000 Tape File End Depth 12227.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet