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Home My WebLink About204-075 e e 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. ~ {¿ Lf - (j 7 S Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: -1-LL-- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L YES BY: CMar~ Date: 7 / ;L(P / b ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) ~wo-sided 11111111111111" III RESCAN ~or Items: D Greyscale Items: DIGITAL DATA o Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date 7 /:;.1,/0 (p Date 7 /~ lo¿' "3 Project Proofing BY: ~ Scanning Preparation BY: Date: BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: D Other:: mE 1//11111111/1//111I VVl£ I J 0 /5/ /5/ ;).0 = TOTAL PAGES (Count does not include cover sheet) /5/ III IIlllt II/lilt III NO /5/ VV1 P NO /5/ 11//111111/11111111 ReScanned BY: Maria Date: /5/ Comments about this file: IIIIIIIIIIII~ IIIII Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • ~ -,.~„_ -• =~~ - MICROFILMED 03/01/2008 DO NOT PLACE ~~. ~, -~~, ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc \ ~ J~l., DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040750 Well Name/No. KUPARUK RIV U WSAK 1E-123L 1 Operator CONOCOPHILLlPS ALASKA INC 5p~L 1 J_ 2,Qi)'1 API No. 50-029-23208-60-00 MD 13345 ,/ TVD 3639 ~ Completion Date 6/16/2004 /' Completion Status 1-01L Current Status 1-01L UIC N -~-- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ ~ DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens/Neutron Well Log Information: (data taken from Logs Portion of Master Well Data Maint Name Interval Start Stop . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ~- ~ 7670 13345 6/25/2004 108 13345 10/8/2004 LIS TIF FILE, GRAPHIC IMAGES RWD-GR/MPR 25 Blu 108 13345 10/8/2004 RWD-GR/MPR 25 Blu 108 13345 10/8/2004 RWD-GR/MPR I 108 13345 10/8/2004 RWD-GR/MPR .~~ ~~~ Sample Set Sent Received Number Comments Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Rpt Directional Survey C PdfLL5 12764 Induction/Resistivity 12764 Induction/Resistivity 12764 Induction/Resistivity 12764 LIS Verification ~ Well Cores/Samples Information: Formation Tops (t/N (91 N . ADDITIONAL INFORMATION Well Cored? Y ß Chips Received? ".¥.L.f:IL.. Daily History Received? Analysis Received? ~ Comments: Compliance Reviewed By: ~ Date: 7~~- . . Tom, Here is the well orientation plot for the 1320 requested on lE-114. Also, included are the cementing reports for each one of these wells. Six wells were seen 'to intersect the 1320 plot: lE-168v ~)ò'-\"1a0 !'\ .. lE-123'/ ;JO'-\ -,0"\ ~ ... \~\::o\vc.\:\~d «;h~ -OL~ ~l);.~",:~~1r- ~-o'1.S- ID-116 ./ \~(6- \ '\. J ID-113 ~ '~<rj- \"l ~ ID-112/ ,~~- -. \ <6 ~ "'" c ID-I03 ';;>0 ðh-O<;' (", -<èv:.\~C(\í(c.) "\11 s -0 L\ All the wells had good cementing operations with the exception of ID-103. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and performed a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 'T~~\5 ~()C'-.J~C,"\- ~G,l.? ~~OS'\h C)\ -\.~ fAL\4{ \- o.~;;.S~C"~ ~Ci:.2J, ·\e t· ~-¡T \r ,~Ö\ \ t: - \ \ ~ ,- l~.\..,~."" Ld. \~k. \:¿h '0\~~~ \ W(2\~ ,Q,CD':~ \-.0",> \-, '<-t-~, ~ \0.ct:2>\ "-\-~ WS.F 4~ .ç':\ \ ~,,~ ~. t \ \J~\t.\\.> \j"-J C~·<! CJQ ~<:\--~~\rl:QJ .~ 0 I"O-,-K o.cœ.p\-OL IÞ \G: \ i"-.:"'~,,'L ~ ' ~9-~~ ~ (9,/ ll-O ..::> · , -;1 / / / / / / / / i g i ""'. ../ fKuparuk ID Pad, ID-103, ID-I03 VI I I Kul Kuparuk IE Pad, lE-123, lE-123 V2 I 7000- ANTI-COLLISION SEtTINGS y J 3538 ConocoPhillips ¡ 3S9S I Kuparuk lEPad, lE-168, lE-168 VI I I ~ 3598 I Kupa~k ID p'ad, ID-112, ID-112 VU ',/il :;%" I Kuparuk IE Pad, lE-1l1, lE-1141 '?", 1J.\)~1 I it! " ~'b ~ nf " ,..,~ 11 " I¡ ~788 ~1~ .l...~.. 3778 ',1~~~ I" I ' <J~~ \iH " "'J",'1.,'b ;1113538 jJ Kuparuk IE Pad, lE-168, lE-168Ll ~3 P K ID Pad, ID-l13, ID-ll3 ru btterpolation Mtlbod:1VD Intenal: 1.000 Depth Rahle From: 3478.000 To: 3788.Z50 MaxUnum Range: 1376.200 RefereUl:e: Defwit¡"e Survey 6000- 5000- +' € o ~ £ 6 VJ 2000- 3718 ! I / ~ 3718 I Kuparuk ID Pad, ID-116, ID-116 V2 l ~' 3658 " , ", f'... , c:::. I 3598 ',~~ ,g7I8 t 3538 --:J478 4000- í=i' ~ o o o ::::: 3000- 1000- -1000- ~ ~~o ~ t ) Pad, IJ?-22, lE-22 VI ~"~ " ) Kuparuk IE Pa<!, l~ Kuparuk lE Pad, lE-33, lE-3~ ~ , '? , I R ----r::5 ' , 34 '" '" , -2000- "" ~I Kuparuk ~~P';d, lE-24, lE-24A VI I ~ I I l I I I I I ..( I I I f I I I I I I I I I I I I I 20bo 3000 4000 5000 6000 7000 ~ 36 ",I :::: \) ''18 / ~ Circles of 1320' Radius 0-, -.. I 8000 !5p1!!1"'"'....v-sun D"ftl' '-INCI i"'IIrAVU:.. West(-)lEast(+) [lOOOftlin] ~ U~"'U\l M..... .........', . Transmittal Form INTEQ To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: ~i~ll:::.:::::? Reference: 1E-123L1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 680722 ,,/ /1 Sent B~len ~r;,eI ., I / / Received ~J /ldfA;/)' 1t;¿/'J4f4! I / ~()cf-o 75 . ,,¡_ BAKER HUGHES Anchorage GEOScience Center .) ~ '. ~\,,~~.. F UL 1 \J b .ÔJÜ4 AIf'iskR Oil &. Gas Cons r.ommla.~!ti; ::::: ;;¡;f'i , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 I'--':::::=':::':::'~:"·Ti ~...;¡_,¡""·;O'I _... ....!....,;"J .., -...1 - ,..". _~ . no . ,c'''_' '- -.., -'" ; .'I>!'~.~ ._.. _ u..,_~ .......__n__ __"_____.__.__.___~_,,.___ __. ;;~;'" ~7'" ":þ. .- -. ... .., --. ~t:~~ ... "':--- -- -- ==~ e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 Plugged U Abandoned 0 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 933' FSL, 630' FEL, Sec. 16, T11 N, R10E, UM At Top Productive Horizon: 944' FNL, 1165' FEL, Sec. 15, T11N, R1OE, UM Total Depth: 21. Logs Run: G AIRes/Dens/Neutron 22. CASING SIZE WT. PER FT. 62.5# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 16" 10.75" 7.625" 4.5" 5960520 . 5963956 ~. ~ ftftf.ll5 Zone-4 Zone- 4 Zone- 4 ~þ .J . ~. ç.t?"t Suspended 0 20AAC 25.110 Other WAG 0 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 5. Date Comp., Susp., or Aband.: June 16, 2004 204-075/ 6. Date Spudded: ...J, £If-iu- ~ ZÞ6t/ 13. API Number: ~ .4t> ¡I-ç.c" 50-029-23208-60 7. Date TD Reached: 14. Well Name and Number: June 6,2004 8. KB Elevation (It): 28' RKB 9. Plug Back Depth (MD + TVD): 13325' MD /3639' TVD 10. Total Depth (MD + TVD): , 13345' MD /3639' TVD . 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A feet MSL 535' FNL, 803'1='ËL, Sec. 10, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 . y- TPI: x- 554604 y- Total Depth: x- 554916 y- 18. Directional Survey: Yes 0 NoU CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 3695' 28' 2205' 28' 8041' 28' 3574' 7666' 13327' 3503' 3639' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slots in upper liner from 7773' to 13264' 9-7/8" 6.75" 24. SIZE 4.5" 1 E-123L 1 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25651 & 25648 17. Land Use Permit: ALK 469 & 466 20. Thickness of Permafrost: -'-ò?r /.V~ ..6D 1530' MD 7":~ '70' Iftj) 3',.52>3 '1v.o ~Ç6Y AMOUNT PULLED HOLE SIZE CEMENTING RECORD 42" 13.5" 300 sx AS I 723 sx AS III Lite, 214 sx DeepCrete 455 sx DeepCrete slotted liner TUBING RECORD DEPTH SET (MD) 6642' PACKER SET none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) July 19, 2004 Gas Lift producer - producdion shared with lower lateral 1 E-123 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 7/22/2004 9 hours Test Period --> 1182 1078 0 100% Flow Tubing Casing Pressure Calculated OIL,BBL GAS-MCF WATER,BBL OIL GRAVITY - API (corr) press. 210 psi 1024 24-Hour Rate ,> 3082 2946 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBOUS Form 10-407 Revised 12/2003 L AIH~ ~ðN~;m)~ . - C -OM:::;;é'";'.'rw -'. I ,~ '-,¡,_ ¡ :v),~ 1 DP.TE~' .6\',(S:'9o . ~.tr"" . 'L,' I ,. -. --------- ; ~."",,_...__...-.J CONTINUEDO 1iEfb I N A L IGAS-OIL RATIO 324 G,~ GEOLOGIC MARKERS e 29. - 28. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None'. 1 E-123L 1 West Sak D 9958' 3535' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Phone Date 7¡2cfty Printed Name ,~v Thomas Signature&;/1~ ~ /?~ IÁ~C? Title: Kuparuk Drillinq Team Leader Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 I , I 1"'\ L e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/15/2004 12:00 - 13:45 1. 75 MOVE DMOB MOVE Install grabber guide bowl & safety wire all bolts, Prep. rig for move. 13:45 - 15:30 1.75 MOVE MOVE MOVE Move rock washer, Boilers, Motors, Pumps, Pits, Sub complexes off 3H-10B. 15:30 - 18:15 2.75 MOVE MOVE MOVE Move Boilers, Motors, Pumps, Pits, Sub complexes from 3H Pad to 1 E Pad. Note; Camp on High line power @ 18:00 hrs. 18:15 - 19:30 1.25 MOVE POSN MOVE Spot Sub complex over hole on 1 E-123. 19:30 - 21 :00 1.50 MOVE POSN MOVE Set matts, Spot Pits, Pumps, Motors, Boilers, Rockwasher into position. 21 :00 - 23:30 2.50 MOVE MOVE MOVE Move pipe sheds from'3H Pad to 1 E Pad, Hook up steam, Air, Water and Glycol lines on rig, Work on rig acceptance list. 23:30 - 00:00 0.50 MOVE POSN MOVE Set pipe sheds into position. 5/16/2004 00:00 - 04:30 4.50 WELCTL NUND RIGUP Nipple up 21-1/4" Diverter system, Mix Spud mud 04:30 - 06:45 2.25 DRILL RIRD RIGUP Load pipe shed with BHA tools, HWDP, Drill pipe, Continue to mix spud mud. 06:45 - 11 :00 4.25 DRILL PULD RIGUP Pick up 29 jts. HWDP, Jars, 90 jts. Drill pipe & stand back in derrick. 11 :00 - 11 :30 0.50 WELCTL BOPE RIGUP Perform Diverter / Accumulator function test, Waived witness test by AOGCC John Crisp. 11 :30 - 13:45 2.25 DRILL PULD SURFAC Make up 13-1/2" Bit, 8" motor w/1.6 deg AKO, NMDC's, Stab, MWD, XIO's, RIH wi 1 stand HWDP. 13:45 - 14:15 0.50 DRILL CIRC SURFAC Tag @ 97', Fill conductor & check for leaks, Clean out to 108'. 14:15 - 15:00 0.75 DRILL DRLG SURFAC Spud well @ 14:15 hrs 5/16/04, Drill f/108' to 188'. 15:00 - 16:00 1.00 DRILL PULD SURFAC Stand back HWDP, Pick up 3 NMCSDP, Wash f/155' to 188'. 16:00 - 18:45 2.75 DRILL DRLG SURFAC Drill 13-1/2" hole f/188' to 343' (Started sliding @ 195'= KOP), Surveys showing erratic Azimuth (Possible magnetic interferance, Closest well slot #7= 45') 18:45 - 20:00 1.25 DRILL TRIP SURFAC POOH to motor and recheck orientation- OK. 20:00 - 21 :30 1.50 RIGMNT RGRP SURFAC Repair top drive- Replace sheared bolts on Stand jump ram, Service top drive. 21 :30 - 22:30 1.00 DRILL TRIP SURFAC Chalk tools in hole to 343', Take check shot surveys @ 285',335' (Still magnetic int.). 22:30 - 00:00 1.50 DRILL DRLG SURFAC Drill 13-1/2" hole fl 343' to 464' (Continue drilling on course to gain seperation and eliminate magnetic interferance). 5/17/2004 00:00 - 02:00 2.00 DRILL DRLG SURFAC Drill f/ 464' to 641' MD / 638' TVD, AST = 1.3 hrs, ART = 0 hrs, WOB 5/20K, 550 GPM @ 1200 psi, UP 71K, DN 67K, (Surveys showing magnetic interferance, Steering motor with chalk line). 02:00 - 02:15 0.25 DRILL CIRC SURFAC Circ hole clean. 02:15 - 03:45 1.50 DRILL TRIP SURFAC POOH, Stand back BHA, Change out MWD tools. 03:45 - 05:15 1.50 DRILL TRIP SURFAC RIH, Take check shot surveys @ 267',357',448',537',631'. 05:15 - 07:00 1.75 DRILL TRIP SURFAC POOH to BHA. 07:00 - 10:00 3.00 WAlTON EOIP SURFAC Wait on Sperry-Sun GYRO. 10:00 - 10:30 0.50 DRILL TRIP SURFAC RIH to 267'. 10:30 - 11 :15 0.75 DRILL RIRD SURFAC Rig up Halliburton wire line service, Run GYRO survey. 11:15-13:00 1.75 DRILL TRIP SURFAC RIH to 641', Take GYRO surveys @ 357',447',537',627'. 13:00 - 14:15 1.25 DRILL CIRC SURFAC Circ & Rig down Halliburton wire line. 14:15 - 00:00 9.75 DRILL DRLG SURFAC Drill f/641' to 1,735' MD /1,520' TVD, AST= 7.1 hrs, ART= 0 hrs, WOB 30/35K, 600 GPM 2150 psi, UP 91K, DN 82K, ROT 87K. 5/18/2004 00:00 - 02:45 2.75 DRILL DRLG SURFAC Drill f/1, 735' to 2,103', AST = 1.0 hrs, ART = 0.8 hrs, WOB 10/30K, 50 RPM, 600 GPM 2150 psi, UP 91K, DN 82K, ROT 87K, TO on 6K15K off. 02:45 - 03:30 0.75 DRILL CIRC SURFAC Pump Hi-vis sweep & circ hole clean w/620 gpm @ 2000 psi, 50 RPM. 03:30 - 04:15 0.75 DRILL TRIP SURFAC POOH to BHA @ 1,085' (Hole in very good shape). 04:15 - 07:45 3.50 DRILL OTHR SURFAC Stand back BHA to Motor, Drain motor & attempt to change rotor nozzle- No Good, Reset Motor AKO to 1.2 deg., RIH w/ BHA. Printed: 7m2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: RIH to 2,020', Precautionary wash to 2,103' (Hole in good shape). Drill f/ 2,103' to 3,705', AST= 1.6 hrs, ART= 5.6 hrs, WOB 15/30K, 100 RPM, 759 GPM 3100 psi, UP 119K, DN 73K, ROT 89K, TQ on 9K- 8/1 OK off. Pump Hi-vis sweep & circ hole clean, Monitor well- Static. Back ream out at drilling rate f/3,705' to 2,565'. Circ btm's up & hole clean while POOH very slow, Pumping at rate of 750 gpm @ 2800 psi, 100 RPM, Circ 2 times btm's up (Had increase of about 30% in cuttings over drilling, then cleaned up fine on 2nd btm's up). POOH on elevators f/2,400' to 890' (Worked thru tight spot f/952' to 922'- Wipe through same several times f/ 1002' to 890'). Stand back HWDP, Lay down Flex collars, Stab, MWD, Motor, Bit, Clear rig floor. Rig to run 10-3/4· casing, Make dummy run with Veto Gray 18-3/16"x 1 0-3/4" casing hanger, PJSM with all crew members. Run 10-3/4" Weatherford Float shoe, 2 its 10-3/4",45.5#, L-80, BTC csg, Weatherford Float collar, 87 its 10-3/4',45.5#, L-80, BTC csg, Veto Gray 18-3/16·x 10-3/4' casing hanger, Ran 10-3/4'x 15-718" Bow spring centralizers as follows= 1-10' above shoe, On collar between jl. #1 & #2, 1-10' below float collar, 1-20' above float collar, 1 every 30' on stop rings for 12 jts., 1 on every collar on its #12 thru #20, Total of 22 centralizers and 12 stop rings. Pump & work thru tight spot @ 960', Wash down to 1,321', Then continue to RIH to btm Float shoe @ 3,694.60', Float collar @ 3,610.75'. 1.00 CEMENT CIRC SURFAC Circ btm's up with Frank's fill up tool at rate of 3 bpm @ 400 psi, Reciprocate csg 15'- UP 160K, DN 90K. 0.50 CEMENT PULD SURFAC Lay down Frank's fill up tool, Rig up Dowell cement head. 1.75 CEMENTCIRC SURFAC Continue to condition mud for cement, Stage rate up to 7 bpm @ 550 psi, Final mud properties 9.6 ppg, 49 vis, PV 17 YP 14, Gels 3/5, PH 8.4, Hold PJSM for cmt job. 4.25 CEMENT PUMP SURFAC Rig Dowell, Mix & pump 5 bbls CW100 at 8.3 ppg at rate of 5.5 bpm @ 400 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 50 bbls, Mix & pump 50 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.5 bpm @ 165 psi, Shut down and drop btm plug, Mix & pump 723 sxs (573.7 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg w/ additives at rate of 6.4 bpm @ 200 psi, Followed by 214 sxs (95.1 bbls) Tail DeepCRETE cmt mixed at 12.0 ppg w/ additives at rate of 6.9 bpm @ 340 psi, Shut down and drop top plug, Displace cmt w/ 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace w/321.6 bbls 9.6 ppg mud (total of 341.6 bbls to bump plug) at rate of 7.0 bpm @ 600 to 730 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, Bump plug w/1000 psi, Floats held- OK, CIP @ 21 :48 hrs 5/19/04, Had good returns thru out job, Reciprocate csg. 15' until MudPUSH at surface then pipe began taking wt., Had 222 bbls good cmt retums to surface. Test casing to 2500 psi for 30 min. on chart- OK. Rig down Dowell cement head, Flush riser and flow line, Rig down casing equip. Nipple down Diverter system. Nipple down Stating head. 5/18/2004 04:15 - 07:45 3.50 DRILL OTHR SURFAC 07:45 - 08:30 0.75 DRILL TRIP SURFAC 08:30 - 20:45 12.25 DRILL DRLG SURFAC 20:45 - 21 :45 1.00 DRILL CIRC SURFAC 21 :45 - 23:15 1.50 DRILL TRIP SURFAC 23:15 - 00:00 0.75 DRILL CIRC SURFAC 5/19/2004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC 01 :00 - 04:00 3.00 DRILL PULD SURFAC 04:00 - 06:00 2.00 CASE RURD SURFAC 06:00 - 14:30 8.50 CASE RUNC SURFAC 14:30 - 15:30 15:30 - 16:00 16:00 - 17:45 17:45 - 22:00 22:00 - 22:30 0.50 CASE MIT SURFAC 22:30 - 00:00 1.50 CEMENT RURD SURFAC 5/20/2004 00:00 - 02:30 2.50 WELCTL NUND SURFAC 02:30 - 05:00 2.50 WELCTL NUND SURFAC Printed: 7nt2004 1:13:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/20/2004 02:30 - 05:00 2.50 WELCTL NUND SURFAC 05:00 - 05:45 0.75 WELCTL NUND SURFAC 05:45 - 08:30 2.75 WELCTL NUND SURFAC 08:30 - 13:15 4.75 WELCTL BOPE SURFAC 13:15 - 15:00 1.75 RIGMNT RSRV SURFAC 15:00 - 17:30 2.50 DRILL PULD SURFAC 17:30 - 22:00 4.50 DRILL PULD SURFAC 22:00 - 23:00 1.00 DRILL TRIP SURFAC 23:00 - 23: 15 0.25 DRILL CIRC SURFAC 23:15 - 00:00 0.75 DRILL TRIP SURFAC 5/21/2004 00:00 - 00:45 0.75 CEMENTTRIP SURFAC 00:45 - 04:00 3.25 CEMENT DSHO SURFAC 04:00 - 05:00 1.00 DRILL CIRC SURFAC 05:00 - 06:00 1.00 DRILL LOT SURFAC 06:00 - 06:45 0.75 DRILL CIRC INTRM1 06:45 - 07:45 1.00 DRILL DRLG INTRM1 07:45 - 09:30 1.75 DRILL CIRC INTRM1 09:30 - 12:00 2.50 DRILL DRLG INTRM1 12:00 - 22:30 10.50 DRILL DRLG INTRM1 22:30 - 23:00 0.50 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL DRLG INTRM1 5/22/2004 00:00 - 05:30 5.50 DRILL DRLG INTRM1 05:30 - 06:00 0.50 DRILL CIRC INTRM1 06:00 - 07:30 1.50 DRILL DRLG INTRM1 07:30 - 08:00 0.50 DRILL CIRC INTRM1 08:00 - 12:00 4.00 DRILL DRLG INTRM1 12:00 - 22:00 10.00 DRILL DRLG INTRM1 NOTE: Took 2.5 hrs to remove Vetco Gray stating head due to new design, Load shoulder ring slipped over and would not let the slip plate slip buy it, Had to remove the slips and leave the ring on the conductor. Nipple up & test Vetco Gray Well head to 5000 psi for 10 min. Nipple up BOPE. Test BOPE to 250 low and 5000 psi high, Hydrill to 250 low and 3500 high, Test waived by AOGCC Jeff Jones. Set wear bushing. Slip & cut drilling line, Service top drive & Blocks. Pick up 75 joints 5" drill pipe from pipe shed and stand back in derrick. Pick up 9-7/8" AutoTrak BHA: Bit, AutoTrak, MAP sub, STOP sub, NM XIO, F/S, NM Stab, 3-NMCSDP, XIO, 3-HWDP, Jars, 26-HWDP, Ghost Reamer, Program & load tools, Surface test same w/550 gpm @ 1100 psi - Weak Pulse. Pick up and single in hole w/ 5" drill pipe to 2,160'. Retest AutoTrak tools w/550 gpm @ 1450 psi- OK. Continue to Pick up and single in hole w/5" drill pipe to 3,374'. RIH to 3,560, fill pipe. Continue RIH and tag top of Float Collar at 3,610. Drill out FC and shoe track. Drill out Float Collar at 3,692', and drill 20' of new hole to 3,725'. Sweep hole clean with 80 rpm, 150 SPM and 1,800 psi. RU and perform LOT w/ 766 psi surface pressure, for an EMW of 16.0 ppg. Displace hole with clean 9.0 ppg LSND mud at 1800 psi and 150 spm. Drill 9-7/8" hole to 3,836' TMD. Circ bottoms up, and perform PWD Baseline test. Drill 9-7/8" hole with AutoTrak to 4,160' tmd. ADT = 2.0 hrs, WOB-5-15K Ib, GPM-507-635, RPM-115, Pump- 1,200 psi, Torque ON/OFF: 5-7,000/4-8,000 ft-Ib Drill 9-7/8" hole with AutoTrak to 5,960' tmd. ADT: 7.2 hrs, WOB-5-20K Ib, GPM-657, RPM-120, Pump- 1,975 psi, Torque ON/OFF: 11-15,000/10-12,000 ft-Ib Changed out blinded off, shaker screens with oily Ugnu sands. NOTE: Water over the Kuparuk River bridge, bridge closed. Drill ahead to 6,065' tmd ADT = 1.0 hrs. Drill 9-718" hole with AutoTrak: 6,065' - 6,782' tmd. WOB-5-20K Ib, GPM-655, RPM-150, Pump- 2,100 psi, Torque ON/OFF: 15-20,000/18,000 ft-Ib Change out shaker screens that were blinded off by oily Ugnu sands. Drill ahead to 6,898' Change out shaker screens that were blinded off by oily Ugnu sands. Control Drill 9-7/8" hole with AutoTrak: 6,898' - 7,245' tmd. ADT = 7.0 hrs (for tower), WOB-5-20K Ib, GPM-655, RPM-150, Pump- 2,100 psi, Torque ON/OFF: 15-20,000/18,000 ft-Ib Drill 9-7/8" hole with AutoTrak: 7,245' - 8,013' tmd. WOB-5-20K Ib, GPM-655, ECD-10.2-10.4 ppg (Calculated ECD at 7-5/8" csg shoe = 10.06 ppg), RPM-150, Pump- 2,250 psi, Torque ON/OFF = 12-19,000/16-17,000 ft-Ib ADT = 7.3 hrs (for tower) (Drilled concretions for 2hrs: 7,690-7725' Note: Held a Pad evacuation drill for all. Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/22/2004 12:00 - 22:00 10.00 DRILL DRLG INTRM1 22:00 - 22:15 0.25 DRILL CIRC INTRM1 Circulate out gas cut mud (max=906 units) 22:15 - 22:30 0.25 DRILL DRLG INTRM1 Drill ahead to 8,047' 22:30 - 22:45 0.25 DRILL CIRC INTRM1 Circulate, survey, downlink and re-program AutoTrak. 22:45 - 00:00 1.25 DRILL REAM INTRM1 Flow check, backream out of hole 8,047'-7,459' at 635 gpm, 150 rpm, 12-15,000 ft-Ibs of torque. Worked tight spot at 7,621'. 5/23/2004 00:00 - 01 :00 1.00 DRILL REAM INTRM1 Continue to backream from 7,459' to 7,181'. Worked thru tight spots from 7,300' -7,181'. Well started unloading excess cuttings (3x cuttings rate over the shakers as when it was drilled). RIH to 7,645', below the first tight. 01 :00 - 01 :30 0.50 DRILL CIRC INTRM1 CBU, until returns started cleaning up. 01 :30 - 03:00 1.50 DRILL REAM INTRM1 Backream form 7,695' - 6,995' at 150 rpm and 635 GPM, w/o problems. 03:00 - 04:00 1.00 DRILL CIRC INTRM1 Pump 35 bbl of Hi-Vis / weighted sweep and circulate. (10% increase in cuttings). 04:00 - 07:15 3.25 DRILL TRIP INTRM1 Flow check - static. POOH on elevators from 6,995' - 3,653'. Hole taking proper fill. 07:15 - 11 :00 3.75 DRILL TRIP INTRM1 Flow check f/15 min. POOH and LD 28 stds of 5" DP, Ghost reamer, 29 Jts of HWDP, BHA. 11 :00 - 12:00 1.00 DRILL PULD INTRM1 Download MWD, LD same. 12:00 - 12:45 0.75 WELCTL OTHR INTRM1 Pull WB, set test plug. 12:45 - 13:45 1.00 WELCTL BOPE INTRM1 Change out top set of pipe rams to 7-5/8" and tested to 3,500 psi. 13:45 - 14:00 0.25 CASE OTHR INTRM1 Make Dry run with landing joint and csg hngr. 14:00 - 15:00 1.00 CASE RURD INTRM1 RU equipment for 7-5/8" csg. 15:00 - 20:30 5.50 CASE RUNC INTRM1 PJSM. Run casing to 3,690'. Up Wt = 127K, Dwn Wt + 69K. 20:30 - 21 :45 1.25 CASE CIRC INTRM1 Circulate casing, staging up to 5 BPM and 325 psi. 21 :45 - 22:30 0.75 CASE CIRC INTRM1 Change out sealing cup on Frank's Tool. 22:30 - 00:00 1.50 CASE RUNC INTRM1 Run casing in open hole to 5,128. Avg MU TQ = 9,000 ft-Ib. 5/24/2004 00:00 - 01 :00 1.00 CASE RUNC INTRM1 Continue to run 7-5/8" casing to 5,560'. 01 :00 - 01 :45 0.75 CASE CIRC INTRM1 Break circ at 2 bpm & stage up to 6 bpm @ 500 psi. 01 :45 - 05:00 3.25 CASE RUNC INTRM1 Continue to run 7-5/8" casing, Total of 188 joints, 1-10'pup, 1-20' pup, Make up landing loint & land @ 8,041'. 05:00 - 05:45 0.75 CASE RURD INTRM1 Lay down Frank's fill up tool, Rig up Dowell cement head. 05:45 - 07:15 1.50 CEMENTCIRC INTRM1 Break circ, Stage rate up to 6 bpm @ 550 psi, Circ & condo mud for cement. 07:15 - 10:15 3.00 CEMENT PUMP INTRM1 Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.3 bpm @ 240 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 5.5 bpm @ 220 psi, Shut down and drop btm plug, Mix & pump 455 sxs (186.4 bbls) Tail DeepCRETE cmt mixed at 12.5 ppg w/ additives at rate of 6.0 bpm @ 300 psi, Shut down and drop top plug, Displace cmt w/20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace w/341.7 bbls 9.0 ppg mud (total of 361.7 bbls to bump plug) at rate of 6.5 bpm @ 200 to 930 psi, Slowed rate to 3.5 bpm @ 1050 psi for last 10 bbls of displacement, Bump plug w/1700 psi, Floats held- OK, CIP @ 10:15 hrs 5/24/04, Had good returns thru out job, Unable to reciprocate casing due to excessive up and down drag with 84.2 deg. deviation. UP 240K, DN 55K, Blocks 35K. 10:15 - 11 :00 0.75 CASE MIT INTRM1 Test 7-5/8" casing to 3000 psi for 30 min.- OK. 11:00 -12:15 1.25 DRILL LOT INTRM1 Rig & pump down 7-5/8" x 10-3/4" annulas w/ 30 bbls mud, Monitor well for 15 min's, Held 410 psi, 1.02 bbls back, Used 9.0 ppg mud, 760 psi= 15.6 ppg EMW. 12:15 - 13:15 1.00 CEMENT RURD INTRM1 Rig down casing tools, Cement head, Lay down landing joint. 13:15 - 14:15 1.00 WELCTL EQRP INTRM1 Install FMC Gen 5 7-5/8' pack off, Test same to 5000 psi for 10 min.- Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/24/2004 13:15 - 14:15 1.00 WELCTL EORP INTRM1 OK. 14:15 - 16:30 2.25 WELCTL EORP INTRM1 Change top rams to 3-1/2" x 6", Btm rams to 4", Set wear bushing. 16:30 - 21 :00 4.50 DRILL PULD INTRM1 Rig & lay down all 5" drill pipe from derrick using mouse hole.. 21 :00 - 00:00 3.00 DRILL PULD INTRM1 Change out 5" equipment to 4", Load pipe shed with Push pipe and 4" drill pipe, Pick up 9 stands push pipe. 5/25/2004 00:00 - 01 :00 1.00 DRILL PULD INTRM1 Continue to pick up Push pipe, Stand back same in derrick. 01 :00 - 05:00 4.00 DRILL PULD INTRM1 PJSM, Pick up 174 jts. 4", 14#, S-135, XT-39 drill pipe from pipe shed. 05:00 - 06:30 1.50 RIGMNT RSRV INTRM1 PJSM, Slip & cut drilling line 59', Service rig. 06:30 - 10:45 4.25 DRILL PULD INTRM1 POOH & stand back 24 stands 4" Drill pipe without LO TAD's, POOH, Pick up LO TAD's on 34 stands & stand back same. 10:45 - 16:15 5.50 WELCTL BOPE INTRM1 Pull wear bushing, Set test plug, Test all BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, AOGCC Jeff Jones waived witness of test., Set wear bushing. 16:15 - 18:00 1.75 DRILL PULD INTRM1 Pick up 6-3/4" BHA, Bit, Turbo reamer, Motor w/1.2 AKO, LWD/MWD/PWD, 3-NMCSDP, XO, 1-HWDP, Jars, 1-HWDP, XO, Total BHA= 255.09'). 18:00 - 00:00 6.00 DRILL TRIP INTRM1 Pick up 56 stands (168 jts., 5,234.39') 4" drill pipe without LO TAD's from pipe shed, Pick up 26 stands 4" drill pipe from pipe shed with LO TAD's. 5/26/2004 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 Continue to pick up 4"drill pipe & Lo Tad's (Total 26 stands with Lo Tad's) to 7,907'. 01 :30 - 04:00 2.50 CEMENT DSHO INTRM1 Break circ, Tag float collar @ 7,958', Drill out float collar @ 7,958', Cmt, Shoe @ 8,041', Cmt to 8,047', Drill new hole f/ 8,047' to 8,067' wI 300 gpm @ 1875 psi, WOB 5/10K, RPM 50, 8/10K TO, UP 86K, DN 55K, ROT 83K. 04:00 - 05:00 1.00 DRILL CIRC INTRM1 Circ & change over to 9.2 ppg Flo Pro mud at rate 300 gpm @ 1700 psi. 05:00 - 06:00 1.00 DRILL LOT INTRM1 Rig & perform LOT 0115.9 ppg EMW w/9.2 ppg mud, 1254 psi, 3574' TVD. 06:00 - 08:00 2.00 DRILL DRLH PROD Drill f/8,067' to 8,195' (128') AST= .50 hrs, ART= 1.0 hrs, WOB 5/1 OK, RPM 100, 315 gpm @ 1900 psi, UP 104K, DN 65K, ROT 82K, TO 5K on/5K off, ECD's range f/1 0.9 to 11.2 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units. 08:00 - 09:00 1.00 DRILL CIRC PROD Circ btm's up & perform PWD clean hole base line tests as follows. 290 gpm 300 gpm 330 gpm 90 RPM= 10.6 ECD 90 RPM= 10.76 ECD 100 RPM= 11.0ECD 100= 10.79 ECD 100 RPM= 10.86 ECD 110 RPM= 11.02 ECD 110= 10.81 ECD 110 RPM= 11.02 ECD 09:00 - 00:00 15.00 DRILL DRLH PROD Drill 1/ 8,195' to 9,820' (1,625') AST = 1.1 hrs, ART = 7.6 hrs, WOB 5/14K, RPM 110/115, 337 gpm @ 2100 psi, UP 109K, DN 64K, ROT 83K, TO 6K on/7K off, ECD's range 11 11.2 to 11.5 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units. Note: At +/- 9,150' MD, Connection gases increased f/400 to 1740 units, Mud cut f/ 9.2 to 8.3 ppg, Gas circ's to +/- 50 units with ECD's. 5/27/2004 00:00 . 12:00 12.00 DRILL DRLH PROD Drill f/9,820' to 10,820' (1,000') AST = 1.0 hrs, ART = 6.2 hrs, WOB 2I14K, RPM 110/115, 337 gpm @ 2400 psi, UP 109K, DN 62K, ROT 82K, TO 7K on/7K off, ECD's range f/11.2 to 11.5 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units, Connection gases fl 100 to 850 units. 12:00·00:00 12.00 DRILL DRLH PROD Drill f/1 0,820' to 11,983' (1,163') AST = 0.8 hrs, ART = 6.7 hrs, WOB 5/14K, RPM 110/115, 337 gpm @ 2650 psi, UP 117K, DN 59K, ROT 81 K, TO 9K on/9K off, ECD's range f/11.3 to 11.6 ppg, Mud wt. 9.2 Printed: 7/7/2004 1:13:43 PM e e Legal Well Name; Common Well Name: Event Name: Contractor Name; Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date; 5/17/2004 End: Group; 5/27/2004 12:00 - 00:00 12.00 DRILL DRLH PROD ppg, Ave BGG 30 to 40 units, Connection gases f/100 to 1025 units. 5/28/2004 00:00 - 02:45 2.75 DRILL DRLH PROD Drill f/ 11,983' to 12,131' (148') AST = 0.3 hrs, ART = 1.0 hrs, WOB 5/10K, RPM 110/115, 325 gpm @ 2700 psi, UP 117K, DN 59K, ROT 81 K, TO 9K on/9K off, ECD's range f/11.3 to 11.6 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units, Connection gases f/ 100 to 600 units. Note; Logs showed we drilled out and above sand. 02:45 - 03:00 0.25 DRILL TRIP PROD Back ream out to 11,950' 03:00 - 06:00 3.00 DRILL DRLH PROD Time drill, Side track low side of hole f/ 11,950 to 12,131', AST = 1.0 hrs, ART = 0.5 hrs. 06:00 - 12:00 6.00 DRILL DRLH PROD Drill f/12,131' to 12,760' (810') AST= 1.0 hrs, ART= 3.0 hrs, WOB 5/10K, RPM 110/115, 325 gpm @ 2700 psi, UP 122K, DN 52K, ROT 84K, TO 10K on/10K off, ECD's range f/11.3 to 11.6 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units, Connection gases f/1 00 to 300 units. 12:00 - 21 :30 9.50 DRILL DRLH PROD Drill f/12, 760' to 13,460' (700') AST = 1.4 hrs, ART = 4.0 hrs, WOB 517K, RPM 110/115, 325 gpm @ 2800 psi, UP 130K, DN 65K, ROT 95K, TO 9K on/ 8K off, ECD's range f/11.3 to 11.8 ppg, Raise mud wt. to 9.4 ppg prior to TD, Ave BGG 30 to 40 units, Pump sweep on last connection. 21 :30 - 23:00 1.50 DRILL CIRC PROD Finish circ sweep around, Gas below 30 units, Drop rabbit, Monitor well - well showing slite flow but decreasing. 23:00 - 00:00 1.00 DRILL TRIP PROD Back ream out of hole at drilling rate f/13,460' to 12,780', 325 gpm @ 2600 psi, 100 RPM. 5/29/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD Back ream out of hole at drilling rate f/12, 780' to 12,131', 325 gpm @ 2600 psi, 100 RPM, Hole not taking correct fill (Gain of 2 bbls- should be a loss of 12.8). 01 :00 - 01 :15 0.25 WELCTL OBSV PROD Observe well for 15 min.- gain of 2 bbls. 01:15-02:00 0.75 DRILL TRIP PROD RIH to 13,460'. 02:00 - 03:00 1.00 DRILL CIRC PROD Circ btm's up at 325 gpm @ 2675 psi- (Trip gas and max gas 35 units). 03:00 - 03:15 0.25 WELCTL OBSV PROD Observe well for 15 min.- gain of 2 bbls. 03:15 - 05:00 1.75 DRILL CIRC PROD Circ and raise mud weight f/9.4 to 9.5 ppg, No mud loss, Gas below 20 units. 05:00 - 05:30 0.50 WELCTL OBSV PROD Observe well for 20 min.- gain of 0.7 bbls, Slight flow. 05:30 - 07:30 2.00 DRILL TRIP PROD Back ream out of hole at drilling rate f/13,460' to 12,131', 325 gpm @ 2600 psi, 100 RPM. 07:30 - 14:00 6.50 DRILL TRIP PROD Note: Observe well several times on way out to shoe with mild breathing(Checking flow for 10 min. with gains of 1.25 to 1.4 bbls). Hole took total 29 bbls (Over and above pipe displacement) while back reaming. 14:00 - 16:00 2.00 DRILL CIRC PROD Pump Hi-vis weighted sweep & circ hole clean- Had 200% increase in cuttings with sweep. 16:00 - 16:30 0.50 WELCTL OBSV PROD Observe well- nearly static, Pump dry job. 16:30 - 22:00 5.50 DRILL TRIP PROD POOH on elevators f/8,OOO' to 3,700', Observe well every 5 to 10 stands well is static at times and very slight flow at other times. (Calc. fill-24.9 bbls, Actual fill +13 bbls, Total of 37.9 bbl gain), Fill pipe and break circ with immediate circulation. 22:00 - 00:00 2.00 DRILL TRIP PROD Pump out of hole f/3, 700' to 1,844' at 5 bpm @ 600 psi. (Calc. fill 1 0.7 bbls, Actual fill-21 bbls, Total of 10.3 bbls loss). Note: As of midnight at 1,844', Calculated fill for Drill pipe and Push pipe= 73.3 bbls, Actual fill = 73.0 bbls, 0.3 bbls difference). 5/30/2004 00:00 - 01 :30 1.50 DRILL TRIP PROD Pump out of hole f/ 1844' to 255' at 5 bpm @ 600 psi. (Calc. fill 9.1 bbls, Actual fill 14.0 bbls, Total of 4.9 bbls loss). 01 :30 - 03:00 1.50 DRILL PULD PROD Monitor well- Very slight flow, Stand back HWDP, Lay down 3- NMCSDP, Break bit, Drain motor. Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/30/2004 03:00 - 04:00 1.00 DRILL PULD PROD Down load LWD tools & lay down same. 04:00 - 04:45 0.75 CASE RURD CMPL TN Rig to run 4-1/2" liner, PJSM w/ all personnel. Note: Monitor well for 15 min. while rigging up, Had .68 bbl gain- Same as prior to POOH for liner. 04:45 - 09:00 4.25 CASE PULR CMPL TN Run 4-1/2" ROT Silver bullet guide shoe, 2- it Blank 4-1/2", 12.6#, L-80, IBT casing, BOT Pack off bushing, XIO, 6- its, 32 spf, 2.5" x 1/8" x 4 rows, DWC Slotted casing, 8 jts Blank 4-1/2",12.6#, L-80, DWC Casing, 119 its Slotted 4-1/2",12.6#, L-80, DWC casing, 2- jts Blank 4-1/2", 12.6#, L-80, DWC casing, Installed Weatherford 4-1/2" x 6-1/4" Spiral Glide centralizers every 30' sliding on stop collars on first slotted casing to 7-5/8" shoe. 09:00 - 15:30 6.50 CASE RURD CMPL TN Rig & run 2-7/8",6.5# Inner string. 15:30 - 16:30 1.00 CASE PULR CMPL TN Pick up BOT Liner hanger, UP 100K, DN 73K, TO 4,500 fVlbs. 16:30 - 19:30 3.00 CASE RUNL CMPL TN RIH w/liner on drill pipe to 8,030' (7-5/8" shoe @ 8,041'), Running speed 30 to 50 fVmin., Pipe displacement 1.0 to 1.5 bbls per 5 stands (Calculated 2.6 bbls per 5 stands), Record UP & DN weights every 5 stands. 19:30 - 21 :00 1.50 CASE CIRC CMPL TN Stage rate up and Circ btm's up at 3 bpm @ 950 psi, No btm's up gas, Mud wt. out 9.6+ ppg w/ Vis 58, Mud wt in 9.5 ppg w/53 Vis., After btm's up increase rate to 4 bpm @ 1130 psi, lost total 9 bbls while circ. 21 :00 - 00:00 3.00 CASE RUNL CMPL TN RIH w/liner on drill pipe to 10,550', Running speed 30 to 50 fVmin., Pipe displacement 1.5 to 2.0 bbls per 5 stands (Calculated 2.6 bbls per 5 stands), Record UP & DN weights every 5 stands, Record torque every 10 stands, Pump 50 bbls at 3 bpm @ 950 psi while coming down with every 10th stand. 5/31/2004 00:00 - 03:30 3.50 CASE RUNL CMPL TN RIH w/liner on drill pipe to 13,460', Running speed 30 to 50 fVmin., Pipe displacement 1.5 to 2.0 bbls per 5 stands (Calculated 2.6 bbls per 5 stands), Record UP & DN weights every 5 stands, Record torque every 10 stands, Pump 50 bbls at 3 bpm @ 950 psi while coming down with every 10th stand. 03:30 - 05:15 1.75 CASE CIRC CMPL TN Reciprocate pipe 15' to 20', Stage rate up to 4 bpm @ 1600 psi & Circ btm's up, UP 132K, DN 71 K, ROT 65K, 15 RPM @ 6500 ftIIbs, Had a little sand back on btm's up. 05:15 - 05:45 0.50 CASE CIRC CMPL TN Flush pumps with Brine, Pressure test lines to 5000 psi. 05:45 - 08:30 2.75 CASE CIRC CMPL TN Pump Spacer, Change over outter annulus to 9.5 ppg w/ 490 bbls brine at rate of 4 bpm @ 1650 psi, Reciprocate pipe 15' to 20', Observe spacer pill back to surface, then some thick oil, No sand observed. 08:30 - 08:45 0.25 CASE OTHR CMPL TN Clean Possum belly and under shakers. 08:45 - 10:30 1.75 CASE CIRC CMPL TN Circ another hole volume 490 bbls at rate of 5 bpm @ 1700 psi, No sand observed, Had small amounts of polymer and traces of oil. 10:30 - 11 :30 1.00 WELCTL OBSV CMPL TN Observe well, Gained 42 bbls. 30.5 bbls in first 30 min., 12 bbls in next 30 min. 11 :30 - 16:00 4.50 CASE CIRC CMPL TN Circ & raise weight to 9.7 ppg, Had 240 units gas on btm's up. Pumped max of 6 BPM wI 2450 psi (Did not set hanger), Had small amounts of poymer and traces of oil. 16:00 - 16:30 0.50 WELCTL OBSV CMPL TN Observe well, Gained 13.9 bbls in 30 min. 16:30 - 18:00 1.50 CASE CIRC CMPL TN Circ & displace 155 bbls clean 9.7 ppg brine in outter annulus at rate of 5 bpm @ 1750 psi. 18:00-19:15 1.25 CASE CIRC CMPL TN Drop ball, Circ down w/112 bbls clean brine at rate of 5 bpm @ 1750 psi, Set hanger w/2800 psi @ 14,459', Top @ 7,748.72' 19:15 - 20:30 1.25 CASE DEOT CMPL TN Work pressure up to 3600 psi & ball sheared, Work 4 rounds left hand torque down to hanger (Working pipe each round- No torque observed) Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/31/2004 19:15 - 20:30 1.25 CASE DEQT CMPL TN and confirm release, Set liner top packer, Test annulus to 1500 psi for 10 min.- OK 20:30 - 22:00 1.50 CASE CIRC CMPL TN Pick up 20', Change over inner annulus 280 bbls, 9.7 ppg clean brine at rate of 5 bpm @ 1700 psi, Observed good amount of Flo Pro mud at shackers. 22:00 - 22:45 0.75 WELCTL OBSV CMPL TN Observe well, Gained 12.5 bbls in 30 min. 22:45 - 00:00 1.25 DRILL TRIP CMPLTN POOH w/ wash string, Hole is taking 3/4 hole fill. 6/1/2004 00:00 - 03:30 3.50 DRILL TRIP CMPL TN Continue to POOH to 7,748' (TOL) , Hole fill Calculated= 33.1 bbls, Actual= 16.0 bbls, Gain 19.0 bbls, Observe well w/ slight flow. 03:30 - 04:45 1.25 DRILL CIRC CMPL TN Pump 30 Hi-vis sweep, Change over to 9.9 ppg brine at rate of 14.2 bpm @ 3000 psi. Had Heavy amount of thick oil on btm's up, then clean, No sand, Circ 3 btm's up, Lost 20 bbls while circ. 04:45 - 05:00 0.25 WELCTL OBSV CMPL TN Slight flow for 15 min. then dead. 05:00 - 06:45 1.75 DRILL TRIP CMPL TN POOH to 5,717', Lay down liner running tools, Hole fill Calc.= 11.3 bbls, Actual= 27.5 bbls, 16.2 bbls over calc. 06:45 - 12:00 5.25 DRILL TRIP CMPL TN PJSM, Rig & lay down 187 jts. 2-7/8" tbg. 12:00 - 12:30 0.50 DRILL OBSV CMPL TN Monitor well, Clear floor, Hole tool 3 bbls. 12:30 - 15:30 3.00 DRILL PULD CMPL TN Make up Whipstock BHA, Orient & load MWD/LWD, RIH to 1013'. 15:30 - 20:30 5.00 DRILL TRIP CMPL TN Surface test MWD, RIH slow to 7,095', Hole taking 1 to 3 bph over calc. displacement. 20:30 - 21 :00 0.50 DRILL DEQT CMPL TN Mad Pass K-13 w/ LWD f/7,095' to 7,161', Showed dill pipe measurements 1.5' high. 21 :00 - 22:00 1.00 DRILL TRIP CMPL TN RIH to 7,702'. 22:00 - 22:30 0.50 DRILL SURV CMPL TN Break circ, Work pipe & orient to 10 deg. left of high side, Tag TOL @ 7,753', Stack out No Go @ 7,764', Top of Window @ 7,670' MD 3,503' TVD, Btm of window @ 7,682'. 22:30 - 23:00 0.50 DRILL DEQT CMPL TN Rig & test annulus to 1500 psi-No good. 23:00 - 23:30 0.50 DRILL DEQT CMPL TN Double check orientation (10 deg. Left of highside), Set trip anchor w/ 20K, Toolface still 10 left, Shear mill bolt. 23:30 - 00:00 0.50 DRILL CIRC CMPL TN Change over to 9.5 ppg mud. 6/212004 00:00 - 00:30 0.50 DRILL CIRC CMPL TN Fin displacing out 9.9 brine with used 9.5 ppg Flo-Pro mud, 00:30 - 00:45 0.25 WINDOWOTHR CMPL TN Pressure tested whipstock seal to 1,500 psi for 10 min, pressure bled down 200 psi to 1 ,300 psi in 10 min 00:45 - 05:15 4.50 WINDOWSTWP CMPL TN Milled window in 7 5/8" csg, top of window at 7,670', btm of window at 7,682', drilled 63/4" hole to 7,699' (17'), 2-7K wom, 120 rpm's, 300 gpm, 1,650 psi, rot wt 88K, up wt 108K, dn wt 70K, torque on & off btm 5K ft-Ibs 05:15 - 06:15 1.00 WINDOWCIRC CMPL TN Circ hi vis sweep and circ hole clean, 300 gpm at 1,650 psi 06:15 - 07:00 0.75 WINDOWCIRC CMPL TN Monitored well, had slight flow, circ btms up and max gas at btms up 45 units 07:00 - 08:15 1.25 WINDOWTRIP CMPL TN POOH 10 stds to 6,770', monitored well static 08:15 - 10:00 1.75 WINDOWTRIP CMPL TN POOH F/6,770' to 4,378', hole not taking calc fill 10:00 - 10:15 0.25 WINDOWOTHR CMPL TN Monitored well, gained 1/4 bbl in 10 min 10:15 - 12:00 1.75 WINDOWTRIP CMPL TN TIH F/4,378' to 7,670', raised MW in pits F/9.5 to 9.7 ppg 12:00 - 12:30 0.50 WINDOWCIRC CMPL TN Circ 9.7 ppg MW around, circ at 380 gpm at 2,400 psi, max gas at btms up 33 units 12:30 - 13:00 0.50 WINDOWOTHR CMPL TN Monitored well, well breathing slightly (1/4 bph rate) 13:00 - 15:00 2.00 WINDOWTRIP CMPL TN Pumped dry job and POOH to 4,378' 15:00 - 17:00 2.00 WINDOWTRIP CMPL TN Cont POOH from 4,378' to BHA at 1,013' 17:00 - 19:00 2.00 WINDOWPULD CMPL TN POOH standing back DC's & HWDP, downloaded MWD and LD Milling assembly, upper string mill in gauge, cleared rig floor 19:00 - 20:00 1.00 WELCTL OTHR CMPL TN Pulled wear bushing and flushed out stack 20:00 - 00:00 4.00 WELCTL BOPE CMPL TN RU and tested BOPE, tested rams, valves and choke manifold to 250 Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/2/2004 20:00 - 00:00 4.00 WELCTL BOPE CMPL TN 6/3/2004 00:00 - 03:00 3.00 DRILL PULD PROD2 03:00 - 07:15 4.25 DRILL TRIP PROD2 07:15 - 08:15 1.00 RIGMNT RSRV PROD2 08:15 - 09:15 1.00 DRILL CIRC PROD2 09:15 - 10:15 1.00 DRILL CIRC PROD2 10:15 -11:00 0.75 DRILL CIRC PROD2 11 :00 - 00:00 psi low and 5,000 psi high, tested Annular to 250 psi and 3,500 psi, RD and installed wear bushing Note: Lou Grimaldi with AOGCC witnessed 60% of test MU 6 3/4" Directional BHA #8, oriented and uploaded MWD TIH with BHA #8 to 7,660' (Top of window @ 7,670'), tested MWD at 3,525' and ck ok Slip and cut 95' of drlg line Displaced out 9.7 ppg Flo-Pro mud with new 9.0 ppg Flo-Pro Oriented BHA and RIH thru window with no pumps or problems, washed and reamed undergauge hole from 7,685' to btm at 7,699',325 gpm, 1,800 psi and 80 rpm's, string up wt 105k, dn wt 69K Circ hole and cond mud while changing out shaker screens due to new mud blinding off shakers, circ to sheared mud and began adding drill zone to help keep mud from running off shakers, changed screens from 2-210's & 1-175 t02-140's & 1-110 13.00 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology and directional plan, drilled from 7,699' to 9,195' MD/3,526' TVD, (1,496') ART 5.8 hrs, AST 1.7 hrs, ave 3-5K wob, 14K wob while drlg calcite stringers, 100 rpm's, 78 spm, 325 gpm, off btm pressure 1,850 psi, on btm pressure 2,050 psi, off btm torque 5K ft-Ibs, on btm 6K ft-Ibs, rot wt 83K, up wt 106K, dn wt 66K, 9.0 ppg MW, ave ECD 10.9 ppg, ave BGG 450-500 units, max conn gas 2,200 units with 9.0 ppg mud gas cut to 8.0 ppg 18.50 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 9,195' to 10,789' MD/3,562' TVD (1,594') ART 6.4 hrs, AST 4.3 hrs, ave 3-7K wob, 10-12K wob while drlg calcite stringers, 100-110 rpm's, 78 spm, 325 gpm, off btm pressure 2,200 psi, on btm pressure 2,400 psi, off btm torque 6K ft-Ibs, on btm 7K ft-Ibs, rot wt 80K, up wt 113K, dn wt 60K, 9.1 ppg MW, ave ECD 11.7 ppg, ave BGG 300-400 units, max conn gas 2,550 units from 9,435', 9.1 ppg mud gas cut to 7.8 ppg 2.00 DRILL TRIP PROD2 Backreamed out of hole taking check shots to verify accuracy of MWD tool, found when toolface was in 3rd quadrant of MWD tool would get innacurate azimuth reading, other quadrunts checked ok, decision made to drill ahead and take survey's with tool face on high side 0.50 DRILL TRIP PROD2 TIH from 10,297' to 10,699', washed 90' to btm at 10,789' with no problems 3.00 DRILL DRLG PROD2 Drill, slide and survey from 10,789' to 11,083' MD/3,576' TVD (294'), ART .9 hrs, AST .5 hrs, 4-7K wob, 110 rpm's, 325 gpm, off btm pressure 2,200 psi, on btm pressure 2,300 psi, off btm torque 8K ft-Ibs torque, on btm 8K ft-Ibs, rot wt 84K, up wt 115K, dn wt 60K, 9.1 MW, ave ECD 11.6 ppg, ave BGG 500 units, max gas 1,850 units from 10,983', gas cut mud to 8.0 ppg, drilling with 3% lubricants in mud, at 11,000' began adding 3% glycol to mud system 12.00 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 11,083' to 12,280' MD/ 3,600' TVD (1,197') ART 5.2 hrs, AST .8 hrs, ave 2-14K wob, 80-115 rpm's, 77 spm, 325 gpm, off btm pressure 2,300 psi, on btm pressure 2,500 psi, off btm torque 7.5K ft-Ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 120K, dn wt 50K, 9.2 ppg MW, ave ECD 11.6 ppg, ave BGG 400-500 units, max conn gas 3,400 units from 11,150', 9.1 ppg mud gas cut to 8.0 ppg 12.00 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 12,280' to 13,232' MD/3,640' TVD (952') ART 4.8 hrs, AST .9 hrs, ave 2-14K wob, 115 rpm's, 77 spm, 325 gpm, off btm pressure 2,700 psi, on btm pressure 3,000 psi, off btm torque 8.5K ft-Ibs, on btm 9.5K ft-Ibs, (PU 7 6/4/2004 00:00 - 18:30 18:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 6/5/2004 00:00 - 12:00 12:00 - 00:00 Printed: 71712004 1:13:43 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/512004 12:00 - 00:00 12.00 DRILL DRLG PROD2 stds HWDP) rot wt 92K, up wt 133K, dn wt 63K, raised MW to 9.5 ppg to TD well per well plan, 9.5 ppg MW, ave ECD 11.9 ppg, max ECD 12.2 ppg, pumped 1 weighted hi vis sweep and had 50% increase in cuttings back from sweep, maintained mud with 3% lubricants along with 3% glycol No Gas readings after 16:00 hrs due to Totco unit crashing, lost highline power for 30 min, went onto rig power for 30 min then back to highline, ave gas before Totco unit quit, 500-600 units, ave conn gas 2,200 to 2,600 units 6/6/2004 00:00 - 02:15 2.25 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 13,232' to 13,345' MDI 3,639' TVD (113') (T.D.), ART 1.2 hrs, AST .3 hrs, ave 2-14K wob, 115 rpm's, 77 spm, 325 gpm, off btm pressure 2,700 psi, on btm pressure 3,000 psi, off btm torque 9K ft-Ibs, on btm 10K ft-Ibs, (PU a total of 8 stds HWDP) rot wt 90K, up wt 138K, dn wt 63K, 9.5 ppg MW, ave ECD 11.9 ppg, max ECD 12.2 ppg, maintained mud with 3% lubricants along with 3% glycol No Gas readings due Totco unit down 02:15 - 03:15 1.00 DRILL CIRC PROD2 Pumped 30 bbl weighted hi vis sweep and circ till sweep was up into 7 5/8" csg and above window, circ at 325 gpm, 2,700 psi and 115 rpm's, monitored well and had very slight flow 03:15 - 10:30 7.25 DRILL REAM PROD2 Backreamed out of hole at drlg rate from 13,345' to 7,793'with no problems, backreamed out at 325 gpm, 2,400 psi and 115 rpm's, Pulled on elevators from 7,793' thru window at 7,682'-7,670' with no problems, POOH to 7,600' 10:30 - 13:00 2.50 DRILL CIRC PROD2 Circ hole above window and raised MW from 9.5 ppg to 9.8 ppg, circ hole at 325 gpm, 2,100 psi and 25 rpms, rot wt 75K, up wt 105K, dn wt 70K 13:00 - 13:30 0.50 DRILL OBSV PROD2 Monitored well, had slight breathing, gained .75 bbls in 30 min, dropped 1.74" rabbit on wire 13:30 - 19:30 6.00 DRILL TRIP PROD2 Pumped out of hole 10 stds to 6,633', lost 6 bbls mud over calc fill while pumping out, monitored well, had slight breathing, pumped dry job and POOH to BHA #8 to 250', Calc fill on trip out 40 bbls, actual fill 30 bbls 19:30 - 21 :00 1.50 DRILL PULD PROD2 POOH LD BHA #8, HWDP, jars, DC's, MWD & MM, cleared rig floor, retrieved rabbit at jars, SLM out no corr. 21 :00 - 21 :30 0.50 FISH PULD CMPL T2 MU BHA #9, Baker's fixed lug Whipstock retrieving tool, 1-jt 31/2" HWDP, float sub, bumper sub and oil jars 21 :30 - 00:00 2.50 FISH TRIP CMPL T2 TIH with BHA #9 with DP assembly to be used to run liner, RIH with 40 stds of 4" DP with Lo-Tads to 4,000', calc displacement 21 bbls, actual 19 bbls (To Run 60 stds of Lo-Tads) 6f112004 00:00 - 02:30 2.50 FISH TRIP CMPL T2 TIH with Baker Whipstock Retieving tool from 4,000' to 7,614', filled pipe, st up wt 115K, down wt 85K, lost 27 bbls mud to hole while TIH 02:30 - 02:45 0.25 FISH FISH CMPL T2 RIH and latched onto Whipstock at 7,678', pulled 190K, (75K Over St wt) sheared anchor and pulled whipstock free 02:45 - 03:45 1.00 FISH CIRC CMPL T2 Monitored well and had slight flow, circ 1 .5X btms up at 250 gpm at 1,100 psi, max gas at btms up 40 units, lost 23 bbls mud to hole wlcirc, 50 bbls total while TIH & Circ 03:45 - 04:00 0.25 FISH OTHR CMPL T2 Monitored well and had slight flow, gained less than 1/4 bbl 04:00 - 12:00 8.00 FISH TRIP CMPL T2 POOH with whipstock from 7,668' to 2,769', POOH alternating with and with out pumps on due to swabbing, after 14 stds out, rotated DP and whipstock and well would take fluid, Began POOH rotating 4 stds without pumping & pumping and rotaing the 5 std out otwell, hole still not taking calc fill, began pulling 2 stds wino pump and pumping 1 std Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/7/2004 04:00 - 12:00 8.00 FISH TRIP CMPL T2 out with hole taking some fluid and no signs of any gas 12:00 - 13:30 1.50 FISH TRIP CMPL T2 Pumped out of hole every stand from 2,769' to 1,200', hole took 18 bbls while pumping out of hole 13:30 - 14:30 1.00 FISH TRIP CMPL T2 Monitored well and had slight flow, cont to pump out of hole from 1,200' to 930' when BGG began to increase, while pumping out at 930' BGG increased to 4,923 units, max gas on Totco unit, 9.8 MW gas cut to 7.0 ppg 14:30 - 17:00 2.50 FISH CIRC CMPL T2 Circ hole monitoring gas, gas would increase to 4,923 units then drop down, while moving pipe gas would increase again dropping back out, initial circ at 270 gpm at 400 psi and staged up to 340 gpm at 525 psi with 50K st wt 17:00 - 00:00 7.00 FISH TRIP CMPL T2 Staged into hole from 930' to 3,056', began puming down singles circ btms up after each stand, would max out Totco unit with 4,923 units gas back at btms up with 9.8 ppg mud gas cut to 7.0 ppg, increased MW to 9.9 ppg while pumping in hole, after 5 stds began staging in, would run 1 std wIno pump, pumping 2nd stand down, would pump down at 210 gpm at 200 psi and circ btms up at 340 gpm with initial pressure of 550 psi, at 3,056' at 340 gpm had 750 psi, increased running in hole 3 stds with no pump and pumping 4th std down and btms up gas was down to 3,500 units max and dropping out within 5 min's, 9.9 ppg MW gas cuts ranging from 7.0 ppg with 4,923 units gas to 8.4 ppg with 2,700 units gas, string up wt 64K, dn wt 60K, lost 31 bbls mud to hole while RIH and circ btms up to 3,056', Mud report showed in last 24 hrs had a total loss of 39 bbls to hole 6/8/2004 00:00 - 07:00 7.00 FISH TRIP CMPL T2 Cont to stage in hole with whipstock retrieving tool from 3,056' to 7,610', staged in RIH 3 stds W/O pumping then pumping 4th std down, Circ btms up each time, increased stages to RIH 8 stds and pumping 9th std down, circ btms up at 340 gpm, initial circ pressure at 3,056', 750 psi, final circ pressure from 6,885', 1,400 psi, ave max gas at btms up was 2,700 units gas 07:00 - 07:45 0.75 FISH CIRC CMPL T2 Circ btms up at 7,610', circ at 340 gpm at 1,800 psi, max gas at btms up 1,650 units, st wt up 116K, dn wt 85K, 9.9 ppg MW gas cut to 9.0 ppg at btms up, lost approx 75 bbls mud while staging in hole & CBU 07:45 - 08:00 0.25 FISH FISH CMPL T2 RIH with retrieving tool and saw seal assembly from whipstock assembly enter top of liner, set down with 5K st wt and found whipstock to still be latched onto retrieving tool, PU out of seal assembly 08:00 - 08:30 0.50 FISH OTHR CMPL T2 Monitor well, had slight flow with no measurable gain in trip tank 08:30 - 10:00 1.50 FISH OTHR CMPL T2 Transfer 9.9 brine from tank farm to mud pits, cont. to monitor well with slight flow and no measurable gain in trip tank 10:00 - 11 :00 1.00 FISH CIRC CMPL T2 Displaced out 9.9 ppg mud in well over to 9.9 ppg brine, circ at 380 gpm at 2,350 psi 11 :00 - 11 :30 0.50 FISH OTHR CMPL T2 Monitor well, had slight flow with no measurable gain in trip tank 11 :30 - 17:30 6.00 FISH TRIP CMPL T2 POOH with whipstock to BHA #9 at 61', no problems POOH, calc fill on trip out, 51 bbls actual fill 49 bbls 17:30 - 19:00 1.50 FISH PULD CMPL T2 POOH LD whipstock retrieving assembly and whipstock, cleared rig floor 19:00 - 19:30 0.50 CASE RURD CMPL T2 RU to run 4 1/2" liner, held PJSM on running liner, monitored well-static 19:30 - 00:00 4.50 CASE PULR CMPL T2 PU & ran 41/2" liner to 4,717', MU 31/2" guide shoe (no float), 1 bent jt of 3 1/2", 9.2 #, L-80 IBT-M tbg, XO to 41/2" DWC-Csg, 1 blank jt of 4 1/2", 12.6#, L-80 csg, cont RIH with slotted 4 1/2" liner to 4,717', PU wt 65K, DN wt 57K 6/9/2004 00:00 - 01 :00 1.00 CASE PULR CMPL T2 Fin PU & RIH with 41/2" Liner to 5,634', Ran a total of, 1- bent it of 3 1/2" tbg, 3 blank its and 132 slotted its of 41/2" 12.6#, L-80 DCW-C, Printed: 7/7/2004 1: 13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/9/2004 00:00 - 01 :00 1.00 CASE PULR CMPL T2 Ran 17241/2" x 61/2" Spiralguides with 127 stop rings, 1 cent/every 30', recorded up and down weights every 10 jts after jt #50, calc liner displacement 25 bbls, actual displacement 20 bbls, st up WI 69K, dn WI 54K 01 :00 - 08:00 7.00 CASE PUTB CMPL T2 RU and ran 186 jts of 2 7/8" 6.5# Hydril 511 inner wash string, wash string up WI 60K, dn WI 43K 08:00 - 08:30 0.50 CASE PULR CMPL T2 MU Baker 7 5/8" x 41/2" B-1 flanged hook liner hanger, st WI 90K up, 68K down with 35K block weight 08:30 - 09:00 0.50 CASE RURD CMPL T2 RD Doyon's liner running tools 09:00 - 10:45 1.75 CASE RUNL CMPL T2 RIH with liner on 4" DP to 7,663', recorded up & down weights every 5 stds, st WI with 9.9 ppg brine, 115K up, 85K dn 10:45 - 13:00 2.25 CASE CIRC CMPL T2 Displaced out 9.9 brine in hole back to 9.9 ppg mud, circ at 3 bpm at 800 psi, st WI with 9.9 ppg mud, 103K up, 70K down 13:00 - 18:00 5.00 CASE RUNL CMPL T2 Oriented liner and after 2nd attempt, entered lateral with liner, RIH with liner to 13,327' with no problems, recorded up & down weights every 5 stds, calc displacement from window 13 bbls, actual 16 bbls 18:00 - 18:30 0.50 CASE OTHR CMPL T2 Oriented and hooked liner hanger at btm of window at 7,682',slacked off 30K on hanger, landed liner with shoe at 13,327' and top of liner at 7,666', 18:30 - 19:30 1.00 CASE OTHR CMPL T2 Finished transfering 9.8 ppg brine to mud pits, transfer was delayed due to injection well going down and shortage of vac trucks 19:30 - 00:00 4.50 CASE CIRC CMPL T2 Pumped 35 bbl hi vis spacer and displaced out 9.9 ppg mud in outer liner annulus to 9.8 brine, max gas 2,750 units, BGG dropped down to less than 150 units, circ out spacer, shut down and cleaned out under shakers, cont to circ hole with clean 9.8 brine, círc at 4.75 bpm at 1,975 psi NOTES: Recieved 48 hr waiver on BOP test from John Crisp WIAOGCC, Injection well 1 E-34 pressured up after water flush, decision made to quit using as an injection well, Little Red freeze protected well with 85 bbls diesel 6/10/2004 00:00 - 01 :00 1.00 CASE CIRC CMPL T2 Fin circ outer liner liner annulus with 9.8 ppg brine, circ at 4 3/4 bpm at 1 ,975 psi 01 :00 - 01 :45 0.75 CASE CIRC CMPL T2 Dropped 29/32" ball and pumped ball down to seat, initial rate 3 bpm at 700 psi, slowed to 2 bpm at 400 psi, with ball on seat pressured up to 3,300 psi to release running tool. 01 :45 - 02:00 0.25 CASE DEQT CMPL T2 PU on string to 135K and running tool was released, pressured up to 4,100 psi and blew ball seat, st wt 125K, slacked of into top of liner 02:00 - 04:00 2.00 CASE CIRC CMPL T2 Circ 1.5x hole volume at 7.5 bpm at 3,500 psi, then spotted clean brine in outer liner annulus, didn't see any change in returns from higher rate 04:00 - 07:00 3.00 CASE CIRC CMPL T2 PU out of liner, LD 1-jt of 4" DP, pumped 35 bbl high vis spacer and círc out of hole at 7.5 bpm at 3,500 psi, had additional 35 bbls interface from sweep, cont to circ 1.5X hole volume at 7.5 bpm then spotted clean brine in liner 07:00 - 07:15 0.25 CASE OTHR CMPL T2 Monitored well and had slight flow, no measurable gain in trip tank 07:15 - 18:00 10.75 DRILL TRIP CMPL T2 POOH LD 4" HWDP and 4" DP to 2 7/8" Inner wash string, LD 27 jts of 4" HWDP, 213 jts of 4" DP and 60 Lo-Tads, monitored well atTOL and well was static, monitored well several times W/LD DP and well was static 18:00 - 18:30 0.50 DRILL PULD CMPL T2 LD Baker running tool and cleared rig floor 18:30 - 23:00 4.50 CASE PUTB CMPL T2 RU and POOH LD 186 jts of 2 7/8" Hydril 511 inner wash string 23:00 - 00:00 1.00 CMPL TN RURD CMPL T2 Pulled wear bushing and RU Doyon's tubing handling tools 6/11/2004 00:00 - 00: 15 0.25 CMPL TN SFTY CMPL T2 Pre Job Safety meeting with crew and all contractors 00:15 - 06:00 5.75 CMPL TN RUNT CMPL T2 Run Completion - Ran 212 jts 4.5" 12.6# L-80 IBTM mod wI special Printed: 7f712004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 5/15/2004 6/11/2004 Spud Date: 5/17/2004 End: Group: 6/11/2004 00:15·06:00 5.75 CMPLTN RUNT CMPL T2 06:00 - 07:15 1.25 CMPL TN RUNT CMPL T2 07:15 - 07:30 0.25 CMPL TN RURD CMPL T2 07:30 . 10:00 2.50 CMPL TN RURD CMPL T2 10:00 - 10:45 0.75 CMPL TN RURD CMPL T2 10:45 - 12:00 1.25 CMPL TN RURD CMPL T2 12:00 - 13:30 1.50 CMPL TN RURD CMPL T2 13:30·14:15 0.75 CMPL TN RURD CMPL T2 14:15 - 21 :30 7.25 DRILL PULD CMPL T2 21 :30 - 00:00 2.50 DRILL PULD CMPL T2 clearance coupling 4.920" coupling - Up WI 80K. Dn WI 56K. Bk WI 35K . 9.8 ppg brine in hole M/U hanger & landing jt - Install blank penatrator thru hanger - Land tbg @ 6605 - RILDS - ABB Vetco rep James Lott Test upper and lower hanger seals to 5000 psi for 10 min - "OK" UD Landing joint· Set BPV Remove rams from BOPs - Flush out BOP body's for metal from milling NID BOPs - Set back on stump N/U Tree Con't N/U Tree - Pull BPV - Set TWC - Test tree 250/5000 psi f/10 min "OK"- Pull TWC and set BPV R/D all tbg equipment and clear from floor· RIU to UD DP UD 7500' DP from derrick using mouse hole C/O saver sub to 41/2 IF - CIO to 5" TD handling tools Rig released 23:59 hrs 6/11/04 "" Note""" 10.750" X 7.625" annulus was tested for annular injection. LOP @ 730 psi - Ann was flushed with 250 bbls water - Freeze protected wI 75.5 bbls diesel to 1902' TVD Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 COMPLETION n1334@ppco.com Doyon 141 Start: 6/13/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: 6/16/2004 Group: 6/13/2004 04:00 - 08:30 4.50 MOVE MOVE MOVE Prepare Rig for move. Lowered Derrick. RD Hand-Y-Berm, RD Sub, Pipe Shed, & Motor Complex. Trucks arrived and hooked up prep to move to 1 E-123. 08:30 - 11 :00 2.50 MOVE MOVE MOVE Move rig and camp from 1 L pad to 1 E pad. 11 :00 - 16:00 5.00 MOVE RURD MOVE Spot camp and connect gen. and communications satelite. RU Hand-Y-Berm around well and spot sub. RU pipe shed and motor complex. Raise derrick and scope up. Held Pre-Job meeting with Night crew. 16:00 - 19:00 3.00 MOVE RURD MOVE Complete all hookups inside rig. Accept Rig @ 1700 hrs. Hook up Rig pump to circulate with tree still on. 19:00 - 19:30 0.50 WELCTL NUND CMPL T2 Removed BPV 19:30 - 20:30 1.00 WELCTL CIRC CMPL T2 Load Pits w/9.8# brine. Prepare to circulate hole. 20:30 - 22: 15 1.75 WELCTL CIRC CMPL T2 Circulate hole w/ 9.8# heavy. Pumping down the tubing and taking retums from IA. Pump Rate @ 4 BPM pump pressure @ 250 psi. Circulated 330 bbls lost app: 8 bbls of fluid during circulation. Talked w/ AOGCC inspector John Crisp @ 20:45 and he waived the witness of BOP Test. 22:15 - 23:15 1.00 WELCTL OBSV CMPL T2 Monitored Hole. U-tubed from the IA to the tubing for awhile. Allowed well to equalize and monitored hole for returns. 23:15 - 23:45 0.50 WELCTL NUND CMPL T2 Drained tree and Montiored well further. Well is dead. 23:45 - 00:00 0.25 WELCTL EQRP CMPL T2 Installed BPV and Prepare to ND Tree. 6/14/2004 00:00 - 01 :00 1.00 WELCTL NUND CMPL T2 ND Tree 01 :00 - 04:00 3.00 WELCTL NUND CMPL T2 NU BOPE, discovered that between the double gate of the stack and the Hanger there would not be enough room for the Vetco Plug off tool and also the riser would have to be extended, requiring a welder. Called out for a 2' spacer spool (mud cross) to raise double gate and alleviate all problems. Continued NU BOPE. 04:00 - 05:30 1.50 WELCTL NUND CMPL T2 Spacer Spool on location. Vetco Gray Rep went ahead and installed Plug off tool on Hanger. Continued NU BOPE 05:30 - 06:00 0.50 WELCTL SFTY CMPL T2 Held Pre-completion Mtg with the day crew. 06:00 - 15:00 9.00 WELCTL NUND CMPL T2 Continued to NU BOPE. 15:00 - 18:00 3.00 WELCTL BOPE CMPL T2 As stated on yesterdays report AOGCC Inspector John Crisp waived the witness on the BOP Test.Talked with him on 06113/04 @ 20:45. Function test BOPE. Attempt to test BOP no luck yet. Blinds Tested OK to 3500 psi. Unable to get pipe rams to test. 18:00 - 20:00 2.00 WELCTL BOPE CMPL T2 The Test joint is at to much of an angle, because of the way the hanger is offset to one side. Pulled test joint and it was scarred from the pipe rams. Installed Test joint with donut and Tested pipe rams to 3500 psi. 20:00 - 21 :00 1.00 WELCTL BOPE CMPL T2 Pulled Test joint & donut. Pulled out plug off tool. Confirmed well is still dead. Pulled BPV. Installed 2-way check. Install test joint. Test annular to 3500 psi. 21 :00 - 22:00 1.00 WELCTL BOPE CMPL T2 Pulled test joint. Confirmed well is dead. Pulled 2-way check. Test accumulators and dart valve. BOPE Test completed. 22:00 - 22: 15 0.25 CMPL TN SFTY CMPL T2 Held pre-job mtg. 22:15 - 23:00 0.75 CMPLTN TRIP CMPL T2 Pulled Hanger to the Floor. Up Wt = 58k. Laid down hanger and 1st full joint of pipe in the pipe shed. Fit test Penetrator in Hgr (good fit). Pull 1 st full stand and rack back in derrick. 23:00 - 23:45 0.75 CMPL TN CIRC CMPL T2 Fill hole, hole is out of balance. Mixed up a 15 bbl dry job and circulated same down tbg. 23:45 - 00:00 0.25 CMPL TN TRIP CMPL T2 Able to pull dry pipe and circulate over the top of the hole keeping hole full. 5 stands racked back in derrick. Continued tripping pipe OOH. 6/15/2004 00:00 - 05:00 5.00 CMPL TN TRIP CMPL T2 Tripped OOH Racked back all tubing 05:00 - 07:00 2.00 CMPL TN PULD CMPL T2 Set up Centrilift Equipment and begin bringing ESP components to the Printed: 7/7/2004 1 :04:03 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 COMPLETION n1334@ppco.com Doyon 141 Start: 6/13/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: 6/16/2004 Group: floor. Made up Centralizer, Press & Temp Sensor, Motor, Seals, TIC, & X-over. Verified Oil Fill on the Motor, tightness of all plugs, and Free rotation of Motor components. Connect ESP cable to Motor. Begin adding flat cable protectors and bands for completion proceedures. Test cable integrity. Continue to RIH. Having problems getting stand number 6 to torque up. Change out coupling. No good. Prep to change out bottom joint on stand number 6. Changed out joint and continued into hole. At stand number 9 cable dropped into a gap at the airslip guide bolt which subsequently compromised the cable. shut down for a splice. Splice ESP cable. Held Pre-job meeting went over the running ovf completion with ESP & cable. Removed roller from guide bolt on the air slip (this is what caused the cut in the cable). Began running ESP completion again. Testing ESP cable every 1000'. Continue running new ESP completion. Checking ESP cable every 1000'. Hole fill is very stable losing about 1/4 BPH brine wt @ 9.8#. Pick up hanger and begin final splice after spacing out cable length. Count bands, protectrolizers, and cannon clamps on location for accountability. Meg test passed. Landed Hgr. Final Up Wt = 72k and Down Wt 35k. RILDS. Pressure tested upper and lower hanger seals --- passed--. Back pressure valve set. Begin to nipple down the BOPE. Wash pits prep for rig move. Check ESP cable after BOP removed and it checked out good. NU tree. Checked ESP cable and it is good. PresslTemp Gauge reading 1837 psi @ 65.3 degrees. 2.00 CMPL TN SEOT CMPL T2 Pressure tested Pack offs to 5000 psi. Pulled BPV and install 2-way check. Pressure test Tree to 5000 psi. Check ESP cable again and it checked out. 2.00 CMPL TN RURD CMPL T2 Make up Actuators to the Tree. Release Rig @ 22:00 hrs. 6/15/2004 05:00 - 07:00 2.00 CMPL TN PULD CMPL T2 07:00 - 10:30 3.50 CMPL TN PULD CMPL T2 10:30 - 13:30 3.00 CMPL TN PULD CMPL T2 13:30 - 14:00 0.50 CMPL TN RUNT CMPL T2 14:00 - 15:30 1.50 CMPL TN RUNT CMPL T2 15:30 - 17:30 2.00 CMPL TN RUNT CMPL T2 17:30 - 20:30 3.00 CMPL TN RUNT CMPL T2 20:30 - 20:45 0.25 CMPL TN SFTY CMPL T2 20:45 - 00:00 3.25 CMPL TN RUNT CMPL T2 6/16/2004 00:00 - 08:00 8.00 CMPL TN RUNT CMPL T2 08:00 - 12:08 4.13 CMPLTN RURD CMPL T2 12:08 - 13:00 0.87 CMPL TN SEOT CMPL T2 13:00 - 18:00 5.00 CMPL TN NUND CMPL T2 18:00 - 20:00 20:00 - 22:00 Printed: 7/7/2004 1 :04:03 PM C~illips ConocoPhilJips Alai Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellb.123 L 1 Wellpath: MWD wI Mag&Sag <7771 - 13345'> Date Printed: 21-Jun-2004 ?-ö"4 - 0 1\ .¡. ---Au INTEQ WeIIbofe Name 123 L1 I Last Revised 14-Jun-2004 Name 123 ID Name Slot #123 Name Pad 1 E Field Name KUDaruk River Unit I Eastina 487754.6208 I Northina . 5948985.8206 I CoordSvstemName . .1 NorttiÄli(nment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10418.87 Feet on azimuth 29.22 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 'f'ItJ\ £:) ~\1Y Cor1ocÓÁ1illips ConocoPhillips AI., Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb. 123 L 1 Well path: MWD wI Mag&Sag <7771 - 13345'> Date Printed: 21-Jun-2004 rei. -,¿. INTEQ We II path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] I Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionfftl 7670.00 75.19 5.11 3503.51 ! 3441.31N 4740.34E 0.00 3736.26 554606.78 5963992.00 7771.55 83.95 4.58 3521.88 3540.73N 4748.75E 8.64 3836.01 554614.54 5964091.46 7835.62 89.82 4.19 3525.36 3604.49N 4753.64E 9.18 3899.96 554619.00 5964155.24 7932.26 92.15 3.99 3523.70 3700.86N 4760.53E 2.42 3996.57 554625.25 5964251.65 8028.86 90.68 6.73 3521.31 3797.00N 4769.55E 3.22 4093.09 554633.64 5964347.83 8125.74 90.40 3.25 3520.40 3893.49N 4777.98E 3.60 4189.92 554641.42 5964444.37 8222.36 89.29 7.61 3520.66 3989.65N 4787.12E 4.66 4286.47 554649.92 5964540.58 8319.17 90.98 4.59 3520.43 4085.90N 4797.41E 3.57 4383.18 554659.57 5964636.89 8415.51 89.57 0.96 3519.97 4182.11N 4802.07E 4.04 4479.49 554663.59 5964733.11 8512.19 91.04 3.64 3519.45 4278.69N 4805.95E 3.16 4576.13 554666.83 5964829.72 8609.16 89.75 7.71 3518.78 4375.17N 4815.53E 4.40 4673.01 554675.77 5964926.24 8705.28 88.65 8.52 3520.13 4470.31N 4829.10E 1.42 4768.83 554688.70 5965021.46 8802.34 89.39 1.84 3521.79 4566.90N 4837.86E 6.92 4865.78 554696.82 5965118.10 8899.49 90.64 2,16 3521.76 4663.99N 4841.25E 1.33 4962.89 554699.56 5965215.20 8996.79 90.00 1.49 3521.22 4761.24N 4844.35E 0.95 5060.14 554702.02 5965312.46 9092.82 87.67 3.30 3523.17 4857.16N 4848.36E 3.07 5156.12 554705.39 5965408.39 9189.30 88.28 2.08 3526.58 4953.47N 4852.88E 1.41 5252.52 554709.27 5965504.72 9286.49 89.66 8.28 3528.33 5050.20N 4861.65E 6.53 5349.61 554717.40 5965601.49 9382.38 88.86 4.44 3529.57 5145.47N 4872.27E 4.09 5445.37 554727.39 5965696.83 9480.22 87.60 7.31 3532.59 5242.74N 4882.28E 3.20 5543.07 554736.75 5965794.15 9577.94 88.62 4.67 3535.82 5339.86N 4892.47E 2.89 5640.65 554746.29 5965891.33 9673.79 90.83 0.41 3536.28 5435.59N 4896.72E 5.01 5736.45 554749.90 5965987.07 9771.50 91.50 3.39 3534,29 5533.21N 4899.95E 3.13 5834.09 554752.49 5966084.71 9866.61 89.94 359.82 3533.09 5628.26N 4902.62E 4.10 5929.11 554754.52 5966179.76 9963.96 86.96 357.39 3535.73 5725.53N 4900.25E 3.95 6026.03 554751.51 5966277.00 10060.76 87.36 357.62 3540.52 5822.12N 4896.04E 0.48 6122.15 554746.66 5966373.55 10157.16 89.82 358.02 3542.89 5918.41N 4892.38E 2.59 6218.02 554742.36 5966469.81 10253.92 89.48 359.64 3543.49 6015.14N 4890.40E 1.71 6314.43 554739.74 5966566.52 10351.45 88.00 0.12 3545.63 6112.65N 4890.20E 1.60 6411.72 554738.89 5966664.01 10448.36 88.62 355.47 3548.49 6209.42N 4886.47E 4.84 6508.06 554734.52 5966760.74 10543.66 88.65 0.61 3550.76 6304.60N 4883.21E 5.39 6602.84 554730.63 5966855.89 10640.29 86.78 358.81 3554.61 6401.15N 4882.72E 2.68 6699.16 554729.50 5966952.42 10737.67 86.59 358.65 3560.24 6498.34N 4880.57E 0.25 6796.02 554726.70 5967049.59 10834.03 84.28 358.23 3567.91 6594.35N 4877.96E 2.44 6891.67 554723.45 5967145.57 10931.09 88.53 1.28 3574.00 6691.19N 4877.55E 5.39 6988.28 554722.40 5967242.39 11027.72 89.33 2.45 3575.80 6787.74N 4880.69E 1.47 7084.84 554724.90 5967338.96 11127.28 89.94 5.44 3576.44 6887.06N 4887.54E 3.07 7184.39 554731.09 5967438.30 11222.81 91.44 2.91 3575.29 6982.31N 4894.49E 3.08 7279.90 554737.41 5967533.60 11320.91 88.19 4.15 3575.61 7080.21N 4900.53E 3.55 7377 .98 554742.80 5967631.52 11415.35 88.53 6.19 3578.31 7174.22N 4909.04E 2.19 7472.34 554750.68 5967725.58 11512.80 88.59 4.00 3580.76 7271.25N 4917.69E 2.25 7569.73 554758.69 5967822.65 11609.07 88.86 7.31 3582.90 7367.02N 4927.17E 3.45 7665.90 554767.53 5967918.47 11706.68 87.48 7.15 3586.02 7463.80N 4939.45E 1.42 7763.27 554779.17 5968015.32 11799.96 88.16 7.24 3589.57 7556.28N 4951.13E 0.74 7856.30 554790.22 5968107.87 11893.12 88.56 7.94 3592.23 7648.58N 4963.43E 0.87 7949.20 554801.91 5968200.24 11987,30 88.86 8.96 3594.35 7741.72N 4977.26E 1.13 8043.03 554815.13 5968293.45 12080.16 90.34 9.74 3595.00 7833.34N 4992.35E 1.80 8135.42 554829.60 5968385.16 12174.16 88.28 7.81 3596.13 7926.22N 5006.69E 3.00 8229.03 554843.32 5968478.13 12266.90 87.49 6.51 3599.55 8018.17N 5018.24E 1.64 8321.53 554854.26 5968570.15 12360,70 86.81 4.68 3604.22 8111.40N 5027.37E 2.08 8415.16 554862.77 5968663.43 12452.63 86.93 3.33 3609.24 8202.97N 5033.78E 1.47 8506.95 554868.58 5968755.03 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10418.87 Feet on azimuth 29.22 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated conoccjÃ,illips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb.123 L 1 Wellpath: MWD wI Mag&Sag <7771 - 13345'> Date Printed: 21-Jun-2004 .~. a.œdl.s INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionrftl 12546.62 88.77 3.80 3612.76 8296.71N 5039.62E 2.02 8600.87 554873.79 5968848.79 12637.60 88.68 1.75 3614.79 8387.55N 5044.02E 2.25 8691.81 554877 .59 5968939.66 12726.91 86.68 2.48 3618.41 8476.73N 5047.32E 2.38 8781.01 554880.29 5969028.84 12816.74 86.14 2.95 3624.03 8566.28N 5051.56E 0.80 8870.65 554883.94 5969118.41 12908.40 86.19 4.16 3630.16 8657.56N 5057.23E 1.32 8962.10 554889.01 5969209.71 12999.16 88.41 3.28 3634.43 8748.02N 5063.12E 2.63 9052.75 554894.29 5969300.20 13088.94 88.68 3.60 3636.72 8837.60N 5068.50E 0.47 9142.50 554899.08 5969389.82 13180.01 88.22 4.66 3639.18 8928.40N 5075.06E 1.27 9233.54 554905.03 5969480.65 13271.85 90.22 3.25 3640.43 9020.01 N 5081.39E 2.66 9325.36 554910.75 5969572.29 13292.84 90.92 3.94 3640.22 9040.96N 5082.71E 4.68 9346.35 554911.93 5969593.24 13345.00 90.92 3.94 3639.38 9092.99N 5086.29E 0.00 9398.50 554915.17 5969645.29 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10418.87 Feet on azimuth 29.22 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJ¡)¡,¡llips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb.123 L 1 Well path: MWD wI Mag&Sag <7771 - 13345'> Date Printed: 21-Jun-2004 rei. "Au INTEQ Comments MOfftl I TVDfftl I Northfftl I Eastfftl I Comment 7640.00 3495.83 3412.42N 4737.77E DTop 13345.00 3639.38 9092.99N 5086.29E Proiected Data - NO SURVEY Hole Sections Oiameter Start Start Start Start End End End Start Wellbore [inl MDfftl TVDfftl Northfftl Eastfftl MDfftl TVDfftl Northfftl Eastfftl 24.000 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 123 PB1 131/2 108.00 108.00 O.OON O.OOE 3705.00 2210.15 1017.06N 2176.76E 123 PB1 97/8 3705.00 2210.15 1017.06N 2176.76E 8047.00 3574.49 3815.02N 4771.58E 123 PB1 63/4 7670.00 3503.51 3441.31N 4740.34E 13345.00 3639.38 9092.99N 5086.29E 123 L1 Ç!asinQs Nðm.e Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDfftl TVDfftl Northfftl Eastfftl MDrftl TVDfftl Northfftl Eastfftl 20" Conductor 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 123 PB1 103/4" CasinQ 0.00 0.00 O.OON O.OOE 3694.00 2206.33 1012.83N 2167.35E 123 PB1 7 5/8" CasinQ 0.00 0.00 O.OON O.OOE 8042.00 3573.99 3804.99N 4768.18E 123 PB1 4 1/2" x 3 1/2" 7689.00 3508.10 3459.67N 4741.96E 13327.00 3639.67 9075.03N 5085.05E 123 L 1 Slotted Liner All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10418.87 Feet on azimuth 29.22 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Re: New West Sak Producing Wells . . Subject: Re: New West Sak Producing Wells From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 06 Jul2004 06:25:50 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> dO~-O~~ à o\.-.\. - 0'\ S- Jerry, OC'\C I looked at our 407 list and I don't show that we have received ~ on this well yet. I would suggest that the 407 reflect that the well was completed as a producer on gas lift. When the switch to ESP is made, then you can send the 404 as you plan. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: .~ š: \ ~ - \ d-~ '-1- Tom: 1E-123 (PTD 2040740) is a new West Sak ESP producing well. The well has been completed but the surface facilities are not yet complete. Until all the electrical systems are in place the ESP pump cannot be operated. Operations wants to temporarily operate the well on gaslift production until the facilities are completed, which are not expected to be ready until the November time frame. There may be an additional 4 or 5 wells completed during the interim that will have the same issue. What kind of notification, if any, do you want to have to bring these wells on line with gaslift, and then report the change with the swap to ESP production? The situation does not fit in any particular category on the proposed matrix we were discussing the other day. As a suggestion, may I propose an email notification when the well is brought on line on gaslift, followed by a 10-404 when the swap is made to ESP? It will be a week or so before 1E-123 is ready so whatever we do right now can be used as a model for the remaining wells. Thanks for your feedback. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 1 of 1 7/6/20048:30 AM Re: Change in Procedure on lE-123, lE-123Ll, Permits # 204-074,... - e Subject: Re: Change in Procedure on 1E-123, 1E-123L1, Pennits # 204-074, 204-075 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 10 JUll 2004 11:27:43 -0800 To: "McKeever, Steve" <Steve.McKeever@conocophillips.com> CC: "Ennis, J J" <J.J.Ennis@conocophillips.com> Steve, What you describe is how did the completions back when reasoning is to use a "better tool" and one whose crew ESPs. 3S is up and running so there should not be any proposal is acceptable. Please be sure that the rig contacts the Inspectors for the 3S BOP test. place a copy of this message in the well file. Please call with any questions. Tom Maunder, PE AOGCC I was in Kuparuk. Your has more experience running start up issues. Your I wi 11 McKeever, Steve wrote: Hi Tom- With regard to our conversation yesterday, listed below is the revised drilling procedure we are proposing for the completion of 1E-123 & 1E-123L1, the dual lateral well currently under construction. The approved Applications for Permit to Drill indicated that the final ESP completion would be run by Doyon #141. We would like to take advantage of the availability of a lower cost rig, Nabors 3s, to run that final completion. The configuration of that final completion will be as permitted; only the steps to get it into the ground have changed. At the current time, 10 am, June 10, the operation underway at the rig is Step # 4 below. The upper liner is in place and the drill pipe is being laid down. If this change in procedure is acceptable to the AOGCC without further documentation, can you please so indicate with a return e-mail to me? Thanks, Steve Revised Drilling Procedure for 1E-123 and 1E-123L1: 1. PU and run 4-1/2" slotted liner. 2. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 3. Release hanger running tool. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. 4. POOH, laying down drill pipe as required. 5. RIH with 4-1/2" open ended tubing with one gas lift mandrel (loaded with dummy valve) to window depth less 50 feet. Land tubing. Set BPV. 6. Freeze protect 10-3/4" x 7-5/8" annulus with diesel. 7. Nipple down BOPE, nipple up tree and test. Pull BPV. 8. Move Doyon Rig 141 off the well. Nabors 3s Rig Operations: 9. Move in and rig up Nabors Rig 3s. Nipple down tree, nipple up and test 13-5/8" x 5ksi RRA BOP stack. 10. Pull BPV. Circulate bottoms up. POOH with tubing, standing back. 11. Make up ESP drive section (motor only, no pump), other completion equipment as required and RIH to setting depth. Make up tubing hanger and land tubing. Set BPV. 12. Nipple down BOPE and nipple up and test tree. 13. Freeze protect tubing and tubing annulus with diesel. Post Rig Well Work Operations: 14. Rig up wire line unit. Pull BPV 15. Set gas lift valves in mandrels. Operate well on gas lift for ± 180 days. 10f2 6/1 0/2004 11 :27 AM Re: Change in Procedure on lE-I23, lE-I23Ll, Permits # 204-074,... e e 16. Replace gas lift valves with blank dummy valves. 17. Run ESP through tubing. 18. Operate well with ESP. Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 steve. md::eever@conocophillps . com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 "One of the reasons people stop learning is that they become less and less willing to risk failure." - John W. Gardner 20f2 6/1 0/2004 11 :27 AM · e FRANK H. MURKOWSKI, GOVERNOR AI1A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279'1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL NO. 406A.01 Mr. Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 ;)()L{~. 015 Re: Spacing Exception for Kuparuk River Unit lE-123Ll Well Dear Mr. Thomas: On May 17, 2004, the Alaska Oil and Gas Conservation Commission ("Commission") received your correspondence dated May 15, 2004 requesting a waiver of spacing requirements for drilling and operation of the Kuparuk River Unit ("KRU") lE-123Ll oil production well. This well will lie entirely within state leases ADL 025651 and ADL 025648, and more than 300 feet from any property lines where ownership changes. The productive interval of KRU lE-123Ll will lie within the West Sak "D" sand, and will approach within 310 feet of existing well KRU 1 B-1 OIL 1, which is also open to the West Sak D sand. Conservation Order 406A ("CO 406A") governs the West Sak Oil Pool within the Kuparuk River Unit. Rule 3 of CO 406A states: "Nominal spacing units within the pool will be 10 acres. The pool shall not be opened in any well closer than 300 feet to an external boundary where ownership changes." An exception to the spacing requirements of Rule 3 is required as KRU 1 E-123L1 will open the pool in the same 10-acre spacing unit as existing well KRU 1 B-1 01 L1. Rule 13 of CO 406A states: "Upon proper application, the Commission may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste, jeopardize correlative rights, and is based on sound engineering and geoscience principles." Administrative approval is appropriate for a waiver of well spacing requirements specified in CO 406A. Notice and public hearing are not required for this spacing exception application as KRU lE-123LI will lie entirely within unitized State leases ADL 025651 and ADL 025648, which are committed to the West Sak Participating Area, and will be located more than 300 feet from any property lines. Correlative rights will not be jeopardized. · e Mr. R. Thomas May 20, 2004 Page 2 of2 The Commission has determined drilling and operation of the KRU lE-123Ll well is based on sound engineering and geoscience principles, will enhance recovery, will not promote waste or jeopardize correlative rights, and will not result in an increased risk of fluid movement into freshwater. The Commission hereby approves the drilling and operation of the Kuparuk River Unit lE-123Ll well as proposed. DONE at Anchorage, Alaska and dated May 20,2004. a ~ohn¡K.~rman, Clì r ~rI1lSSlOner ~~.~¿JoJL rGi;I-f)SdãJíount, Jr. ~8'-- Commissioner $ þ.o }(')~ ;)! <../0 P v...-. . . FRANK H. MURKOWSKI, GOVERNOR AI,J\SKA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-123Ll ConocoPhillips Alaska, Inc. Permit No: 204-075 Surface Location: 933' FSL, 630' FEL, SEC. 16, TIIN, RlOE, UM Bottomhole Location: 528' FNL, 909' FEL, SEC. 10, TUN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom 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 KRU lE-123, permit #204-074 and API #50:- 029-23208-00. Production should continue to be reported as a function of the original API number stated above. 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. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). BY ORDjJ....... "f THE COMMISSION DA TED~~Y of month, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .. ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 17, 2004 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, lE-123 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well bore, the upper lateral well bore of a multilateral horizontal well, in the West Sak "D" sand. The main bore of this well will be designated lE-123 and has been permitted under a separate application, submitted on May 5, 2004. This application is for the upper lateral of that well, to be designated lE-123L1. The expected date that operations will begin on lE-123L1 is May 25, 2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve McKeever at 265-6826 if more information is needed to issue a Permt to Drill for lE- 123L1. Sincerely, ~~ Randy Thomas GKA Drilling Team Leader ?~ECEI\/ED -I, ~ 7 2004 Alaska Oil & Gas Cons., \,;ummission Anchorage ORIGINAL 1 a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED AI'I!!':c.~ :n~~~:m~1 \\ ExploratoryU Development Oil ~ Am~horag~UltiPle Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1 E-123L 1 6. Proposed Depth: 12. Field/Pool(s): 13215' MD 3674' TVD Kuparuk River Field 7. Property Designation: RedrillU 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 933' FSL, 630' FEL, Sec. 16, T11 N, R10E, UM Top of Productive Horizon: 924' FNL, 1169' FEL, Sec. 15, T11N, R10E, UM Total Depth: 528' FNL, 909' FEL, Section 10, T11N, R10E, UM 4b. Location of Well (State B.ase Plane Coordinates): ?"ýC¡ fflÓ ~Þ.,1i 5,7~..o .5ZL'.> Surface: x- .0660301 ç,¡-1t. '1- 59W781 Zone- 4 (Height above GL): 28' RKB 16. Deviated wells: t;1.1 þ.Þ¡ 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff depth: 7526 ft. Maximum Hole Angle: ~f 11·<''( Max. Downhole Pressure: 1834 psig 18. Casing Program Setting Depth Size Specifications Top Weight Grade Coupling Length MD TVD 94# K-55 Weld 80' 28' 28' 45.5# L-80 BTC 3832' 28' 28' 29.7# L-80 BTCM 7874' 28' 28' 12.6 L-80 Grant 5689' ~.,~ 1"5").1,.; '~St,U PRESENT WELL CONDITION SUMMAR" í~lf\ Sf \s (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (It): Plugs (measur!!fiP . I ~ffective Depth MD (It): Effective Depth TVD (It): Junk (measured) Length Size Cement Volume MD TVD Hole Casing 42" 20" x 34" 13.5" 10.75" 9-7/8" 7-5/8" 6.75" 4.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat ALK 25651 & 25648 8. Land Use Permit: ADL 469 & 466 9. Acres in Property: 2560 10. KB Elevation Bottom MD 108' 3860' 7902' 13215' [J wJ BOP SketchD o Diverter Sketch 0 I Perforation Depth TVD (ft): Drilling Program~ Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature West Sak Pool 13. Approximate Spud Date: 5/14/2004 14. Distance to Nearest Property: 908" @ TD 15. Distance to Nearest Well Within Pool: 18-101/144' @ 13199' TVD 108' 2200' 3474' 3679' I Max. Surface Pressure: 1422 psig Quantity of Cement c. f. or sacks (including stage data) 260 cf ArcticCrete 770 sx AS Lite, 180 sx DeepCrete 160 sx DeepCrete slotted liner Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 R. Thomas Contact Steve McKeever @ 265-6826 Title Kuparuk Drilling Team Leader Phone z..~.f' b ß Si> Date '!i 1'(') lø Y ~~ \. ~. Commission Use Only Permit to Drill I API Number: I Permit APpro~a/ Number: ;2Ocj-C)¡Ç" 50- C>7-C7·-232...Df~""~l) Date: 5/,~/0'f Conditions of approval: Sam les required 0 Yes ~ No Mud log required aro en sulfide measures 0 Yes J8l No Directional survey required Other: '-;;> ""'. ';-',---- ,,\ ,,""-' '-.i x~\:::> Ü~· \-'é'.S ""\'"" COMMISSIONER BY ORDER OF THE COMMISSION Form 1 0-401 Revised 3/2003 . ORIGINAL PreDared bv Sharon AI/suo-Drake Isee cover letter for other requirements ld Yes IS? No A Yes 1]- No Date: 11ft ~ Submit in duplicate · Aeon for Permit to Drill, WeIl1E-123L1 Revision No.O Saved: 14-May-04 Permit It - West Sak Well #1 E-123L 1 Application for Permit to Drill Document M(JximizE Well l/oll,I~ Table of Contents 1. Well Name..... ................. ................................................. ...................... ......... ........... 2 Requirements of 20 AAC 25.005 (f)... ............................. ........................................................................ 2 2. Location Su mmary .. ............ ............................ ...... .... ........... ...................... .......... .... 2 Requirements of 20 AAC 25.005(c)(2) ................... ......... ................. ............ .......... ......... ............ ........... 2 Requirements of 20 AAC 25. 050(b)................................................................ .................... ......... ........... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005( c)(3) ..... .................................... .............................. .................. .......... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) .... ............ .................................................................. ...... .... ....... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) .............. .................................. ..... ....... ..... ............. ..................... 4 8. Drilling FI uid Program .............................................................................................5 Requirements of 20 AAC 25.005(c)(B) ..... ............................................................. ....................... .......... 5 Lateral Mud Program (MI FloPro NT) ............. ...... ......................................................... .................. ....... 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 1 O. Seism ic Analysis..... ............ ............ ....... ..... ........ ................ .................... ......... ........ 5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL 1 E-123L 1 PERMIT IT Rev2. doc Page 1 of 7 Printed: 14-May-04 · Aetion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 14-May-04 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7 15. Attach ments ................ ..... ....... .............. ...... ................ ........ ........ ... ..... .......... ... ........ 7 Attachment 1 Directional Plan (8 pages) ................................................................................................ 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Well Schematic (1 pages) ...............................................................................................7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by t/le operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must simllady be identified by a unique name and API number by adding a suftìx to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as lE-123L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file wIth the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of t!le well at the surface, at the top of each objective formation and at total depth, referenæd to govemmental sectionlines. (8) the coordinates of the proposed location of the well at the surface; referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUl1ieY in the National Oceanic and Atmospheric Administrat]()n;, (C) the proposed depth of the weli at tIle top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,960,520 Eastings: 549,890 933' FSL, 630' FEL, Section 16, T11N, Rl0E, UM I RKB Elevation I 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,963,975 Eastings: 554,600 924' FNL, 1169' FEL, Section 15, T11N, Rl0E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7,526 3,500 3,401 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,969,652 Eastings: 554,810 528' FNL, 909' FEL, Section 10, T11N, RlOE, UM Measured Depth, RKB: 13,215 Total Vertical Depth, RKB: 3,674 Total Vertical Depth, 55: 3,575 and (D) at/IeI' information required by 20 MC 25.050(b); ORIGINAL 1E-123L1 PERMIT IT Rev2.doc Page2of7 Printed: 14-May-04 · Aetion for Permit to Drill, We1l1E-123L 1 Revision No.O Saved: 14-May-04 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Driil (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbor~ including all adjacent wellbores within 200 feet of any portion of the proposed well/ Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of me proposed well bore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record", and show that each named operator has been furnished a copy of me application by certified mall; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item", except for an item already on file wim the commission and identified in the application: (3) a diagram and descliption ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 AAC 25.036, or 20 MC 25.037; as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well lE-123Ll. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of me following item", except for an item already on file with the commission and identified in the application: (4) information on drilling hazard", including (A) the maximum downhole pressure that may be encounterec1r criteria used to determine it, and maximum potential surface pressure based on a methane gradient," The expected reservoir pressures in the West Sak sands in the lE-123L1 area vary from 0.42 to 0.49 psi/ft, or 8.1 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1,422 psi, calculated thusly: MPSP =(3,742 ft)(0.49 - 0.11 psi/ft) =1,422 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone", and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application tor a Permit to DJiII must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting tormatlon integrity test", as required under 20 MC 25. 030(f}/ The parent wellbore,lE-123, will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. ORIGINAL 1E-123L1 PERMIT IT Rev2.doc Page 3 of 7 Printed: 14-May-04 · A.tion for Permit to Drill, We1l1E-123L1 Revision No.O Saved: 14-May-04 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on tìle wIth the commission and Identífíed in the applícation: (6) a complete proposed casing and cementing program as required by 20 AAC 25.03~ and a description of any slotted line;; pre- perforated line;; or screen to be installect· Casing and Cementing Program See also Attachment 3, APD for 1E-123: Cement Summary Hole Size (in) 42 6-3/4" Lower Lateral (lE-123) 4-1/2 6-3/4" slotted Upper Lateral (lE-123 L1) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fol/owing item~ except for an Item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2)/ Csgffbg OD (in) 20 X 34 10-3/4 13-1/2 7-5/8 9-7/8 4-1/2 slotted Weight (Iblft) 94 Top MD/TVD (ft) 28 / 28 Btm MD/TVD (ft) 108 / 108 Grade Connection Welded Length (ft) 80 K55 45.5 L-80 BTC 28 / 28 3832 3860 /2200 29.7 L-80 BTCM 28 / 28 7874 7902/ 3474 12.6 L-80 Grant Prideco DWCjC 7566/ 3510 13,345 / 3742 5779 12.6 L-80 Grant Prideco DWC/C 75261 3500 5689 13215 1 3674 No diverter system will be utilized during operations on 1E-123L1 Cement Program Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 770 sx AS Lite Lead, 180 sx DeepCRETE Tail Cement Top planned @ 7000' MD / 3348'1VD. Cemented w/ 160 sx DeepCRETE Slotted- no cement Slotted- no cement 1 E-123L 1 PERMIT IT Rev2.doc Page 4 of 7 Printed: 14-May-04 ORIGINAL · Aetion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 14-May-04 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to DriN must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid prograrn including a diagram and description of the drilling fluid system, as required by 20 AAC 2,50033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI FloPro NT) BID sand laterals Initial Value Final Value 9.7 9.7 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) Tau 0 Chlorides (mgll) pH API filtrate (cc 130 min) **HTHP filtrate (cc 130 min) MBT (Ib I gal) ***Solids (% Vol) 22-30 22-30 8-12 8-12 4-7 4-7 65-80K 65-80K 8-9.5 8-9.5 <6 <6 <10 <10 <5 <5 <6-9 <6-9 .. HTHP to be run at 80° F'" The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the foilowing Items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Pemlit to Drill must be accompanied by each of the following items, except for an item already on file with the commis...';íon and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: ORIGINAL 1E-123L 1 PERMIT IT Rev2.doc Page 5 of 7 Printed: 14-May-04 · Aetion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 14-May-04 (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drlllt/¡g vessel, an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commis.<;iofl and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an Item already on file with the commission and identified in the applkation: The proposed drilling program for lE-123 L1 is listed below. Please refer also to Attachment 5, Well Note: Previous operations are covered under the 1E-123 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7,526' MD / 3,500' TVD, the top of the D sand. 2. Displace hole to used mud from lower later~1 ~tk:? Æ~; Millt:/4.5~n~w·Å~~"" 1/4 s-: /o.c::.'/" ß/'J 3. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. ç, no'( 4. Displace to new drilling mud at 9.7 ppg. Drill to TD of D sand lateral at 13,215' MD /3,674' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. 10. POOH, laying down drill pipe as required. 11. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Set BPV and move rig off. 14. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Rig up wire line unit. Pull BPV 16. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 17. Replace gas lift valves with dummies. 18. Run ESP through tubing. 19. Operate well with ESP. ORIGINAL 1 E-123L 1 PERMIT IT Rev2.doc Page 6 of 7 Printed: 14-May-04 · Aetion for Permit to Drill, Well 1 E-123L1 Revision No.O Saved: 14-May-04 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following item~ except for an item already on fíle with the commission and Identifíed in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20AAC 25,080 for an annular disposal operation in the wel/.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan (11 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Well Schematic (1 pages) ORIGINAL 1 E-123L 1 PERMIT IT Rev2.doc Page 7 of 7 Printed: 14-May-04 -AnocoPhillips Alaska, -&:- -.. ..,. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #123 Well: 123 Wellbore: 1E-123 Scale 1 em = 350 ft East (feet) -> 1400 2100 2800 3500 4200 4900 5600 6300 7000 7700 8400 9100 9800 10500 11900 -700 700 o 1 E-123L 1 TD LOCATION: 529' FNL, 909' FEL SEC.10,T11N,R10E 1E-123 TD LOCATION: ] 404' FNL, 908' FEL I SEC. 10, T11N, R10E I TD,4 1/2 Liner PI. N -<, 0'\ N 0' N -< ~, M TOP WEST SAK LOCATION: 925' FNL, 1169' FEL SEC. 15,T11N, R10E SURFACE LOCATION: 933' FSL, 630' FEL SEC. 16,T11N, R10E ~ 1r..7,] 0,1:::1 1::1). 'b' 1'0 !1 <'a "J 7;Sfil '/J U. '0' Þ. ~ 0,0 (i.fob~(¡ -1 l¡~,o )'; 1'0 °c '91¡(¡ ¡f(¡1}¡, <'11¡.96' '/Ju. '/J)'; 'l}t ð Ì'rl¡ '91¡(¡ <'11¡.9.' Q"/Q'/)) ,]/7a C el¡f I't¡ </. '0 V700 / ~ 70 7;0 ,]/A. '/J '- 7'11¡ '1'7$ Cil. ;s'11¡.9 1'0 b7J ~ Sil '/J 1:.,] 1::0 ;s'& Þ. S/Q' C &'0. ki S/Q'" 6/7.a ëlJ?o 0,0 ù/700'O ;s'f ORIGINAL ConocJ'Phillips Created by: Planner Date plotted: 13-May-2004 Plot reference is 1 E-123. Refwellpath is 1E-123 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. ~ 11200 ~ 10500 9800 9100 8400 7700 7000 6300 ^ I Z 5600 0 ~ ::r - - 4900 m - - 4200 3500 2800 2100 1400 700 en () II) CD 0 () 3 II -700 w 01 0 ;::þ o :::0 - GJ - ~ ~ n 3350 (/) _ 3400 - () J!! :; 3450 - Q, () C 3500 cu (,) :e 3550 () > () 3600 :::s ... l- I V 3650 3700 ConocoPhillips Alaska, Inc. :\ Ij) ?JI'I1j) 'ò'2.~ ~\Ò. ?JI~'I y;.oV \)~"Q ~ 'ò'ò~___.__'..-4._-'" ~\òb.\'IçJ;) C. ~I ... 1~~ i I --1 'J.. S'ò-'V- 'ò?J9() ~ ~0"Q -..r-IeS c.'ò-'¿'\'(I~ ~\'Ò\'(I 1 ø:»"~ (j:)~ ,,-.r:.. 0\..""· INTEQ Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E fòl'llj) ~\ò _'I'2.?J,~~"(Io\e. \0 'I ~\\'\~'eö v"Q'ð ~\e«;¡~~Ò~~\ .. y;.oV 3650 3700 3750 3800 3850 Scale 1 cm = 25 ft Slot: Slot #123 Well: 123 Wellbore: 1E-123 y;.cß~'2. 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 Vertical Section (feet) .> Azimuth 3.65 with reference 0.00 N, 0.00 E from Slot #123 Conoc~illips Created by : Planner Date plotted: 22,Apr,2004 Plot reference is 1 E,123. Ref wellpath is 1 E-123 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: gg.OO It. Plot North is aligned to TRUE North. 4500 4550 4600 4650 4700 . . --6 1E-123 > 4750 ConocoPhillips Alaska, Inc. BA Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #123 Well: 123 Wellbore: 1E,123 Conoc~hillips INTEQ Created by : Planner Date plotted: 13-May-2004 Plot reference is 1E-123. Refwellpath is 1E-123 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. . o :::0 - (J) - Z "" 2750 » '" ;:! " r- j 3000 .... :; 3250 - ~3500-R - 1E-123 > ":J.'I.\S} ~~ -,_.~------~ <:(I.. "IS) 'oJ."çf:; \ß,e\ -~--~ __~ ø'~ <j~'a' . .. ,~._------ . .. .It ,,,,~'!i.,,IS)<#J';Jc# '":J,,,çf:; # "IS) # <tv 11E-123 ~~' .~~ .>«..~i '(\fèJ. ifl'" '?J'" 'I.'(l- \) ~.b. e (ij c.> ~ 3750 () > () 4000 ~ ... l- I V 4250 4500 ":J.'I.\S}# Çf-~ 4500 4750 5000 5250 5500 Scale 1 em = 125 ft 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 Vertical Section (feet) -> Azimuth 3.65 with reference 0.00 N, 0.00 E from Slot #123 8750 9000 9250 9500 9750 10000 ConocóPhillips ConocoPhillips Alas.nCo,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSA.STING Page 1 Wellbore: 1 E-123L 1 Wellpath: 1 E-123L 1 Ver#3a Date Printed: 13-May-2004 '&1. BAKER HUGHES INTEQ I Created 29-Jan-2004 123 Installation Name Pad 1E I Coord Svstem Name North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True I Eastina 487754.6208 Field KUDaruk River Unit I Coord Svstem Name I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method PÕaR l 81 ~ÃI[rporated ConocriPhillips ConocoPhillips Alas.nc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSA.STING Page 2 Wellbore: 1 E-123L 1 Well path: 1 E-123L 1 Ver#3a Date Printed: 13-May-2004 "1. BAKER HUGHES INTEQ 0.00 0.00 0.00 0.00 -99.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 1.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 200.00 0.00 0.00 200.00 101.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 300.00 0.00 0.00 300.00 201.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 End of Hold 400.00 3.00 65.00 399.95 300.95 1.11N 2.37E 5960521.12 549892.36 3.00 1.26 500.00 6.00 65.00 499.63 400.63 4.42N 9.48E 5960524.48 549899.45 3.00 5.02 600.00 9.00 65.00 598.77 499.77 9.94N 21.31 E 5960530.08 549911.24 3.00 11.27 633.33 10.00 65.00 631.64 532.64 12.26N 26.30E 5960532.44 549916.21 3.00 13.91 Bid 5/100. End of BuildfTurn 733.33 15.00 65.00 729.24 630.24 21.41 N 45.91 E 5960541.71 549935.76 5.00 24.29 833.33 20.00 65.00 824.58 725.58 34.11 N 73.15E 5960554.59 549962.92 5.00 38.70 Bid 6/100, End of Build 933.33 26.00 65.00 916.59 817.59 50.62N 108.55E 5960571.33 549998.20 6.00 57.43 1033.33 32.00 65.00 1004.01 905.01 71.10N 152.47E 5960592.10 550041.98 6.00 80.66 1133.33 38.00 65.00 1085.89 986.89 95.33N 204.43E 5960616.67 550093.77 6.00 108.15 1233.33 44.00 65.00 1161.33 1062.33 123.04N 263.86E 5960644.78 550153.01 6.00 139.60 1333.33 50.00 65.00 1229.50 1130.50 153.93N 330.11E 5960676.11 550219.05 6.00 174.65 1433.33 56.00 65.00 1289.65 1190.65 187.67N 402.46E 5960710.32 550291.16 6.00 212.92 1533.33 62.00 65.00 1341.13 1242.13 223.88N 480.11E 5960747.04 550368.56 6.00 254.00 1633.33 68.00 65.00 1383.37 1284.37 262.16N 562.21E 5960785.86 550450.40 6.00 297.44 1641.50 68.49 65.00 1386.40 1287.40 265.37N 569.09E 5960789.11 550457.25 6.00 301.08 EOC, End of Build 1700.00 68.49 65.00 1407.85 1308.85 288.37N 618.41E 5960812.44 550506.42 0.00 327.17 1800.00 68.49 65.00 1444.52 1345.52 327.69N 702.73E 5960852.31 550590.47 0.00 371.78 1900.00 68.49 65.00 1481.18 1382.18 367.01 N 787.05E 5960892.19 550674.52 0.00 416.39 2000.00 68.49 65.00 1517.85 1418.85 406.32N 871.37E 5960932.06 550758.56 0.00 461.00 2100.00 68.49 65.00 1554.52 1455.52 445.64N 955.69E 5960971.94 550842.61 0.00 505.61 2200.00 68.49 65.00 1591.18 1492.18 484.96N 1040.01E 5961011.81 550926.66 0.00 550.22 2300.00 68.49 65.00 1627.85 1528.85 524.28N 1124.321;. 5961051.68 551010.71 0.00 594.83 2400.00 68.49 65.00 1664.52 1565.52 563.60N 1208.64E 5961091.56 551094.75 0.00 639.44 2500.00 68.49 65.00 1701.18 1602.18 602.92N 1292.96E 5961131.43 551178.80 0.00 684.05 2600.00 68.49 65.00 1737.85 1638.85 642.24N 1377.281;, 5961171.30 551262.85 0.00 728.66 2700.00 68.49 65.00 1774.51 1675.51 681.55N 1461.60E 5961211.18 551346.90 0.00 773.27 2800.00 68.49 65.00 1811.18 1712.18 720.87N 1545.92E 5961251.05 551430.94 0.00 817.88 2900.00 68.49 65.00 1847.85 1748.85 760.19N 1630.23F 5961290.92 551514.99 0.00 862.49 3000.00 68.49 65.00 1884.51 1785.51 799.51N 1714.55E. 5961330.80 551599.04 0.00 907.10 3100.00 68.49 65.00 1921.18 1822.18 838.83N 1798.87E 5961370.67 551683.08 0.00 951.71 3200.00 68.49 65.00 1957.85 1858.85 878.15N 1883.19F 5961410.54 551767.13 0.00 996.32 3300.00 68.49 65.00 1994.51 1895.51 917.47N 1967.51E 5961450.42 551851.18 0.00 1040.92, 3400.00 68.49 65.00 2031.18 1932.18 956.78N 2051.83E 5961490.29 551935.23 0.00 1085.53 3500.00 68.49 65.00 2067.84 1968.85 996.10N 2136.15F 5961530.16 552019.27 0.00 1130.14 3600.00 68.49 65.00 2104.51 2005.51 1035.42N 2220.47E. 5961570.04 552103.32 0.00 1174.7~ 3700.00 68.49 65.00 2141.18 2042.18 1074.74N 2304.78E 5961609.91 552187.37 0.00 1219.36 3800.00 68.49 65.00 2177.84 2078.84 1114.06N 2389.10F 5961649.79 552271.42 0.00 1263.97 3860.43 68.49 65.00 2200.00 2101.00 1137.82N 2440.06E 5961673.88 552322.21 0.00 1290.92 3900.00 68.49 65.00 2214.51 2115.51 1153.38N 2473.42E 5961689.66 552355.46 0.00 1308.58 4000.00 68.49 65.00 2251.18 2152.18 1192.69N. 2557.741;, 5961729.53 552439.51 0.00 1353.1~ 4100.00 68.49 65.00 2287.84 2188.84 1232.01N 2642.06E 5961769.41 552523.56 0.00 1397.8C 4200.00 68.49 65.00 2324.51 2225.51 1271.33N 2726.381; 5961809.28 552607.61 0.00 1442.41 4300.00 68.49 65.00 2361.18 2262.18 1310.65N 2810.70E 5961849.15 552691.65 0.00 1487.0" 4400.00 68.49 65.00 2397.84 2298.84 1349.97N 2895.01E 5961889.03 552775.70 0.00 1531.6~ 4500.00 68.49 65.00 2434.51 2335.51 1389.29N 2979.33E 5961928.90 552859.75 0.00 1576.24 All data is in Feet,imless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method prrrRbl BGel ~hA[Porated Conocó'Phillips ConocoPhillips Alas.nCo,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAaTING Page 3 Wellbore: 1 E-123L 1 Well path: 1 E-123L 1 Ver#3a Date Printed: 13-May-2004 Rií. BAKER HUGHES INTEQ 4600.00 68.49 65.00 2471.18 2372.17 1428.61N 3063.65E 5961968.77 552943.80 0.00 1620.85 4700.00 68.49 65.00 2507.84 2408.84 1467.92N 3147.97E 5962008.65 553027.84 0.00 1665.4Q 4800.00 68.49 65.00 2544.51 2445.51 1507.24N 3232.29E 5962048.52 553111.89 0.00 1710.07 4900.00 68.49 65.00 2581.17 2482.17 1546.56N 3316.61E 5962088.39 553195.94 0.00 1754.68 5000.00 68.49 65.00 2617.84 2518.84 1585.88N. 3400.931;, 5962128.27 553279.99 0.00 1799.21,j¡ 5036.02 68.49 65.00 2631.05 2532.05 1600.04N 3431.30E 5962142.63 553310.26 0.00 1815.35 Trn 3/100. 3DXS Kick off Point 5100.00 68.34 62.94 2654.59 2555.59 1626.15N 3484.76E 5962169.09 553363.53 3.00 1844.81 5200.00 68.16 59.72 2691.65 2592.65 1670.70N. 3566.231;, 5962214.17 553444.71 3.00 1894.4Q 5300.00 68.04 56.49 2728.97 2629.97 1719.71N 3644.99E, 5962263.71 553523.13 3.00 1948.39 5400.00 67.98 53.25 2766.42 2667.42 1773.06N 3720.81E 5962317.55 553598.59 3.00 2006.46 5500.00 67.99 50.02 2803.92 2704.92 1830.59N. 3793.491;, 5962375.56 553670.88 3.00 2068.51 5600.00 68.06 46.78 2841.36 2742.36 1892.15N 3862.82E 5962437.57 553739.79 3.00 2134.35 5700.00 68.19 43.55 2878.63 2779.63 1957.57N 3928.62E 5962503.41 553805.14 3.00 2203.83 5800.00 68.38 40.33 2915.63 2816.63 2026.66N 3990.701;, 5962572.91 553866.76 3.00 2276.74 5844.49 68.49 38.90 2931.99 2832.98 2058.53N 4017.08E 5962604.96 553892.93 3.00 2310.23 EOC. End of Build/Tum 5900.00 68.49 38.90 2952.34 2853.34 2098.73N 4049.51E 5962645.36 553925.09 0.00 2352.40 6000.00 68.49 38.90 2989.00 2890.00 2171.13N 4107.941;, 5962718.14 553983.02 0.00 2428.31,j¡ 6100.00 68.49 38.90 3025.67 2926.67 2243.54N 4166.36E, 5962790.93 554040.96 0.00 2504.36 6200.00 68.49 38.90 3062.33 2963.33 2315.94N 4224.78E 5962863.71 554098.89 0.00 2580.34 6300.00 68.49 38.90 3099.00 3000.00 2388.34N 4283.20F 5962936.49 554156.83 0.00 2656.32. 6375.48 68.49 38.90 3126.67 3027.67 2443.00N 4327.30E 5962991.43 554200.56 0.00 2713.67 Start 200' PumD Tanaent 6400.00 68.49 38.90 3135.66 3036.66 2460.75N 4341.63E 5963009.28 554214.76 0.00 2732.30 6500.00 68.49 38.90 3172.33 3073.33 2533.16N. 4400.051;, 5963082.06 554272.70 0.00 2808.28 6575.48 68.49 38.90 3200.00 3101.00 2587.81N 4444.15E 5963137.00 554316.43 0.00 2865.63 End 200' Pump Tangent, Bld/Trn 4/100, Ene of Hold 6600.00 68.58 37.85 3208.97 3109.97 2605.70N 4458.31F 5963154.98 554330.47 4.00 2884.38 6700.00 69.01 33.58 3245.16 3146.16 2681.37N 4512.72E 5963231.01 554384.37 4.00 2963.37 6800.00 69.54 29.34 3280.57 3181.57 2761.12N 4561.52E 5963311.08 554432.63 4.00 3046.07 6900.00 70.17 25.14 3315.02 3216.02 2844.57N 4604.47F 5963394.80 554475.03 4.00 3132.01,j¡ 7000.00 70.90 20.97 3348.35 3249.35 2931.31N 4641.38E 5963481.77 554511.35 4.00 3221.00 7100.00 71.73 16.84 3380.40 3281.40 3020.91 N 4672.05E 5963571.57 554541.42 4.00 3312.37 7200.00 72.64 12.74 3411.00 3312.00 3112.94N 4696.331;, 5963663.74 554565.10 4.00 3405.761 7300.00 73.64 8.70 3440.02 3341.02 3206.95N 4714.12E 5963757.86 554582.26 4.00 3500.71 7400.00 74.71 4.69 3467.30 3368.30 3302.48N 4725.32E 5963853.45 554592.82 4.00 3596.76 7426.09 75.00 3.65 3474.12 3375.12 3327.60N. 4727.161;. 5963878.58 554594.49 4.00 3621.94 EOC. End of Build/Turn 7500.00 75.00 3.65 3493.25 3394.25 3398.84N 4731.70E 5963949.85 554598.56 0.00 3693.3~ 7526.09 75.00 3.65 3500.00 3401.00 3423.99N 4733.31E 5963975.00 554600.00 0.00 3718.53 Top Whipstock Face, Tie to 1E-123, Tie on 7538.09 76.91 3.65 3502.91 3403.91 3435.61N 4734.05E 5963986.62 554600.66 15.90 3730.17 Base WhiDstock Face. End of Build 7556.09 76.91 3.65 3506.99 3407.99 3453.11 N 4735.17E, 5964004.13 554601.66 0.00 3747.71 End Milled Ooonhole. Bid 6/100. End of Holl 7656.09 82.91 3.65 3524.50 3425.50 3551.31N 4741.44E 5964102.37 554607.28 6.00 3846.11 7756.09 88.91 3.65 3531.64 3432.64 3650.81N 4747.781;, 5964201.89 554612.97 6.00 3945.81 775628 88.92 3.65 3531.64 3432.64 3651.00N 4747.80E 5964202.08 554612.98 6.00 3946.00Bld 3/100. 2DXS Kick off Point 7856.28 91.92 3.65 3530.91 3431.91 3750.78N 4754.17E 5964301.89 554618.69 3.00 4045.99 7856.34 91.92 3.65 3530.90 3431.90 3750.85N 4754.171;, 5964301.96 554618.69 3.00 4046.0~EOC. End of Build 7900.00 91.92 3.65 3529.44 3430.44 3794.39N 4756.95E 5964345.51 554621.18 0.00 4089.68 7992.61 91.92 3.65 3526.33 3427.33 3886.76N 4762.85E 5964437.91 554626.46 0.00 4182.24 Drop 3/100, End of Hold 8092.61 88.92 3.65 3525.60 3426.60 3986.54N 4769.211;, 5964537.73 554632.17 3.00 4282.2~EOC 8100.00 88.92 3.65 3525.74 3426.74 3993.92N 4769.68E 5964545.10 554632.59 0.03 4289.62- 8200.00 88.92 3.65 3527.62 3428.62 4093.70N 4776.05E 5964644.91 554638.29 0.00 4389.60 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method PreRared by Baker Hughes Incorporated ORIGINAL ConocriPhillips ConocoPhillips Alas.nCo,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAATING Page 4 Well bore: 1 E-123L 1 Wellpath: 1E-123L1 Ver#3a Date Printed: 13-May-2004 '&i. BAKER HUGHES INTEQ 8300.00 88.92 3.65 3529.51 3430.51 4193.48N 4782.42E 5964744.72 554644.00 0.00 4489.58 8400.00 88.92 3.65 3531.39 3432.39 4293.25N 4788.79e. 5964844.53 554649.70 0.00 4589.5~ 8500.00 88.92 3.65 3533.28 3434.28 4393.03N_ 4795.16E 5964944.34 554655.41 0.00 4689.55 8600.00 88.92 3.65 3535.16 3436.16 4492.81N 4801.52E 5965044.15 554661.11 0.00 4789.53 8700.00 88.92 3.65 3537.05 3438.05 4592.59N 4807.89E 5965143.96 554666.82 0.00 4889.51 8800.00 88.92 3.65 3538.93 3439.93 4692.37N 4814.26E 5965243.77 554672.52 0.00 4989.49 8900.00 88.92 3.65 3540.82 3441.82 4792.15N 4820.63E 5965343.58 554678.23 0.00 5089.47 9000.00 88.92 3.65 3542.70 3443.70 4891.93N 4827.001;. 5965443.39 554683.93 0.00 5189.4& 9100.00 88.92 3.65 3544.59 3445.58 4991.71N 4833.37E 5965543.20 554689.64 0.00 5289.44 9200.00 88.92 3.65 3546.47 3447.47 5091.49N 4839.73E 5965643.00 554695.34 0.00 5389.42 9300.00 88.92 3.65 3548.35 3449.35 5191.27N. 4846.101;. 5965742.81 554701.05 0.00 5489.4Q 9334.25 88.92 3.65 3549.00 3450.00 5225.44N 4848.28E 5965777.00 554703.00 0.00 5523.65 Drop 3/100, WS 1 E X5 D-MDPT#1 RVSD021804, 3DJ Kick off Point 9360.47 88.13 3.65 3549.67 3450.67 5251.60N 4849.95F 5965803.17 554704.49 3.00 5549.8G,EOC. End of DroDITurn 9400.00 88.13 3.65 3550.96 3451.96 5291.03N 4852.47E 5965842.61 554706.75 0.00 5589.37 9500.00 88.13 3.65 3554.22 3455.22 5390.77N 4858.83E 5965942.38 554712.44 0.00 5689.31 9600.00 88.13 3.65 3557.48 3458.48 5490.52N 4865.19F 5966042.15 554718.14 0.00 5789.2~ 9700.00 88.13 3.65 3560.73 3461.73 5590.26N 4871.55E. 5966141.93 554723.84 0.00 588921 9800.00 88.13 3.65 3563.99 3464.99 5690.01N 4877.90E 5966241.70 554729.53 0.00 5989.16 9900.00 88.13 3.65 3567.25 3468.25 5789.75N 4884.271;. 5966341.48 554735.23 0.00 6089.1Q 10000.00 88.13 3.65 3570.51 3471.51 5889.49N 4890.63E 5966441.25 554740.93 0.00 6189.05 10100.00 88.13 3.65 3573.76 3474.76 5989.24N 4896.98E 5966541.03 554746.62 0.00 6289.00 10200.00 88.13 3.65 3577.02 3478.02 6088.98N 4903.34e. 5966640.80 554752.32 0.00 6388.94 10300.00 88.13 3.65 3580.28 3481.28 6188.73N 4909.70E 5966740.58 554758.02 0.00 6488.89 10400.00 88.13 3.65 3583.53 3484.53 6288.47N 4916.06E 5966840.35 554763.71 0.00 6588.84 10500.00 88.13 3.65 3586.79 3487.79 6388.22N 4922.42F 5966940.13 554769.41 0.00 6688.7/?¡ 10600.00 88.13 3.65 3590.05 3491.05 6487.96N 4928.78E 5967039.90 554775.11 0.00 6788. 7~ 10700.00 88.13 3.65 3593.31 3494.31 6587.70N 4935.14E 5967139.67 554780.81 0.00 6888.68 10800.00 88.13 3.65 3596.56 3497.56 6687.45N. 4941.501;. 5967239.45 554786.50 0.00 6988.6~ 10900.00 88.13 3.65 3599.82 3500.82 6787.19N 4947.861:; 5967339.22 554792.20 0.00 7088.57 11000.00 88.13 3.65 3603.08 3504.08 6886.94N 4954.22E 5967439.00 554797.90 0.00 7188.52 11100.00 88.13 3.65 3606.34 3507.34 6986.68N. 4960.58e. 5967538.77 554803.59 0.00 7288.47 11200.00 88.13 3.65 3609.59 3510.59 7086.43N 4966.94E 5967638.55 554809.29 0.00 7388.41 11212.48 88.13 3.65 3610.00 3511.00 7098.88N 4967.74E 5967651.00 554810.00 0.00 7400.89 Bld/Tm 3/100, WS 1E X5 D-MDPT#2 RVSD021804. 3DJ Kick off Point 11300.00 88.63 1.07 3612.47 3513.48 7186.28N 4971.34E. 5967738.42 554813.02 3.00 7488.34 11327.60 88.78 0.25 3613.10 3514.10 7213.87N 4971.65E 5967766.01 554813.15 3.00 7515.90 EOC, End of Build/Turn 11400.00 88.78 0.25 3614.64 3515.64 7286.25N 4971.981;. 5967838.38 554813.00 0.00 7588.15 11500.00 88.78 0.25 3616.76 3517.76 7386.23N 4972.42E. 5967938.35 554812.78 0.00 7687.95 11600.00 88.78 0.25 3618.89 3519.89 7486.20N 4972.87E 5968038.32 554812.56 0.00 7787.76 11700.00 88.78 0.25 3621.01 3522.01 7586.18N. 4973.31F 5968138.28 554812.34 0.00 7887.5& 11800.00 88.78 0.25 3623.14 3524.14 7686.16N 4973.76E 5968238.25 554812.12 0.00 7987.3~ 11900.00 88.78 0.25 3625.27 3526.27 7786.13N 4974.20E 5968338.22 554811.90 0.00 8087.16 12000.00 88.78 0.25 3627.39 3528.39 7886.11 N 4974.65F 5968438.19 554811.68 0.00 8186.9~ 12100.00 88.78 0.25 3629.52 3530.52 7986.09N 4975.09E 5968538.15 554811.46 0.00 8286. 7~ 12200.00 88.78 0.25 3631.64 3532.64 8086.06N 4975.53E 5968638.12 554811.24 0.00 8386.57 12300.00 88.78 0.25 3633.77 3534.77 8186.04N 4975.98e. 5968738.09 554811.02 0.00 8486.37 12310.92 88.78 0.25 3634.00 3535.00 8196.95N 4976.03E 5968749.00 554811.00 0.00 8497.26 Drop/Tm 3/100, WS 1E X5 D-FL T1S RVSD031804, 3DS Kick off Point All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL Conocó'Phillips ConocoPhillips AlasenCo,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSA&TING Page 5 Wellbore: 1 E-123L 1 Wellpath: 1 E-123L 1 Ver#3a Date Printed: 13-May-2004 J&I_ BAKER HUGHES INTEQ 12371.18 86.98 0.39 3636.23 3537.23 8257.17N 4976.37E 5968809.21 554810.94 3.00 8557.38 EOC, End of Drop/Turn 12400.00 86.98 0.39 3637.75 3538.75 8285.95N.. 4976.57E 5968837.98 554810.95 0.00 8586.11 12500.00 86.98 0.39 3643.02 3544.02 8385.79N 4977.2.6E, 5968937.82 554810.97 0.00 8685.79 12600.00 86.98 0.39 3648.28 3549.28 8485.63N 4977.94E 5969037.65 554811.00 0.00 8785.47 12686.57 86.98 0.39 3652.85 3553.85 8572.06N 4978.541;. 5969124.07 554811.02 0.00 8871.7QBldlTrn 3/100. End of Hold 12700.00 87.38 0.34 3653.51 3554.51 8585.4 7N 4978.62E, 5969137.48 554811.01 3.00 8885.15 12711.53 87.72 0.29 3654.00 3555.00 8596.99N 4978.69E 5969149.00 554811.00 3.00 8896.65 EOC, WS 1E X5 D-FLT1N RVSD031804, End of BuildlTurn 12800.00 87.72 0.29 3657.52 3558.52 8685.39N 4979.13E 5969237.39 554810.86 0.00 8984.90 12900.00 87.72 0.29 3661.49 3562.49 8785.31 N 4979.64E 5969337.30 554810.70 0.00 9084.65 13000.00 87.72 0.29 3665.47 3566.47 8885.23N.. 4980.141;. 5969437.22 554810.54 0.00 9184.40 13100.00 87.72 0.29 3669.45 3570.45 8985.15N 4980.64F 5969537.13 554810.38 0.00 9284.15 13200.00 87.72 0.29 3673.42 3574.42 9085.07N 4981.15E 5969637.04 554810.22 0.00 9383.90 13215.00 87.72 0.29 3674.02 3575.02 9100.05N 4981.22F 5969652.02 554810.20 0.00 9398.860 TD. 4 1/2 Liner Pl. End of DroD. End of Hol< All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared bÖaR ll;s¡'ÑÃtt PROPOSA.)TING Page 6 Well bore: 1E-123L 1 Well path: 1E-123L1 Ver#3a Date Printed: 13-May-2004 Conoc~illips ConocoPhillips Alas.nCo,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska J&ií. BAKER HUGHES INTEQ II1IDrftl 633.33 833.33 1641.50 5036.02 5844.49 6375.48 6575.48 7426.09 7526.09 7526.10 7538.09 7556.09 7756.28 7856.34 7992.61 8092.61 9334.25 9360.47 11212.48 11327.60 12310.92 12371.18 12686.57 12711.53 13215.00 TVDrftl 631.64 824.58 1386.40 2631.05 2931.99 3126.67 3200.00 3474.12 3500.00 3500.00 3502.91 3506.99 3531.64 3530.90 3526.33 3525.60 3549.00 3549.67 3610.00 3613.10 3634.00 3636.23 3652.85 3654.00 3674.02 ËåStrftl 26.30E 73.15E 569.09E 3431.30E 4017.08E 4327.30E 4444.15E 4727.16E 4733.31E.. 4733.31 E 4734.05E 4735.17E.. 4747.80E 4754.17E 4762.85E 4769.21E 4848.28E 4849.95E 4967.74E 4971.65E 4976.03E 4976.37E 4978.54E 4978.69E 4981.22E Ndrtl'ìFftl 12.26N 34.11 N 265.37N 1600.04N 2058.53N 2443.00N 2587.81N 3327.60N 3423.99N 3423.99N 3435.61N 3453.11N 3651.00N 3750.85N 3886.76N 3986.54N 5225.44N 5251.60N 7098.88N 7213.87N 8196.95N 8257.17N 8572.06N 8596.99N 9100.05N Cålmîenf BId 5/100 Bid 6/100 EOC Trn 3/100 EOC Start 200' PumD Tanoent End 200' Pump Tanqent, BldlTrn 4/100 EOC Tie to 1E-123 Top Whipstock Face Base Wl'ìiDstock Face End Milled ODenhole. Bid 6/100 Bid 3/100 EOC DroD 3/100 EOC DroD 3/100 EOC BldlTrn 3/100 EOC DroDlTrn 3/100 EOC BldlTm 3/100 EOC TD,4 1/2 Liner PI. 13 1/2 97/8 63/4 0.00 3860.43 7526.09 0.00 2200.00 3500.00 O.OON 1137.82N 3423.99N O.OOE 2440.05E 4733.31E 2200.00 3574.65 3674.02 2440.05E 4757.09E 4981.22E 1E-123 1E-123 1 E-123L 1 1137.82N 3796.53N 9100.05N 3860.43 7902.15 13215.00 10 3/4in Casino 0.00 0.00 O.OON O.OOE 3860.43 2200.00 1137.82N 2440.05E 1E-123 7 5/8in Casinq 0.00 0.00 O.OON O.OOE 7902.15 3574.65 3791.13N 4756.74E 1E-123 ma'~..e~s Nâiñê WS 1E X5 19 20.2948 D-MDPT#2 RVSD021804 WS 1EX5 5225.44N 4848.28E 3549.00 N70 19 1.8706 W149 33 23.7361 554703.00 5965777.00 D-MDPT#1 RVSD021804 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method ~ÕR ÎGïÑÄI,,"œd Conoc6'Phillips ConocoPhillips AlaS.Co,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAATING Page 7 Well bore: 1 E-123L 1 Wellpath: 1 E-123L 1 Ver#3a Date Printed: 13-May-2004 r&i_ BAKER HUGHES INTEQ WS 1E X5 D-FLT1S 8196.95N 4976.03E 3634.00 N70 19 31.0942 W149 33 19.9513 554811.00 5968749.00 RVSD031804 WS 1EX5D-FLT1N 8596.99N 4978.69E 3654.00 N70 19 35.0285 W149 33 19.8660 554811.00 5969149.00 RVSD031804 WS 1EX5DTOE 9225.04N 4981.85E 3679.00 N70 19 41.2053 W149 33 19.7612 554810.00 5969777.00 RVSD021804 654442 Planned 13215.00 3674.02 ISCWSA MWD MWD+MagCorr+SAG - ISCWSA - 28 Jan 03 OJH 645540 Planned 3860.43 2200.00 ISCWSA MWD MWD+SAG - ISCWSA - 28 Jan 03 OJH 660200 Planned 7526.09 3500.00 ISCWSA MWD MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10374.18 Feet on azimuth 28.70 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL eaker Hughes Incorpor. Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 7526.09 to 13215.00 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/23/2004 Validated: No Planned From To Survey ft ft 0.00 7526.08 Planned: 1E-123 VER#3 V15 (0) 7526.08 13215.00 Planned: 1E-123 L 1 VER#3a V11 Version: Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Casing Points 7526.08 3500.00 13215.00 3674.03 7.625 4.500 9.875 6.750 75/8" 4 1/2" Summary 123,1E-123 L 1,1E-123 L 13215.00 13215.00 0.00 384.84 -384.84 FAIL: Major Risk Pad 1 B 101 1B-101V3 13199.71 6525.00 143.74 0.00 143.74 Pass: Minor 1/200 Pad 1 B 101 1B-101L1 V3 13199.71 6525.00 143.74 0.00 143.74 Pass: Minor 1/200 Pad 1 B 102 1B-102 V15 13215.00 3275.00 3027.48 332.52 2694.95 Pass: Major Risk Pad 1B 8 18-08 VO 12495.11 5900.00 1924.38 306.79 1617.59 Pass: Major Risk Pad 1 8 8 1 8-0BA VO 12495.11 5900.00 1924.38 306.79 1617.59 Pass: Major Risk Pad 1 D 103 10-103 V1 11653.47 11500.00 847.36 527.68 319.~8 Pass: Major Risk Pad 1 E 10 1E-10 VO Out of range Pad 1 E 102 102 8-Lateral VO Plan: 13031.05 12072.67 682.94 0.00 682.94 Pass: Minor 1/200 Pad 1 E 102 102 D-Lateral VO Plan: 13028.90 12067.88 680.14 0.00 680.14 Pass: Minor 1/200 Pad 1 E 103 103 VO Plan: 1E-103 VE Out of range Pad 1 E 11 1E-11 VO Out of range Pad 1 E 121 121 8-Lateral VO Plan: 13205.52 11600.00 1557.90 695.38 862.53 Pass: Major Risk Pad 1 E 121 121 D-Lateral VO Plan: 13208.31 11600.00 1555.88 665.41 890.47 Pass: Major Risk Pad 1 E 12 1E-12 VO Out of range Pad 1 E 123 1E-123 V5 Plan: tE-123 7549.99 7550.00 0.60 145.95 -145.36 FAIL: MajorRisk Pad 1 E 126 126 A2-Lateral VO Plan Out of range Pad 1 E 126 126 B-Lateral VO Plan: Out of range Pad 1 E 126 126 D-Lateral VO Plan: Out of range Pad 1 E 168 168 A2-Lateral V3 Plan Out of range Pad 1 E 168 168 8-Lateral VO Plan: Out of range Pad 1 E 168 168 D-Lateral VO Plan: Out of range Pad 1 E 36 1 E-36 VO Out of range Pad 1 E 5 1E-05 VO Out of range Pad 1 E 6 1 E-06 VO Out of range Pad 1 E 7 1E-07 VO 7526.08 7825.00 2239.08 103.19 2135.88 Pass: Major Risk Pad 1 E 8 1 E-08 V1 Out of range ORIGINAL · . lE-123 Ll Drillina Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Low Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Lost Circulation Hole Swabbing on Trips Low Moderate ORIGINAL. 1E-123 L 1 Drilling Hazards Summary. doc prepared by Steve McKeever 5/1/2004 2:02 PM Wellhead I Tubing Head I Tree, 13-5/8" x ¿- 4-W', 5,000 ksi 1 E-123 As Staked,;, Eostings: +/,549,890 Northings: +/, 5.960.520 Pod Elevation: 71' AMSl Insulated Conductor Casing,20", -ì- 94#, K55 x 34", \r ¡ 0,312"Wf@ : +1-108' MD t-- 10-3/4",45.5#, L- ~"'\'~ SO, BTC set @ +/- 3,S60' MD 12,200' TVD ~ @ 65 degrees TD ~ 13-1/2" hole o ::0 - G') - z » r- Top of 5,54S' MD / 2,S C @ ----. TVD (x) Joints Tubing Tubing String: 4-1/2", 12.6 #, L-SO, IBT,AB Modiifed with Special Clearance Couplings (4.920" OD) Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 99' AMSL to (1) Gas Lift Mandrel (1) ESP Motor I Intake Section, bottom at 6550' MD 1321S' TVD Liners, 4-%",12.6#, LSO, DWC/C, every joint slotted, (0.125" x 2.5" slots, 32 per foot, 5.9% open area), 1 E-123L 1 : 6-%" Upper lateral TD @ 13,215 MD /1 3674 TVD ....~.............~.....................................1 I Top of Cement @ 7,000' MD 13,34S TVD ----. 123L 1 Window @ +1- ~ 7,526' MD 13,500' TVD, ¥ 75 degrees of West Sak @ MD / 3,500 TVD ----. /f 4-%" slotted liner / top @ at +/- 7,566' I ~ 3510' ;~~~~~~~~~~~~~~§~§§§§~~§§§§§§~§§§§§§§~~§§§§§§§§§§§§§§~§~I ~ ~ tz 7-5/S", 29.7#, L-SO, BTCM 1E-123: J "--- Casing set @ +1- 7,902' MD I 6-%" Lower lateral 3,574' TVD TD @ 13,345 MD I Set@ S5 degrees TD 9.875" hole 3,742 TVD =an - ".Si~ 't'!i~,,= ~:;;"", (I)~fj ~~ ~æ h ~~ . ~ ...J C') N '":' (,) w:¡:¡ ~ lIS =E GI GI >.c~ >(,)... C(/)o o-~ :g=Eâ) ~ C GI 'tIo.c o-(/) ...- Q. .- ~ E lIS GI (/)Q. - UI ~ . "'J2 Q.gj =<{ )~ 8 o c: 8 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): ,/ Surface: 933' FSL, 630' FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: 924' FNL, 1169' FEL, Sec. 15, T11N, R10E, UM Total Depth: 403' FNL, 908' FEL, Sec. 10, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): "" , ~~Ó~'1'D .þl>'D'Í 5~·".b ~2l.) Surface: x- {. ¡'¡'y- ~1 16. Deviated wells: Kickoff depth: 7526 ./ 18. Casing Program Size 1a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Hole Casing 42" 20" x 34" 13.5" 10.75" 9-7/8" 7-5/8" 6.75" 4.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat Specifications Grade Coupling TVD K-55 Weld 28' L-80 BTC 28' L-80 BTCM 28' 28' L-80 Grant ~ ~ .tŒ7h1. " , "\ S~ - 3.Sò\J PRESENT WELL CONDITION SUMM y. ç 1'-1:: / C) Li (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (It): Plugs (me ured) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) length 1";" \ Cement Volume MD TVD \. i~ \'-"ì " ft. Weight 94# 45.5# 29.7# 12.6 . ~ RECEIVED S{\ MAY 032004 / . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU Alaska Oil ~a! Cons mn:::;~:cn ExploratoryU Development Oil'¡ h Multiple ~one 0 Service 0 Development Gas C ge Single Zone 0 5. Bond: U Blanket U Single Well 11. ell Name and Number: Bond No. 59-52-180 1 E-123L 1 6. Proposed Depth: 12. Field/Pool(s): 13340' MD.I Kuparuk River Field 11b. Current Well Class: Stratigraphic Test 0 Zone- 15. Distance to Nearest 7. Property Designation: , 8. Land Use Permit: West Sak Pool 13. Approximate Spud Date: 5/14/2004 14. Distance to Nearest Property: 908" @ TD 4 (Height aOO... l): 28' RKB Well Within Pool: 1B-101/104' @ 13291' 17. An' ipated Pressure (see 20 AAC 25.035) .,. Ma . Downhole Pressure: 1834 psig I Max. Surface Pressure: 1422 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 260 cf ArcticCrete 2200' 770 sx AS Lite, 180 sx DeepCrete 3474' 160 sx DeepCrete 3679' slotted liner Maximum Hole Angle: 'II. 't.!, Þ trJ ~rti-··( MD 108' 3860' 7902' 13340' perfOration Depth TVD (ft): Drilling Program~ Time v. Depth Plot U Seabed Report 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 22. I hereby certify that the foregoing is t e and correct to the best of my knowledge. Printed Name Signature Commission Use Only API Number: " .... '" _I Permit Approval 50- OdS - ð ~ ðG%' - ~Ù Date: o Yes ~o o Yes ~NO \>~ \ ('A '\ Ii"''' '''-'.J M. ßÖ '?-\cë 'S \- Permit to Drill Number: ;to \....\ - \:J Other: ~SÕ Approved by: Contact Steve McKeever @ 265-6826 Title Kuparuk Drilling Team Leader Phone ¿('5'~' 6IB 3 ¡) Date 5/3/0 ~ PreDared bv Sharon Al/suD-Drake Samples required Hydrogen sulfide measures Mud log required Directional survey required Isee cover letter for other requirements ø:. No o No Form 10-401 Revised 3/2003 . DYes ~Yes COMMISSIONER BY ORDER OF THE COMMISSION Date: ORJGj~Jl\L Submit in duplicate .~ Apr 'on for Permit to Drill, Well 1 E-123L 1 ____ Revision No.O Saved: 2-May-04 Permit It - West Sak Well #1 E-123L 1 Application for Permit to Drill Document MoximizE Well ValUE Table of Contents 1. Well Name.. ............................. .... ...... .... .... ... ........ ... .... ....... ... .... ......... ... ... ..... ... ... ...... 2 Requirements of 20 AAC 25.005 (f)...... ........................ .... ..... ........................ ...... .................... ......... ......2 2. Location Sum mary ............ ..... ... ... ........ ... ....... .... ......... ............. ....... ..... ... ..... ... ... ...... 2 Requirements of 20 AAC 25.005(c)(2) ...;.. ........... ...................... ........................ .................... ..... ..... ......2 Requirements of 20 AAC 25.050(b)........... ......... ................... ........................ .............. ................ ........... 3 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) . ................ ..... ............ ........ ....... ...................... ....... ........ ............. 3 4. Dri II ing Hazards Information.... ....... ..... ......... ........ ... ......... ...... ............ ... .... ..... ........ 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Dri II ing FI u id Program .......... ...... ..... ....... ....... .... .... ........... .... ... ............ .............. ...... 5 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis. .......... ..... ................ .... ........... ........... ..... ........... ......... ................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bondi ng . ......... ..... ............ ....... .... ...... ........ ... ....... .... ..... ........... ... .... ... ... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL 1E-123L1 PERMIT IT. doc Page 1 of 7 Printed: 2-May-04 Ä;.tion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 2-May-04 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AA C 25.005 (c )(14) ................................................................................................ 7 15. Attachments................ ............................... ............. ......... ................. ...... ..... ....... ..... 7 Attachmentf Directional Plan. (13 pages) ..... ................... ........... ..... ............................... ....... ......... ....... 7 Attáchment 2 Drílling Hazards Bummary (1page) ................................................................................. 7 Attachment 3 Cement Loads and CemCADEBummary (2 page) ........Error! Bookmark not defined, Attachment4 Well Schematics (5 pages) ............ ......................... .................... ........... .......................... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number as...s1gned by the commissIon under 20 MC 25: 040(b). For a well wIth multiple well branche.s~ each branch must simllady be identified by a unique name and API number by addIng a suffix to the name designated for the well by the operator and to the number assigned to t/7e well by the commission The well for which this Application is submitted will be designated as lE-123Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pert!?it to Drill must be accompanied by each of the following item~ except for an item already on tÎle ¡"11th the commission and Identified in the application: (2) a plat idenœýing the propertý and the property's owners and sl70wing (Ajthe coordinates of the proposed location of the well at the surface! at the top of each objective forrnation and at total depthl referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUNey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings.' 5,959,781 Eastings.· 550,301 933/ FSL, 630/ FEL, Section 16, TllN, R10E, UM RKB Elevation 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings.· 5,963,975 Eastings: 554,600 924/ FNL, 1169/ FEL, Section 15, TllN, Rl0E, UM Measured Depth/ RKB: Total Vertical Depth RKB: Total Vertical Depth 55: 7,526 3,500 3,401 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,969,777 Eastings: 554,810 403/ FNL, 908/ FEL, Section 10, TllN, Rl0E, UM Measured Depth/ RKB.· 13,340 Total Vertical Depth/ RKB: 3,679 Total Vertical Depth/55: 3,580 and (D) other ínformation required by 20 MC 25.0S0(b); nnlclN- Al L)t\~U '. "ij . ~ 1 E-123L 1 PERMIT IT. doc Page 2 of 7 Printed: 2-May-04 -- Apr 'on for Permit to Drill, Well 1 E-123L 1 _ Revision No.O Saved: 2-May-04 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale/ showing the path of HJe proposed wellbore/ including all adjacent wel/bores wIthin 200 feet of any portion of the proposed we/~' Please see Attachment 1: Directional Plan and (2) for all wells witl7in 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been fumished a copy of the application bycenitied mail;' or (B) state that the applicant is tl7e only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the applicaäon: (3) a diagram and description of the blowout prevention equipment (SOPE) as required by 20 MC 25. 03~ 20 MC 25. 03ii or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well lE-123L1. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PermIt to On/I must be accompanied by each of the following ítem~ except for an item already on tile with the commission and Identified in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encounterert criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lE-123Ll area vary from 0.42 to 0.49 psi/ft, or 8.1 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1,422 psi, calculated thusly: MPSP =(3,742 ft)(0.49 - 0.11 psi/ft) =1,422 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concermi1g potential causes of hole problems such as abnormally geo-pressured strata" lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Onll must be accompanied by each of the foilowing ítems/ except for an item already on file wIth the commission and Identified in the applicaäon: (5) a description of the procedure for conducting formation integntý tes~ as requiœd under 20 MC 25.030(f); The parent wellbore,lE-123, will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1E-123L1 PERMIT IT. doc Page 3 of 7 Printed: 2-May-04 ORIGINAL A ttion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 2-May-04 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Per/nit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and ídentified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25. 030/ and a description of any slotted iine0 pre- perforated line0 or screen to Ùe iÌ7stal/ed; 6-3/4" Lower Lateral (lE-123) 4-1/2 6-3/4" slotted Upper Lateral (lE-123 L1) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commissíon and identified in the application: (7) a diagram and description of [rye diverter system as required by 20 MC 25. 03~ unless this requirement is waived by the commission under 20 AAC 25.035(h){2/' Casing and Cementing Program See also Attachment 3, APD for 1E-123: Cement Summary Hole Size (in) 42 Top MOITVO (tt) 28 / 28 Btm MDITVD (tt) 108/ 108 Connection Welded Length (tt) 80 Csg/Tbg 00 (in) 20 X 34 Weight (Ibltt) 94 Grade K55 10-3/4 13-1/2 28 / 28 3860 /2200 L-80 STC 3832 45.5 7-5/8 9-7/8 28 / 28 7902/ 3474 L-80 STCM 7874 29.7 4-1/2 slotted 7566 / 3510 13,345 / 3742 L-80 Grant Prideco DWC/C 5779 12.6 12.6 L-80 75261 3500 13340 I 3679 Grant Prideco DWC/C 5814 No diverter system will be utilized during operations on 1E-123L1 ñF"'l. ~ I 1_~J t) f\ ~ f\1,\1 tJ ¡";l\L Cement Program Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 770 sx AS Lite Lead, 180 sx DeepCRETE Tail Cement Top planned @ 7000' MD / 33481 TVD. Cemented w / 160 sx DeepCRETE Slotted- no cement Slotted- no cement 1E-123L1 PERMIT IT. doc Page 4 of 7 Printed: 2-May-04 '-' Ap. ion for Permit to Drill, Well 1 E-123L 1 '--' Revision No.O Saved: 2-May-04 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the fo/lowing item~ except for an item already on file with the commission and identified in the application: (8) a drilling fluid program/ including a diagram and description of the dril/ing fluid system/ as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intelVals: Lateral Mud Program (MI FloPro NT) B/D sand laterals Initial Value Final Value 9.7 9.7 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb/100 sf) Tau 0 Chlorides (mg/I) pH API filtrate (cc /30 min) **HTHP filtrate (cc /30 min) MBT (Ib / gal) ***Solids (% Vol) 22-30 22-30 8-12 8-12 4-7 4-7 65-80K 65-80K 8-9.5 8-9.5 <6 <6 <10 <10 <5 <5 <6-9 <6-9 .... HTHP to be run at 80° F u" The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermJt to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identífìed in the application: (9) for an exploratory or stratigraphic test wel~ a tabulation settíng out the depths of predided abnormally geo-pressured strata as required by 20 MC 25.033(f}/' Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following ítem~ except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphIc test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dnll mllst be accompanied by each of the foílowing item~ except for an item already on file wIth the commission and Identified in the application: ORIGINAL 1 E-123L 1 PERMIT IT. doc Page 5 of 7 Printed: 2-May-04 Ar tion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 2-May-04 (i1) for a well dnï/ed from an offshore platfom7/ mobile bottom-founded structuíe/ jack-up rig/ or f10ating drll/filg vesse¿ an analysis of seabed conditions as required by 20 AAC 2S061(b)/' Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicatIon for a Permit to Drill must be accompanied by each of the foflowing item~ except for an Item already on file wit!] the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fa/lowing item~ except for an Item already on file wIth the commission and Identified in the application: The proposed drilling program for lE-123 L1 is listed below. Please refer also to Attachment 5, Well Note: Previous operations are covered under the 1E-123 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7,526' MD / 3,500' 1VD, the top of the D sand. 2. Displace hole to used mud from lower lateral at 9.7 ppg. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Displace to new drilling mud at 9.7 ppg. Drill to TD of D sand lateral at 13,340' MD / 3,679' 1VD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. 10. POOH, laying down drill pipe as required. 11. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Set BPV and move rig off. 14. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Rig up wire line unit. Pull BPV 16. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 17. Replace gas lift valves with dummies. 18. Run ESP through tubing. 19. Operate well with ESP. () D f ~ Î NA I Uf\IOlij L 1E-123L1 PERMIT IT. doc Page 6 of 7 Printed: 2-May-04 -~ Apf 'on for Permit to Drill, Well 1 E-123L 1 '"-'. Revision No.O Saved: 2-May-04 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mllstc be accompanied by each of the following items; except for an item aíreadyon tile with the commission and Identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25,080 for an annular disposal operation in the we/f.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan (8 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Well Schematic (1 pages) ORIGINAL 1E-123L1 PERMIT IT. doc Page 7 of 7 Printed: 2-May-04 '-' Conoc;Pt,illips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska '--., PROPOSAL LISTING Page 1 Wellbore: 1 E-123L 1 Wellpath: 1E-123L1 Ver#3 Date Printed: 22-Apr-2004 B"_ BAKER HUGHES L"lTEQ Well bore Name 1 E-123L 1 I Created 29-Jan-2004 Well Name 123 I Govemment ID Last Revised 29-Jan-2004 Slot Name Slot #123 I Grid Northinq 5960520.0000 I Grid Eastinq 549890.0000 Installation Name Pad 1 E I Fastina 550528.1946 I Northina 5959591.1090 I Coord Svstern Name ..... .... .......... "JNorthAJianrnent .... AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name KUDaruk River Unit IF astina 487754.6208 I Northina 5948985.e206 fCoord SvstêmNarue ........................ ··.··....NOrthAlianment AK-4onNORTHAMERICAN DATUM 1927datum .......... ..' .' True Created By Comments All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL Conocri"Pt,illips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 1 E-123L 1 Well path: 1 E-123L 1 Ver#3 Date Printed: 22-Apr-2004 r&i. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg} Azi[deg} TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing fdeq/100ftl Sectionfftl 7526.09 75.00 3.65 3500.00 3423.99N 4733.31 E 0.00 3718.53 554600.00 5963975.00 7538.09 76.91 3.65 3502.91 3435.61 N 4734.05E 15.90 3730.17 554600.66 5963986.62 7556.09 76.91 3.65 3506.99 3453.11N 4735.17E 0.00 3747.71 554601.66 5964004.13 7656.09 82.91 3.65 3524.50 3551.31 N 4741.44E 6.00 3846.11 554607.28 5964102.37 7756.09 88.91 3.65 3531.64 3650.81 N 4747.78E 6.00 3945.81 554612.97 5964201.89 7756.28 88.92 3.65 3531.64 3651.00N 4747.80E 6.00 3946.00 554612.98 5964202.08 7856.28 91.92 3.65 3530.91 3750.78N 4754.17E 3.00 4045.99 554618.69 5964301.89 7856.34 91.92 3.65 3530.90 3750.85N 4754.17E 3.00 4046.05 554618.69 5964301.96 7900.00 91.92 3.65 3529.44 3794.39N 4756.95E 0.00 4089.68 554621.18 5964345.51 7992.61 91.92 3.65 3526.33 3886.76N 4762.85E 0.00 4182.24 554626.46 5964437.91 8092.61 88.92 3.65 3525.60 3986.54N 4769.21E 3.00 4282.23 554632.17 5964537.73 8100.00 88.92 3.65 3525.74 3993.92N 4769.68E 0.03 4289.62 554632.59 5964545.10 8200.00 88.92 3.65 3527.62 4093.70N 4776.05E 0.00 4389.60 554638.29 5964644.91 8300.00 88.92 3.65 3529.51 4193.48N 4782.42E 0.00 4489.58 554644.00 5964744.72 8400.00 88.92 3.65 3531.39 4293.25N 4788.79E 0.00 4589.56 554649.70 5964844.53 8500.00 88.92 3.65 3533.28 4393.03N 4795.16E 0.00 4689.55 554655.41 5964944.34 8600.00 88.92 3.65 3535.16 4492.81 N 4801.52E 0.00 4789.53 554661.11 5965044.15 8700.00 88.92 3.65 3537.05 4592.59N 4807.89E 0.00 4889.51 554666.82 5965143.96 8800.00 88.92 3.65 3538.93 4692.37N 4814.26E 0.00 4989.49 554672.52 5965243.77 8900.00 88.92 3.65 3540.82 4792.15N 4820.63E 0.00 5089.4 7 554678.23 5965343.58 9000.00 88.92 3.65 3542.70 4891.93N 4827.00E 0.00 5189.46 554683.93 5965443.39 9100.00 88.92 3.65 3544.59 4991.71 N 4833.37E 0.00 5289.44 554689.64 5965543.20 9200.00 88.92 3.65 3546.47 5091.49N 4839.73E 0.00 5389.42 554695.34 5965643.00 9300.00 88.92 3.65 3548.35 5191.27N 4846.10E 0.00 5489.40 554701.05 5965742.81 9334.25 88.92 3.65 3549.00 5225.44N 4848.28E 0.00 5523.65 554703.00 5965777.00 9360.47 88.13 3.65 3549.67 5251.60N 4849.95E 3.00 5549.86 554704.49 5965803.17 9400.00 88.13 3.65 3550.96 5291.03N 4852.47E 0.00 5589.37 554706.75 5965842.61 9500.00 88.13 3.65 3554.22 5390.77N 4858.83E 0.00 5689.31 554712.44 5965942.38 9600.00 88.13 3.65 3557.48 5490.52N 4865.19E 0.00 5789.26 554718.14 5966042.15 9700.00 88.13 3.65 3560.73 5590.26N 4871.55E 0.00 5889.21 554723.84 5966141.93 9800.00 88.13 3.65 3563.99 5690.01 N 4877.90E 0.00 5989.16 554729.53 5966241.70 9900.00 88.13 3.65 3567.25 5789.75N 4884.27E 0.00 6089.10 554735.23 5966341.48 10000.00 88.13 3.65 3570.51 5889.49N 4890.63E 0.00 6189.05 554740.93 5966441.25 10100.00 88.13 3.65 3573.76 5989.24N 4896.98E 0.00 6289.00 554746.62 5966541.03 10200.00 88.13 3.65 3577.02 6088.98N 4903.34E 0.00 6388.94 554752.32 5966640.80 10300.00 88.13 3.65 3580.28 6188.73N 4909.70E 0.00 6488.89 554758.02 5966740.58 10400.00 88.13 3.65 3583.53 6288.4 7N 4916.06E 0.00 6588.84 554763.71 5966840.35 10500.00 88.13 3.65 3586.79 6388.22N 4922.42E 0.00 6688.78 554769.41 5966940.13 10600.00 88.13 3.65 3590.05 6487.96N 4928.78E 0.00 6788.73 554775.11 5967039.90 10700.00 88.13 3.65 3593.31 6587.70N 4935.14E 0.00 6888.68 554780.81 5967139.67 10800.00 88.13 3.65 3596.56 6687.45N 4941.50E 0.00 6988.63 554786.50 5967239.45 10900.00 88.13 3.65 3599.82 6787.19N 4947.86E 0.00 7088.57 554792.20 5967339.22 11000.00 88.13 3.65 3603.08 6886.94N 4954.22E 0.00 7188.52 554797.90 5967439.00 11100.00 88.13 3.65 3606.34 6986.68N 4960.58E 0.00 7288.4 7 554803.59 5967538.77 11200.00 88.13 3.65 3609.59 7086.43N 4966.94E 0.00 7388.41 554809.29 5967638.55 11212.48 88.13 3.65 3610.00 7098.88N 4967.74E 0.00 7400.89 554810.00 5967651.00 11300.00 88.63 1.07 3612.47 7186.28N 4971.34E 3.00 7488.34 554813.02 5967738.42 11327.60 88.78 0.25 3613.10 7213.87N 4971.65E 3.00 7515.90 554813.15 5967766.01 11400.00 88.78 0.25 3614.64 7286.25N 4971.98E 0.00 7588.15 554813.00 5967838.38 11500.00 88.78 0.25 3616.76 7386.23N 4972.42E 0.00 7687.95 554812.78 5967938.35 11600.00 88.78 0.25 3618.89 7486.20N 4972.87E 0.00 7787.76 554812.56 5968038.32 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGiNAL ---' ConocJ'"'Phillips ConocoPhillips Alaska, Inc.,slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska ~ PROPOSAL LISTING Page 3 Wellbore: 1E-123l1 Well path: 1E-123L 1 Ver#3 Date Printed: 22-Apr-2004 r&ii. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft) Inc[deg) Azi[deg) TVD[ft) North[ft) East[ft] Qogleg Vertical rdeQl100ftl SéctîörirftJ 11700.00 88.78 0.?5 3621.01 7586.18N 4973.31 E 0.00 7887.56 554812.34 5968138.28 11800.00 88.78 0.25 3623.14 7686.16N 4973.76E 0.00 7987.36 554812.12 5968238.25 11900.00 88.78 0.25 3625.27 7786.13N 4974.20E 0.00 8087.16 554811.90 5968338.22 12000.00 88.78 0.25 3627.39 7886.11N 4974.65E 0.00 8186.96 554811.68 5968438.19 12100.00 88.78 0.?5 3629.52 7986.09N 4975.09E 0.00 8286.76 554811.46 5968538.15 12200.00 88.78 0.25 3631.64 8086.06N 4975.53E 0.00 8386.57 554811.24 5968638.12 12300.00 88.78 0.?5 3633.77 8186.04N 4975.98F 0.00 8486.37 554811.02 5968738.09 12310.92 88.78 0.25 3634.00 8196.95N 4976.03E 0.00 8497.26 554811.00 5968749.00 12371.17 86.98 0.39 3636.23 8257.17N 4976.37E 3.00 8557.38 554810.94 5968809.21 12400.00 86.98 0.39 3637.75 8285.95N 4976.57E 0.00 8586.11 554810.95 5968837.98 12500.00 86.98 0.39 3643.02 8385.79N 4977.26E 0.00 8685.79 554810.97 5968937.82 12600.00 86.98 0.39 3648.28 8485.63N 4977.94E 0.00 8785.47 554811.00 5969037.65 12686.59 86.98 0.39 3652.85 8572.07N 4978.54E 0.00 8871.78 554811.02 5969124.09 12700.00 87.38 0.34 3653.51 8585.47N 4978.62E 3.00 8885.15 554811.01 5969137.48 12711.53 87.72 0.29 3654.00 8596.99N 4978.69E 3.00 8896.65 554811.00 5969149.00 12800.00 87.72 0.?9 3657.52 8685.39N 4979.13E 0.00 8984.90 554810.86 5969?37.39 12900.00 87.72 0.?9 3661.50 8785.31 N 4979.64F 0.00 9084.65 554810.70 5969337.30 13000.00 87.72 0.29 3665.4 7 8885.23N 4980.14E 0.00 9184.40 554810.54 5969437.22 13100.00 87.72 0.?9 3669.45 8985.15N 4980.64E 0.00 9284.15 554810.38 5969537.13 13200.00 87.72 0.?9 3673.43 9085.07N 4981.15E 0.00 9383.90 554810.22 5969637.04 13300.00 87.72 0.29 3677.41 9184.99N 4981.65E 0.00 9483.65 554810.06 5969736.95 ./ 13340.09 87.72 0.29 3679.00 9225.04N 4981.85E 0.00 9523.63 554810.00 5969777.00 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConoccrPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 1 E-123L 1 Wellpath: 1E-123L 1 Ver#3 Date Printed: 22-Apr-2004 J4i. BAKER HUGHES INTEQ Comments MDrftl rvDrftl 633.33 631.64 833.33 824,58 1641.50 1386.40 5036.02 2631.05 5844.49 2931.99 6375.48 3126.67 6575.48 3200.00 7426.09 3474.12 7526.09 3500.00 7526.10 3500.00 7538.09 3502.91 7556.09 3506.99 7756.28 3531.64 7856.34 3530.90 7992.61 3526.33 8092.68 3525.60 9334.25 3549.00 9360.47 3549.67 11212.48 3610.00 11327.60 3613.10 12310.92 3634.00 12371.17 3636.23 12686.59 3652.85 12711.53 3654.00 13340.09 3679.00 Northrttl 12.26N 34.11 N 265.37N 1600.04N 2058.53N 2443.00N 2587.81 N 3327.60N 3423.99N 3423.99N 3435.61 N 3453.11 N 3651.00N 3750.85N 3886.76N 3986.61 N 5225.44N 5251.60N 7098.88N 7213.87N 8196.95N 8257.17N 8572.07N 8596.99N 9225.04N Eastfftl 26.30E 73.15E 569.09E 3431.30E 4017.08F 4327.30E 4444.15E 4727.16E 4733.31 E 4733.31 E 4734.05E 4735.17E 4747.80E 4754.17E 4762.85E 4769.22E 4848.28E 4849.95E 4967.74E 4971.65E 4976.03F 4976.37E 4978.54E 4978.69E 4981 .85E Comment Bid 5/100 Bid 6/100 EOC Tm 3/100 EOC Start 200' Pumo Tanaent End 200' Pump Tanqent, BldlTm 4/100 FOC Tie to 1E-123 Top Whipstock Face Base Whipstock Face End Milled Ooenhole. Bid 6/100 BId 3/100 EOC Droo 3/100 EOC Droo 3/100 EOC BldlTm 3/100 FOC DroolTm 3/100 EOC BldlTrn 3/100 FOC TD, 4 1/2 Liner pt. Hole Sections Diameter Start Start Start Start End End End End Wellbore nnl MDrm rvDrftl Northrttl Eastrftl MDrftl rvDrftl Northfftl Eastrftl 13 1/2 0.00 0.00 O.OON O.OOE 3860.43 2200.00 1137.82N 2440.05E 1 E-123 97/8 3860.43 2200.00 1137.82N 2440.05E 7902.15 3574.65 3796.53N 4757.09E 1 E-123 63/4 7526.09 3500.00 3423.99N 4733.31 E 13340.09 3679.00 9225.04N 4981.85E 1E-123L1 Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Well bore MDrftl rvDrftl Northfftl Eastrftl MDfftl TVDfftl Northfftl Eastfftl 10 3/4in Casina 0.00 0.00 O.OON O.OOE 3860.43 2200.00 1137.82N 2440.05E 1 E-123 7 5/8in Casinq 0.00 0.00 O.OON O.OOE 7902.15 3574.65 3791.13N 4756.74E 1 E-123 TarQets Name Northfftl Eastfftl TVDrftl Latitude Lonaitude Eastina Northina WS 1E X5 D-FL T1S 8196.95N 4976.03E 3634.00 N70 19 31.094~ W149 33 19.951 554811.00 5968749.00 RVSD031804 WS 1EX5 DTOE 9225.04N 4981.85E 3679.00 N70 19 41.205~ W149 33 19.761 554810.00 5969777.00 RVSD021804 WS 1 E X5 D-FL T1 N 8596.99N 4978.69E 3654.00 N70 19 35.028E W149 33 19.866 554811.00 5969149.00 RVSD031804 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum CUNature method Prepared by Baker Hughes Incorporated OR GI~~AL ----. ConoccrPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska Taraets Name WS 1 E X5 D-MOPT#2 RVS0021804 WS 1 E X5 D-MOPT#1 RVSD021804 "'-' PROPOSAL LISTING Page 5 Well bore: 1 E-123L 1 Wellpath: 1E-123L 1 Ver#3 Date Printed: 22-Apr-2004 F&ii. BAKER HUGHES INTEQ Northrftl Eastrft1 TVDrftl Latitude 7098.88N 4967.74E 3610.00 N70 554810.00 5225.44N 4848.28E 3549.00 N70 19 1.870f W149 33 23.736 554703.00 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL 5965777.00 ConocoPhillips Alaska, Inc. '-'i. BAKU HUGHES íN:ftö Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E Slot: Slot #123 Well: 123 Wellbore: 1 E-123L 1 ~/ ConocoPhillips TRUE NORTH Created by: Planner Date plotted: 22-Apr-2004 Plot reference is 1 E-123L 1. Ref wellpath is 1 E-123L 1 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. 350 o 10 340 20 330 30 310 \. \ \ \ \ 240 40 320 \ \ 50 300 60 290 70 280 / I f I 80 270 2~0 I 1eO I 1~0 ! 40 ~\ 4,0 + 4.0 8.0 120 160 200 \ 240 ! 90 8.0 240 \ \ \ 100 260 250 110 120 230 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well tJR·· I~'N· tAl Lt:"s~J!g \_ · "-."'. 'ßaker Hughes IncorporateD Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 E 123 1E-123 L 1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 7526.08 to 13340.00 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 2/23/2004 Validated: No Planned From To Survey ft ft 4.00 7526.08 Planned: 1E-123 VER#3 V15 CO) 7526.08 13340.00 Planned: 1E-123 L 1 VER#3 V10 Version: 0 Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Casing Points MD TVD Diameter Hole Size ft ft in in 7526.08 3500.00 7.625 9.875 75/8" 13340.00 3679.00 4.500 6.750 41/2" Summary <- - Offset Wellpatb -> Site Well Wellpath Pad 1 B 101 1B-101 V3 13291.13 Pad 1 B 101 1 B-1 01 L 1 V3 13291.13 Pad 1 B 101 1B-101PB1 V6 12662.76 Pad 1 E 10 1 E-10 VO Pad 1 E 102 102 B-Lateral VO Plan: 13031.05 Pad 1 E 102 102 D-Lateral VO Plan: 13028.90 Pad 1 E 103 103 VO Plan: 1E-103 VE Pad 1 E 104 104 VO Plan: 1E-104 VE Pad 1 E 105 105 A2-Lateral VO Plan Pad 1 E 105 105 B-Lateral VO Plan: Pad 1 E 105 105 D-Lateral VO Plan: Pad 1 E 11 1 E-11 VO Pad 1 E 112 112 A2-Lateral VO Plan Pad 1 E 112 112 B-Lateral VO Plan: Pad 1 E 112 112 D-Lateral VO Plan: Pad 1 E 114 114 A2-Lateral VO Plan 8208.87 Pad 1 E 114 114 B-Lateral VO Plan: 8205.57 Pad 1 E 114 114 D-Lateral VO Plan: 8204.52 Pad 1 E 117 117 A2-Lateral VO Plan Pad 1 E 117 117 B-Lateral VO Plan: Pad 1 E 117 117 D-Lateral VO Plan: Pad 1 E 119 119 VO Plan: 1E-119 Ve Pad 1 E 1 1 E-01 VO Pad 1 E 1 1E-01A VO Pad 1 E 121 121 B-Lateral VO Plan: 13278.03 Pad 1 E 121 121 D-Lateral VO Plan: 13280.82 Pad 1 E 12 1E-12 VO Pad 1 E 123 1E-123 V4 Plan: 1E-123 7549.99 Pad 1 E 126 126 A2-Lateral VO Plan Pad 1 E 126 126 B-Lateral VO Plan: Pad 1 E 126 126 D-Lateral VO Plan: Pad 1 E 13 1E-13 VO Pad 1 E 14 1 E-14 VO Pad 1 E 15 1E-15VO Pad 1 E 16 1 E-16 VO Pad 1 E 166 166 A2-Lateral VO Plan Pad 1 E 166 166 B-Lateral VO Plan: Pad 1 E 166 166 D-Lateral VO Plan: Pad 1 E 168 168 A2-Lateral V3 Plan Pad 1 E 168 168 B-Lateral VO Plan: Pad 1 E 168 168 D-Lateral VO Plan: Pad 1 E 170 170 A2-Lateral VO Plan Pad 1 E 170 170 B-Lateral VO Plan: 6625.00 103.80 0.00 103.80 6625.00 103.80 3100.00 3300.12 0.00 3300.11 12072.67 682.94 0.00 682.94 12067.88 680.14 11630.91 1085.32 399.00 11614.38 1053.79 399.53 11609.03 1049.67 403.57 686.31 654.25 646.10 11675.00 1538.96 700.96 11675.00 1537.05 670.82 838.00 866.24 7550.00 0.60 145.95 -145.36 ORIGINAL Pass: Minor 1/200 No Offset Casings Pass: Minor 1/200 Out of range Pass: Minor 1/200 No Offset Casings Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Out of range FAIL: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Baker Hughes Incorporated Anticollision Report Company: Field: ReferenceSite: Reference \Veil: Reference.Wèllpath: ConocoPhillipsAlaska;nlnc. Kuparuk River Unit Pad 1 E 123 1E"123L1 Summary <- __ Offset Wellpath -> Site Well Wellpatb Pad 1 E 170 170 D-Lateral VO Plan: Pad 1 E 17 1 E-17 VO Pad 1 E 18 1 E-18 VO Pad 1 E 19 1 E-19 VO Pad 1 E 20 1 E-20 VO Pad 1 E 21 1 E-21 VO Pad 1 E 2 1 E-02 VO Pad 1 E 22 1 E-22 VO Pad 1 E 23 1 E-23 VO Pad 1 E 24 1 E-24 VO Pad 1 E 24 1 E-24A VO Pad 1 E 25 1 E-25 VO Pad 1 E 26 1 E-26 VO Pad 1 E 26 1 E-26A VO Pad 1 E 27 1 E-27 VO Pad 1 E 28 1 E-28 VO Pad 1 E 29 1 E-29 VO Pad 1 E 30 1 E-30 VO Pad 1 E 31 1 E-31 V1 Pad 1 E 31 1E-31PB1 VO Pad 1 E 3 1 E-03 V1 Pad 1 E 32 1 E-32 VO Pad 1 E 33 1 E-33 VO Pad 1 E 33 1 E-33PB1 VO Pad 1 E 34 1 E-34 VO Pad 1 E 35 1 E-35 VO Pad 1 E 35 35A VO Plan: 35A ST Ve Pad 1 E 36 1 E-36 VO Pad 1 E 4 1 E-04 VO Pad 1 E 5 1 E-05 VO Pad 1 E 6 1 E-06 VO Pad 1 E 7 1 E-07 VO Pad 1 E 8 1 E-08 V1 Pad 1 E 9 1 E-09 VO Pad 1 E WSR#2 WS2 V1 Co-ordinate(NE)Reference: Vertical (TVD)Reference: Date: 4/22/2004 Time: .. ·13:31 :03 Reference MD ft Ctr~Ctr< No~Go Distance Area ft ft Offset Mo. it Out of range Out of range 7526.08 7300.00 3872.50 165.31 3707.19 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 7526.08 7825.00 2239.08 103.19 2135.88 Pass: Major Risk Out of range Out of range Out of range ORIGI~~Þ\L ~ .~~- lE-123 Ll Drillinq Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Low Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, Hole Opener, Decreased mud weiqht Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Lost Circulation Hole Swabbing on Trips Low Moderate ORIGINAL 1 £-123 L 1 Drilling Hazards Summary. doc prepared by Steve McKeever 5/1/20042:02 PM o ;0 ...- GJ - Z » I Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT @ +/- 108' MD Wellhead 1 Tubing Head 1 Tree, 13-5/8" x ¿- 4-W', 5,000 ksi 1E-123 As Staked.;, Eastings: +/- 549,890 Northings: +/- 5,960,520 Pad Elevation: 71' AMSL (x) Joints Tubing Tubing String: 4-1/2", 12.6 #, L-SO, IBT ,AB Modiifed with Special Clearance Couplings (4.920" aD) Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 99' AMSL (x) Joints Tubing -t to "\ \' e'(\'f\\ "\ ~/\ -z,3\. ~t\C '\ '\ Z'3 I Sc\\e\'\'\" ef '3, '\ -e... 01'\\\ \ V\~t'\ 'O"a ~'O\1'ect\ (1) Gas Lift Mandrel Top of Ugnu C @ 5,54S' MD I 2,S22' TVD ----. (1) ESP Motor I Intake Section, bottom at 6550' MD I 321S' TVD Liners, 4-%",12.6#, LSO, DWC/C, every joint slotted, (0.125" x 2.5" slots, 32 per foot, 5.9% open area), Top of Cement @ 7,000' MD I 3,34S TVD ~ 1E-123L 1: 6-%" Upper lateral TD @ 13,340 MD /1 3679 TVD ~~~~~~~~~§§§§::§§§§§§§§§§§§~§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§ I 123L 1 Window @ +1- ~ 7,526' MD 1 3,500' TVD, ¥ 75 degrees Top of West Sak @ 7,526' MD I 3,500 TVD ----. 4-%" slotted liner top @ at +1- 7,566' I 3510' ;§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§~§g ~ ~ ~ 7-5/S", 29.7#, L-SO, BTCM 1E-123: J "'-- Casing set @ +1- 7,902' MD I 6-%" Lower lateral 3,574' TVD TD @ 13,345 MD I Set @ S5 degrees TD 9.S75" hole 3,742 TVD ~~g ...(,)~ :r:;"':;¡ ~ ~ ~i3 "IJ) 1i5.. sÊ 'O~ ia ~~ ( M N .... ~~ _CIS ãi E 3:~.... cu.... 0(1)0 ..=.... g 't: ã) -CcCI) oo.c .......(1) D..... ~ "Ë CIS ... (l)CI) ....0. IJ ~ (' "'..\:1 Q.¡g =<1: )~ 8 o t: a SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 ¡~c~g~~E¿K 99501 OATE 17/'Ie,,? 2ú(,{ 62.14/311 6~~:~¿~E >:ÍÌlfe V¡:: ALt-k~/f 'fkl7rc $ (C'<:'. (.t) -ck Lc~J Jc.¡¿~~_þ~ /0,>. 1055 DOLLARS ó3 ...... CHASE Chase ManhaUan Bank USA, N.A. Valid Up To 5000 Dollars U ~..,..,"',.""". _... 00,,,,, _I . ' .' '~) MEMO ,Sid 0,-- . d¿'~hC¡.. I: 0 :¡ ¡ w 0 UtI, I: è ¡ B I, ? ¡ q 0 ? q è ?b II' W 55/, (' RECEI\/ED MAR 1 7 2004 , COm~¡:i;),E.\rm . 01 & Gas Cons. Aläska I Anchorage ( ~1,=~L:~~~M~T^·qtt,~c;.K~IST-; Field & Pool KU~~_~~~_~IY_~~~~,§~,T~,ð,~_~~~u~_~~~1~9.,_,_.".,.__ Well Name: KUeð8UK8!VU_WS8.ILlE:t2,~Lj___,____.Program .DEY Well bore seg l~1 PTD#: 2040750 Company ,GQ~.QeQl?tllLLlP_S8Lt\SKð-'N.c _, ___._m_ Initial ClasslType ,"'QEV.LI:>ENQ,___ GeoArea ,8.90,. ______.'______'..._"._ Unit :1JJ6Q_ On/Off Shore On " Annular Disposal [J Administration 11 P~rn)it fee attached. NA . Multilat!3r.al w~lIbor,e: fee not r!3qu.ired. ,SFD, , , 12 ,Leas~ ,number ,appropriate , , , , Yes, 13 .U_niq!Je well, n,arn~ .a(1q oltmb.er ' . . . , . , . . , _ _ , _ , , , , , _ , , , , . , _ . _ _ . , , , , , _ . .Y~$ _ _ , . . _ . , , , _ , , , _ _ . _ . _ . . , , _ . . . , _ _ _ _ _ _ _ _ , , , , , , _ , _ _ _ . . _ _ _ , , . ' , _ ' , _ , _ _ _ _ , , , , . , . , \4 ,W~II.lQcated in a, d.efinedpool, Yes . KRU West Sa.k Oil Pool, CQnservatipn Ord!3r No. 406A 5 ,Well.lQcated proper ,distance, from driJling unitb,ound,al)'. , y~s , ,," Nominal spa,cing .Joitswithin the ,pool ,are to.acres., 1167 Well.lQcated pr,oper distance, from otb~r wells, _ No, , NO,1 E-:123L1.will be open to the. pool within ,3:1 0' of 1B.-101 L 1. ,S,ufficient.acr!3age.ayailable in, drilliog un,it. , , , ' No, , , , , , , , No, .1 E-: 123L 1 ,will, be, Qpen to .the, popl. within ,the, same .1 O-acre dr:illing .bloCk as. 18,-10.1 L 1.. is .If,d~viateq, .is. weJlbQre plat inc.luded , y~s . 9 ,Operator only affected Pé!rty , Yes. 10 _Oper.ator bas.apprppriate_ bond in.fQrç~ . _ _ . . _ _ , . . . . , . _ _ ' _ _ _ _ _ _ _ _ _ . . . . . _ _ Y~$ _ _ _ _ _ , , _ , _ , , _ _ . . . . . . . _ . . . . . _ . _ _ _ _ _ _ _ _ _ , _ , _ , _ , _ _ _ _ _ _ _ _ _ , , _ . , . . _ . _ _ . _ _ _ , , , _ , . 11 P,ern)it c,an be issuep witbQut cO,nserva.tion order. Yes , Appr Date 12 P~rmit can þe issued withQut ad,ministrative,approval , , ' No , ,Spa,cing excepti.on can, be, issued via Admioistrative. Approval per: Rul~ 13 Qf COA06A, SFD 5/17/2004 13 Can permit be approved before 15-day wait Yesl 14 ,W~II.lQcated wi,thin area and,strataauthorized by,lnjectioo Ord,er # (put 10# in,c,olJ1m,ents), (For, NA ' , , ' , , , , , , , ' , ' \ 15 AJI welJs. withi.n .1l4_mite_ar~a_of revieW jd~otifieq (Fpr ~erv.ic~ well 9111y). _ _ _ _ . _ _ . . . . . , , .NA . . . _ . . . . . . . . . . . _ _ _ _ _ _ _ _ ' , . _ _ . . . . _ _ . _ _ _ . . _ _ . . . . _ _ _ , , _ _ _ , . , _ _ , . _ _ . _ _ _ _ . ' . _ _ _ _ 16 Pr~-produ,ced injector: 'pur.atiQn,of pre-:pro.PuGtioo I~ss, than ~ months. (For,ser:vice well only) , . ,NA , , , _ _ , , , , , ' 17 ACMP,Finding,ofCon,si,stenCy,h,as bee,n.i~sued,for.this pr,oject . , , , ,NA ' . ,Multilater:atw~lI.bor,e.. , , , , _ , , ' _ _ , ' , - - -..---.------ Engineering Appr TEM Date 5/19/2004 ~ -----~._---_._" ---...---.,,----.----- ---.---.------- -.-----.- -,---------_._,-_.. ------..--.. --.--"'------ ._------_.._----_._-_.__._--~---,.---~--------_.._..._-..--...-.,.-----.- --.-----.----..---------- -- -._--_._---_.__...._-_.__...-.,---_.~._,-_._---- -'-~---- -'-' -----_._-------_.__._~--,,_. ------ -.--.- -.--- -_.~ -. .--- 18 ,C,ondu,ct.or string,prQvid!3d , _ , , , _ , , , _ , _ , ' , , , _ _ _ , _ , , NA , , _ _ _ , , La,teral Jrom,e~isting w~lJ. , , , , , _ _ , _ . _ , , 19 ,S.ur:face ,casing protects all.known USPWs NA , . All aq,uif~rs exernpted 40 erR :147..1.02(b)(3). , , . 20 .CMT vol adequate to circ,ul.ateo.n ,cond,uctor. & su.rf, csg . NA. , , Surface ça~i.ng set,in motberbQre.. , , _ , 21 ,CMT v.ot adequ,ate, to tie-in .long ,string t.o,Sj.lrf c~g, , , , " NA , . _ , , , , prpdu,ction, c;,asing se,t in,mQtherbore,., , _ , _ , 22 _CMT w.ill. coyer,a!lkoown ,productive bQrizons, , _ . _ " ' , , , , , No... .. , , _ , , ,SI9tte,d .liner ,completion planned., , , , , ' _ 23 ,C,asing designs adequat~ for C"T, B,&,permafr,ost Yes " 24 ,A.pequ,ate.tan,kage,OJ re,serve pit " , , , , , ' , ,Yes . , Rig .is, e,qµippe,dwith steel.pits.. NQ r!3sewepjt.pl,ann~d. AU was.te to.CIé!sS II well(s). 25 Jf.a.re-.drill, has, a, 1,0:-4.03 for .abanpon,rne,nU:~e~o approved, , , . , , ' _ " _ ' , . ' , . , NA , , _ _ . , , , , , . ., ',,' _ , , , , , , , " , . ' _ _ _ . , ' , . , ' , , , , , , , , . , . ' , ' , , 26 Adequ.ate.'^le!IQor~ ~eparç¡tjo_n ,prop9~e.d. _ _ _ . _ " . . . . . " . " , _ . _ _ _ _ _ _ _ _ _ , . , _ _ _ .Yß$ _ . _ _ . . . prp'5:imity- é!n.alysis pe.rfprme.d, Neares.t welJb.ore.is the rn.otherbpr:.e, _ " . . _ _ . . " . _ . . . . . . _ _ _ _ _ . _ _ _ _ , 27 Jf..djver:ter Je.q,uir~d, does ,it meet. regu.lations, , . .. ,NA , . aOp wi.1I .be alr~ady b~ in pl.aç~., . , , _ _ , . " 28 .DJiUilJg flujd, program schematic,&. eq.Jip" Jistapequate , , , . _ , . . _ ' , . , Yes " _ _ , .. ,BHI? range, 8.1 : 9.4 EMW. J~lanned mud weigh,t 9.7 ppg.. , , , , _ . ' , , _ , , , , , 29 ,B_OPEs"d,o .they meet n3gu.lé!tion , Yes. , , , , , , , , _ _ _ " , _ , _ , , . '" , , , , , 30 ,BOPE,pre.ssra,tilJgappropriate;,testto.(pu,tpsigin,commeI1ts) , ." _, _", .Y~s", _" ,CalcuJa,t~d,I\lIASP1A22ps.i.,35.0Ppsi,apprORriate, .cPAlnormallyte.sts.t05QOPpsi., 31 ,Choke,manjfold cQrTJpJies. w/API.RP-5~ (May 84), , ,. , ,. _ , , . , , , , _ _ . . " ' , . , , , , ,.Y~s """,."" _ , " , " , , , , , , , " , .. ' _ _ _ , , . , , " , _ 32 VVQrk will occ,ur: withOLJt.operat.ion ,sbutdown, . . _ .. . , . ' . ' , . , ' , YeS, . .. _ , , . . _ , . . _ , , .. , , , , , . _ . _ _ . . _ _ . . , . , , , . _ , , 33 JS.Rres.ence.QfH2Sgas.prQbable., ",' ., _ _ _"'.".,' No.., _." ,Mud.s.h,ouldpr:eclude,tl2,S,Qn,rig., Rig.isequipped,wit.h,sens,ors,andalar:rns. ""." 34 Meçha,n[cal,cood.iti.on ot we.lls with.in AOR yerified (For,s"ervice welJ only), _ _ . .. , ' , . , NA , , , , , , _ , , , , .. ,. , , . , . . _ , ' . ' , . . , , _ _ , , , , . . , , .. , , _ _ , , - - - - - - . ~ - - - - - - - - - ~ - - - - . - - - - - - - - - .. - - - - ( Geology -...-.-.---,,-,.. -_._---------~._.._-_._--_. --------- .._....__h...'._'____._,__ _____.~..___ __ _.._..,~._____._h_."_._.____._ __,__..._._______ ~_._---_._--_._._._,--_._-_._---~_.__._-_.._...--,._----_._-_...-._~------ . , ----.-----.----.--.....------..--------.-.--..---".--.---_._------_.._.._--_...-...,--_.._.,,_._.~.._.._._----- Appr SFD Date 5/17/2004 Geologic Commissioner: 35 .Permit c,an Þe issuep w!Q hypr:ogen" s,ulfide. meaSUres. .. _ _ _ _ , _ , ' Yes , , .. KRU West s.al< W!3US, 1/4 miJe, to ea$t rn.ea$ur~dJe.ssth,an .$ppm.H.2$.in August ,2003,. , . 36.D_ata,presenteq on, Rote,ntial pveJRres,sur~ ,zOl1e.s, , , , , , _ ' . _ , , ' , . , Yes. . ' EXpected.r,es~r\lojr,pre,ssu.re i~ ,8..1.-_9,4,ppg EMW; wj.b~,drill.ep.w.itb 9.7 ppg mud. , , . 37 .Seismic,analysjs, Qf shallow gas,zPlJes, _ , ' _ _ , _ . _ _ , , ' , , ' , , , , . . . , _ _ , , NA , , . _ _ , ' , _ _ ' , , ' , , ' , _ , . , _ _ _ " , " "", _ _ _ , , , , ' , , , , , 38 ,Seab.eçl.col1d.itipo SUr\ley.(if of1-s.h'ore) .. .NA. _ , , , . , , . _ , , , " .""""". _ , . . ' , ' , .. , , , , _ , . , , , , , , ' 39 , CQnta.ct namelphoneJor.weelsly prpgre$s.reports [e~ploratpr:y .only], ,. , _ _ _ _ _ , , , , . , _ , NA. , _ , " ,_"",,".. ,. , . ' , , ' . , . ' . , _ . . _ _ ' , , , " ",'.'" _ . _ ' , , _ , , .. .. ~ - - - - .. Date: Engineering Commissioner: Public Commissioner Date Date Corrected Surface location for lE-123 & lE-123Ll -~ ~ Subject: Corrected Surface location for 1E-123 & lE-123Ll From: "McKeever, Steve" <Steve.McKeever@conocophillips.com> Date: Mon, 10 Ma¥ ~0~4.1_5:43:38 -,O~OO _ .' ...... _.'.""'... ...._ ... '.' ". .i .... To:- "Stévê l)avl¢s~(E~m~A9.~h~t~~e~~vies@ä~:sta~,~~~:h;c.:i:f¿;J'~};: h~ë~" -, .' CC:' "Allsup-Drake, Sharon K"·~Shar9n.K.AIIs11p-~è@èollocop.l#llWs.·;~o#I>'- Steve - The discrepancy you found on the permit paperwork for 1E-123 is indeed a mistake. You will find the same discrepancy on the paperwork for 1E-123L1. On the IIpermit It" documents I inadvertently wrote the surface location for the wrong well. The correct NAD 27 state plane coordinates for 1E-123 and 1E-123L1 are: X = 549,890 Y = 5,960,520. The legal descriptions (offsets from section lines) provided with the paperwork is accurate. Please find attached corrected copies of Page 2 for both IIpermit It" documents, with the correction highlighted in yellow. Please replace page 2 in the documents that you have with these pages. «lE-123 PERMIT IT Corrected.pdf» «lE-123L1 PERMIT IT Corrected.pdf» «112 123 126 166 As Staked.pdf» I have also attached a copy of the official "As-Staked" survey for 1E-123, completed by a professional land surveyor. My apologies for the inconvenience, and thanks for spotting this mistake. Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 IIGII Street Anchorage, Alaska 99501 RECEIVED MAY 1 2 2004 steve.mckeever@conocophillps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 Alaska Oil & Gas Cons. Commission Anchorage IIOne of the reasons people stop learning is that they become less and less willing to risk failure. II - John W. Gardner Content-Description: 1E-123 PERMIT IT lE-123 PERMIT IT Corrected.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ ._._..·___._.._m_____._...m_~·"...n___m_·___.____~__ ._~-_._--- ~~-~-- lE-123Ll PERMIT IT Content-Description: 1E-123Ll PERMIT IT Corrected.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 112_123_126_166 As Staked.pdf 112_123_126_166 As Staked.pdf Content-Type: application/octet-stream Content-Encoding: base64 umn__n__..__....___.__..________ _ . no u ___.__.._ _ __u _ . u...___ _0 _.___________~__ .. __..._._______.._.u_________ 1 of 1 5/12/2004 11 :16 AM - '--.../ Application for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: ,1 O-May-04 13. Proposed Drilling Program......................... ................. ............ ........... ..... ................ 6 Requirements of 20 AAC 25.005 (c)(13)... ........... .... ................... ........ ............ .......... ....... ........... ............ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14)..... ........... ....... ....... ....... .................. ..... .... ............. ..... ......... ......7 15. Attachments ......................................... .................................................................... 7 Attachment 1 Directional Plan (8 pages) ................................................................................................7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Well Schematic (1 pages) .... ....... ......... .......... ........ ......... ... ......... ... .......... ... ......... ............ 7 RECEIVED AAAV 1 D :001 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25. 040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Alaska Oil & Gas Cons. Commission Anchorage The well for which this Application is submitted will be designated as 1E-123Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Drill must be accompanied by each of the following ìtem~ except for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation; and at total depth referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUNey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,960,520 Eastings: 549,890 933' FSL, 6301 FEL, Section 16, T11N, R10E, UM RKB Elevation 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,963,975 Eastings: 554,600 924' FNL, 1169' FEL, Section 15, T11N, R10E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: 7,526 3,500 3,401 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,969,777 Eastings: 554,810 4031 FNL, 9081 FEL, Section 10, T11N, R10E, UM Measured Depth, RKB.· 13,340 Total Vertical Depth, RKB.· 3,679 Total Vertical Depth, Ss.· 3,580 and (D) other information required by 20 MC 25.050(b); 1 E-123L 1 PERMIT IT.doc Page 2 of 7 Printed: 10-May-04 REV DA TE BY CK APP r r-""'I 90 ~8 '-' "-"" REV DA TE BY CK' APP DESCRIPTION DESCRIPTION ---- ''';. ..J ~ f81 ~ 0 s~ \ /' <,~ ~ , ~ .v \. J '--------" IdJ ~ o 08J VICINITY MAP SCALE: 1" = 1 MILE 110 123- 07 126- 120 130 ~t8 150 160 'C' 06 ~ N 3485 04 180 190 03 200 210 02 220 230 01 24~ 112 33825 830 260 35 16 15 1190 21 22 RECEI D MAY 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage 029 166- 028 J ,) "- 027~ LEGEND o EXISTING CONDUCTORS . NEW CONDUCTOR LOCATION ßl LOUNSBURY &: ASSOCIATES. INC. S~EYORS ENGINEERS PLANNERS SEE SHEET # 2 FOR NOTES AND LOCATION INFORMATION ConocJPhillips Alaska, Inc. I DRAWING NO: 4/09/04 CADD FILE NO. LK6105D32 AREA: lE MODULE: XXXX UNIT: 01 D51E WELL CONDUCTOR 112, 123, 126, & 166 A5- 5T AKED LOCA TION5 NSK 6.105 - d32 I PART: 1 OF 2 I REV: 0 REV DATE BY CK APP DESCRIPTION ';... .I REV DATE BY CK - APP DESCRIPTION '-- , NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 3. ALL DISTANCES ARE TRUE. 4. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-E MONUMENTS PER LHD AND ASSOCIATES. 5. DRILL SITE 1-E GRID NORTH IS ROTATED O· 00' 31" EAST FROM GRID NORTH. 6. DATE OF SURVEY: 2/05, 4/23 & 4/24 2004 Sec. 16, T. 11 N., R. 1 0 E., UMIA T MERIDIAN Well A.S.P.s LATITUDE LONGITUDE SEC. SEC. PAD a.G. No. 'y' 'X' LI~E LI~E ELEV. ELEV. a S a S F.S.L. F.E.L. 112 5,959,780.7 550,300.6 70" 18' 03.20" 149" 35' 33.37" 191' 226' 66.3 63.1' 123 5,960,519.7 549,889.7 70" 18' 10.49" 149" 35' 45.20" 933~ 630' 70.7 65.1' 126 5,960,439.7 549,889.7 70" 18' 09.70" 149" 35' 45.22" 8531 631' 70.8 65.1' , ; Sec. 21, T. 11 N., R. 1 0 E., UMIA T MERIDIAN Well A.S.P.s LATITUDE LONGITUDE SEC. SEC. PAD a.G. No. 'y' 'X' LI~E LI~E ELEV. ELEV. a S a S F. N. L. F.LL. 166 5,959,439.8 549,889.6 70" 17' 59.87" 149" 35' 45.42" 147' 640' 70.4 63.4' RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage Øl LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PlANNERS ~ AREA:1E MODULE:XXXX UNIT: D1 DS1E WELL CONDUCTOR 112, 123, 126, & 166 AS-STAKED LOCATION NSK 6.105 - d32 I PART: 2 OF 2 I REV: 0 ConocJP'hillips Alaska, Inc. I ORA WING NO: 4/09/04 CAOO FILE NO. LK6105D32 ~~ -' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill 0 Re-entry 0 1b. Current Well Class: Stratigraphic Test 0 RedrillU 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surtace:933'FSL,630'FEL,Sec. 16,T11N,R10E, UM Top of Productive Horizon: 924' FNL, 1169' FEL, Sec. 15, T11 N, R10E, UM Total Depth: 403' FNL, 908' FEL, Sec. 10, T11 N, R10E, UM 4b. Location of Well (State B~se Plane;o~~rtes): 5"?fAD"S2.f) Surtace: x- ~ 1· IVy_ .~ Zone- 4 16. Deviated wells: '1/. q )'t> . Kickoff depth: 7526 ft. Maximum Hole Angle: ~ -;, .¡t;' /A 18. Casing Program Size Specifications Grade Coupling K-55 Weld L-80 BTC L-80 STCM L-80 Grant Hole Casing Weight 42" 20" x 34" 94# 13.5" 10.75" 45.5# 9-7/8" 7-5/8" 29.7# 6.75" 4.5" 12.6 19 Total Depth MD (ft): PRESENT WELL CONDITION SUM RY Total Depth TVD (ft): Plugs ( asured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Structural Conductor Surtace Intermediate Production Liner Pertoration Depth MD (ft): RECEIVED MAY 032004 Alalka nil & Gas Con~ r.""OO· . ExploratoryU Development Oil 0 ''I\7ICJltlþ'lUo;re~E¥' Service 0 Development Gas D Anchoragltingle Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and umber: Bond No. 59-52-180 -123L 1 6. Proposed Depth: 12. Fiel ool(s): 13340' MD 3679' TVD paruk River Field 7. Property Designation: . ALK 25651 & 25648 8. Land Use Permit: ADL 469 & 466 9. Acres in Property: 10. KB Elevation 28' RKS 17. Anticipa Pressure (see 20 MC 25.035) hole Pressure: 1834 psig Setting Depth Bottom TVD MD TVD 28' 108' 108' 28' 3860' 2200' 28' 7902' 3474' 28' 13340' 3679' Cement Volume Contact Steve McKeever @ 265-6826 Title Kuparuk Drilling Team Leader Phone 4s-,;..- 6Ð 3 () Date ~/3/o?" PreDared bv Sharon AlIsuD-Drake BOP Sketch 0 Diverter Sketch 0 Drilling Program 0 Seabed Report 0 20. Attachments: Filing Fee Property Plat 21. Verbal Approval: Commissi 22. I hereby certify that the for oing is true and correct to the best of my knowledge. Signature '~~ Commission Use Only Permit Approval Permit to Drill Number: API Number: 50- OdS -c) 3dCf;-~ 0 DYes BNO o Yes~o Conditions of approval : Samples required Hydrogen sulfide measures Other: :"SùD\Çs \ \~~~\ 'N\..\.J~'\SC)V' .-\c~ ~ Approved by: MD Perforation Depth TVD (ft): Time v. Depth Plot D Drilling Fluid Program 0 Date: Date: Mud log required Directional survey required COMMISSIONER BY ORDER OF THE COMMISSION Form 10-401 Revised 3/2003 · DUPLICATE West Sak Pool 13. Approximate Spud Date: 5/14/2004 14. Distance to Nearest Property: 908" @ TD 15. Distance to Nearest Well Within Pool: 18-101/104' @ 13291' / Max. Surface Pressure: 1422 psig Quantity of Cement c. 1. or sacks (including stage data) 260 cf ArcticCrete 770 sx AS Lite, 180 sx DeepCrete 160 sx DeepCrete slotted liner TVD Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 See cover letter for other requirements o Yes ~ No ß.yes 0 No Date: Submit in duplicate 1E-123L 1 PERMIT IT. doc Page 1 of 7 Printed: 2-May-04 DUPLICATE 12. Evidence of Bond i ng ...... .... ....... ........... ..... .......... ......... ........ ........... ..... ........... ........ 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 10. Seismi c Analysis..... ......... ........... ..... .... ........... ....... ..... .... ...... ... .... ............... ..... ... ..... 5 Requirements of 20 AAC 25.005 (c) (1 0) ................................................................................................ 5 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 8. Dri II ing FI uid Program ..... .... ....... ................ ...... ...... .... .......... ..... .... ..... ..................... 5 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 6. Casi ng and Cementi ng Program .... ....... ........... .......... ................ ............... .............. 4 Requirements of 20 AAC 25.005(c)(6) .. .................. ............ ...... ................. ........................... ................. 4 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 4. Dri II i ng Hazards Informati on . ........ ............... .... .......... ..... ...... ............... ..... .............. 3 Requirements of 20 AAC 25.005 (c)( 4) .......... ......... ........ ............... .............................................. .......... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005( c)(3) . ................ .................... ........ ............ .......................................... 3 2. Location Sum mary .... ... ........... ........ .... ......... ..... ........ ... .......... ........ ..... ...... ....... .... ....2 Requirements of 20 AAC 25.005(c)(2) ...;....... ........... ............... ........ ....... ..... ............................... ..... ...... 2 Requirements of 20 AAC 25. 050(b )........... ................... .................................. .............. ......... ................. 3 1. Well Name.... ............. ........... ........ .... ... ..... ... ..... .... ...... ... ............ ......... ...... ..... ........ .... 2 Requirements of 20 AAC 25.005 (f)....... ...................................................... ................. ......... ........... ......2 Table of Contents Application for Permit to Drl'll Document Permit It - West Sak Well #1 E-123L 1 A¡:. ,lion for Permit to Drill , Well 1 E-123L1 '- Revision No.O Saved: 2-May-04 Application for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 2-May-04 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AA C 25.005 (c)( 14) ................................................................................................ 7 1 5. A tta c h m e nts ............................................................................................................. 7 Attachment 1 Directional Plan (13 pages) .............................................................................................. 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Cement Loads and CemCADE Summary (2 page) ........Error! Bookmark not defined. Attachment 4 Well Schematics (5 pages)........................ ......................................... .............................7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well mu~t be Identified by a unique name designated by the operator and a unique API number assIgned by the commissIon under 20 MC 25. 040(b). For a well wIth multiple well branches¡ each branch must sirmlarly be identIfied by a unIque name and API number by addIng a suffìx to the name designated for the well by the operator and to the number assigned to the well by the commissIon. The well for which this Application is submitted will be designated as lE-123Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Dr/II must be accompanied by each of the followIng Item~ except for an Item already on file with the commIssion and identified in the app/lcatlon: (2) a plat IdentIfyIng the property and the property's owners and sl]()wlng (A)the coordinates of the proposed locatIon of the well at the surface/ at the top of each objectIve formation and at total depth/ referenced to governmental sedlon lines. (8) the C"Oordlnates of the proposed location of the well at the surface/ referenced to the state plane coordinate system for thís state as maIntained by the Natíonal Geodetic Survey in the National OceanIc and Atmospheric Administration/ (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,781 Eastings.· 550,301 933' FSL, 630' FEL, Section 16, TllN, Rl0E, UM RKB Elevation 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAO 27 Coordinates Northings: 5,963,975 Eastings: 554,600 924' FNL, 1169' FEL, Section 15, TllN, Rl0E, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth 55: 7,526 3,500 3,401 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,969,777 Eastings: 554,810 403' FNL, 908' FEL, Section 10, TllN, R10E, UM Measured Depth/ RKB.' 13,340 Total Vertical Depth/ RKB.' 3,679 Total Vertical Depth 55.' 3,580 and (0) other information required by 20 MC 2S.0S0(b)/ . ~ c r: 1 Ç0 A1, E;'?1Y ","\"" \·'.~,\,,'l'!P ill," ~ lb , ;'C: ;'¡o;ø'fZ ' Q tb ',~jJ~t ~ ' ~J 1E-123L1 PERMIT IT. doc Page 2 of 7 Printed: 2-May-04 " , .~- ,ppJication for Permit to Drill, Well 1 E-123L 1 -- Revision No.O Saved: 2-May-04 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect tl7e application for a Permit to Drill (Fonn 10-401) must (1) include a plat drawn to a suitable scale" showing the path of the proposed wellbore" including all adjacent wellbores within 200 feet of any portion of the proposed welf,,' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells" to the extent that those names are known or discoverable in public records" and show that each named operator has been furnished a copy of the application bycertified mail/ or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fol/owing items" except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equípment (80PE) as required by 20 MC 25. 035, 20 MC 25.036, or 20 MC 25. 037, as applicable/ An API 13-5/8" x 5/000 psi BOP stack (RSRRA) will be utilized to drill and complete well lE-123Ll. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items" except for an item already on file with the commission and Identified in the application: (4) information 017 drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient,,· The expected reservoir pressures in the West Sak sands in the lE-123Ll area vary from 0.42 to 0.49 psi/ft/ or 8.1 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1/422 psi, calculated thusly: MPSP =(3/742 ft)(0.49 - 0.11 psi/ft) =1/422 psi (8) data on potential gas zones/ The well bore is not expected to penetrate any gas zones. and (C) data concermi7g potential causes of hole problems such as abnormally geo-pressured strat0 lost circulation zones, and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dnll must be accompanied by each of the foJ/owing items" except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity te~ as required under 20 MC 25. 030(f)/ The parent wellbore/1E-123, will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. DUPliCATE 1E-123L1 PERMIT IT. doc Page 3 of 7 Printed: 2-May-04 Ap, .ion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 2-May-04 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030/ and a description of any slotted line~ pre- perforated line~ or screen to be installed; Casing and Cementing Program See also Attachment 3, APD for lE-123: Cement Summary Hole Size (in) 42 6-3/4" Lower Lateral (lE-123) 4-1/2 6-3/4" slotted Upper Lateral (lE-123 L1) 7. Diverter System Information Requirements of 20 AAC 25. 005(c) (7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25.035; unless this requirement is waived by the commission under 20 MC 25.035(h)(2}; CsglTbg 00 (in) 20 X 34 10-3/4 13-1/2 7-5/8 9-7/8 4-1/2 slotted Weight (Ib/tt) 94 Length (tt) 80 Top MolTVo (ft) 28 / 28 Btm MolTVo (ft) 108 / 108 Grade K55 Connection Welded 45.5 L-80 28 / 28 3860 /2200 BTC 3832 29.7 L-80 28 / 28 7902/ 3474 BTCM 7874 12.6 7566/ 3510 13,345 / 3742 L-80 Grant Prideco DWC/C 5779 12.6 75261 3500 13340 I 3679 L-80 Grant Prideco DWCIC 5814 No diverter system will be utilized during operations on 1E-123L1 .", ,,~~q íi\(", Al'1{=t-.··. \:~; ~\ LYU '~... w. f] [' ,..{ f\ , t-'..A .<.. \!ì. _.~ :.~/ ~~~):i ~=:J ~ Cement Program Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 770 sx ASLite Lead, 180 sx DeepCRETE Tail Cement Top planned @ 70001 MD / 33481 TVD. Cemented w / 160 sx DeepCRETE Slotted- no cement Slotted- no cement 1E-123L1 PERMIT IT. doc Page 4 of 7 Printed: 2-May-04 \ ---,,/ Afo, -- .tion for Permit to Drill, Well 1 E-123L 1 Revision No.O Saved: 2-May-04 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file ¡"11th the comml:çsion and identified in the application: (8) a drilling fluid program/ including a diagram and description of tile drilling fluid systel7"t- as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI FloPro NT) BID sand laterals Initial Value Final Value 9.7 9.7 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) Tau 0 Chlorides (mgll) pH API filtrate (cc 130 min) **HTHP filtrate (cc 130 min) MBT (Ib I gal) ***Solids (% Vol) 22-30 22-30 8-12 8-12 4-7 4-7 65-80K 65-80K 8-9.5 8-9.5 <6 <6 <10 <10 <5 <5 <6-9 <6-9 ** HTHP to be run at 800 F .... The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Drill must be accompanied by each of the fOllowIng item~ except for an Item already on file with the commission and identified in the application: (9) for an exploratory or stratigrapl7ic test well a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f}; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well a seismic refradion or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the foJlowing item~ except for an item already on file wIth the commission and Identified in the application.' DUPLICATE 1 E-123L 1 PERMIT IT. doc Page 5 of 7 Printed: 2-May-04 APt .íon for Permit to Drill, We1l1E-123L1 Revision No.O Saved: 2-May-04 (11) for a well drilled from an o(f:,770re platform, mobile bottom-founded structure" jack-up rig" or floating dri//1i1g vesse¿ an analysis of seabed conditions as required by 20 MC 25:061(b),· Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items" except for an item already 017 file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding)have been met,,· Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items" except for an item already on file wIth the commission and Identified in the application: The proposed drilling program for lE-123 L1 is listed below. Please refer also to Attachment 5, Well Note: Previous operations are covered under the lE-123 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7,526' MD / 3,500' lVD, the top of the D sand. 2. Displace hole to used mud from lower lateral at 9.7 ppg. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Displace to new drilling mud at 9.7 ppg. Drill to TD of D sand lateral at 13,340' MD / 3,679' lVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. 10. POOH, laying down drill pipe as required. 11. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Set BPY and move rig off. 14. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Rig up wire line unit. Pull BPV 16. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 17. Replace gas lift valves with dummies. 18. Run ESP through tubing. 19. Operate well with ESP. C8~ ~[)~ "n:'r #~\1fff 'c-'/ ~'"'" ¡.¡ '{ ¡ ',-,> Í","O_~ 'I ~L ¡~ ..~ h.i tkJ.- ~~ ~ u f±.- 1£-123L1 P£RMIT IT. doc Page 6 of 7 Printed: 2-May-04 -- '. ,pplication for Penn it to Drill, Well 1 E-123L 1 ---- Revision No.O Saved: 2-May-04 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Drill mustc be accompanied by each of the following items; except for an item already on file with the commission and Identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator li7tends to request authorization under 20 AAC 25.080 for an annular disposal operation jn the wel/./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan (8 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Well Schematic (1 pages) DUPl!(AIE 1E-123L1 PERMIT IT. doc Page 7 of 7 Printed: 2-May-04 '- '- ConoccrPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska Well bore Name 1E-123L 1 Well Name 123 Slot Name Slot #123 Installation Name Pad 1 E Field Name KUDaruk River Unit CÎ"~åtedBY' . Cómmehts· PROPOSAL liSTING Page 1 Wellbore: 1 E-123L 1 Well path: 1 E-123L 1 Ver#3 Date Printed: 22-Apr-2004 'Created 29-Jan-2004 'Last Revised 21-Apr-2004 I Government 10 'I Last Revised 29-Jan-2004 'Grid NorthinQ 5960520.0000 I Grid EastinQ 549890.0000 'Latitude N70 18 10.4942 , LonQitude . W149 35 45.1962 'North 933,25N ,.&1. BAKER HUGHES INTEQ - J East , 632.00W , Fastina 550528.1946 I Northínq 5959591.1090 t Coord System Name " North Aliqnment AK-4 on NORTH AMERICAN DATUM 1927 datum True I Fastinq 487754.6208 I Northina 5948985.fj?06 I Coord SYStem Name (North Alianment AK-4 on NORTH AMFRICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method ·uses Minimum Curvature method Prepared by Baker Hughes Incorporated 0\.':'.\ fi f~l~ gr.·. L\ Tit Jlt1lt'¡,Bt~BJA ~ ~ ConocÓPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 1 E-123L 1 Wellpath: 1 E-123L 1 Ver#3 Date Printed: 22-Apr-2004 '''i BAKER MUGIo! INTEQ W.éUÞath,(3~id)iRêPQrt MD[ftJ Iric[deg] Azi[deg} TVD[ft] Dogleg Vertic@ rdeQ/tOOftl $ectionrft1 7526.09 75.00 3,65 3500.00 3423.99N 4733.31E 0.00 3718.53 554600.00 5963975.00 7538.09 76.91 3.65 3502.91 3435.61 N 4734.05E 15.90 3730.17 554600.66 5963986.62 7556.09 76.91 3.65 3506.99 3453.11N 4735.17E 0.00 3747.71 554601.66 5964004.13 7656.09 82.91 3,65 3524.50 3551.31 N 4741.44E 6.00 3846.11 554607.28 5964102.37 7756,09 88.91 3.65 3531.64 3650.81 N 4747.78E 6.00 3945.81 554612.97 5964201.89 7756.28 88.92 3.65 3531.64 3651.00N 4747.80E 6.00 3946.00 554612.98 5964202.08 7856.28 91.92 3.65 3530.91 3750.78N 4754.17E 3.00 4045.99 554618.69 5964301.89 7856.34 91.92 3.65 3530.90 3750.85N 4754.17E 3.00 4046.05 554618.69 5964301.96 7900.00 91.92 3.65 3529.44 3794.39N 4756.95E 0.00 4089.68 554621.18 5964345.51 7992.61 91.92 3.65 3526.33 3886.76N 4762.85E 0.00 4182.24 554626.46 5964437.91 8092.61 88.92 3.65 3525.60 3986.54N 4769.21E 3.00 4282.23 554632.17 5964537.73 8100.00 88.92 3.65 3525.74 3993.92N 4769.68E 0.03 4289.62 554632.59 5964545.10 8200.00 88.92 3.65 3527.62 4093.70N 4776.05E 0.00 4389.60 554638.29 5964644.91 8300.00 88.92 3.65 3529.51 4193.48N 4782.42E 0.00 4489.58 554644.00 5964744.72 8400.00 88.92 3.65 3531.39 4293.25N 4788.79E 0.00 4589.56 554649.70 5964844.53 8500.00 88.92 3.65 3533.28 4393.03N 4795.16E 0.00 4689.55 554655.41 5964944.34 8600.00 88.92 3.65 3535.16 4492.81 N 4801.52E 0.00 4789.53 554661.11 5965044.15 8700.00 88.92 3.65 3537.05 4592.59N 4807.89E 0.00 4889.51 554666.82 5965143.96 8800.00 88.92 3.65 3538.93 4692.37N 4814.26E 0.00 4989.49 554672.52 5965243.77 8900.00 88.92 3.65 3540.82 4792.15N 4820.63E 0.00 5089.47 554678.23 5965343.58 9000.00 88.92 3.65 3542.70 4891.93N 4827.00E 0.00 5189.46 554683.93 5965443.39 9100.00 88.92 3.65 3544.59 4991.71 N 4833.37E 0.00 5289.44 554689.64 5965543.20 9200.00 88.92 3.65 3546.47 5091.49N 4839.73E 0.00 5389.42 554695.34 5965643.00 9300.00 88.92 3.65 3548.35 5191.27N 4846.10E 0.00 5489.40 554701.05 5965742.81 9334.25 88.92 3.65 3549.00 5225.44N 4848.28E 0.00 5523.65 554703.00 5965777.00 9360.47 88.13 3.65 3549.67 5251.60N 4849.95E 3.00 5549.86 554 704.49 5965803.17 9400.00 88.13 3.65 3550.96 5291.03N 4852.4 7E 0.00 5589.37 554706.75 5965842.61 9500.00 88.13 3.65 3554.22 5390.77N 4858.83E 0.00 5689.31 554712.44 5965942.38 9600.00 88.13 3.65 3557.48 5490.52N 4865.19E 0.00 5789.26 554718.14 5966042.15 9700.00 88.13 3.65 3560.73 5590.26N 4871.55E 0.00 5889.21 554723.84 5966141.93 9800.00 88.13 3.65 3563.99 5690.01 N 4877.90E 0.00 5989.16 554729.53 5966241.70 9900,00 88.13 3.65 3567.25 5789.75N 4884.27F 0.00 6089.10 554735.23 5966341.48 10000.00 88.13 3.65 3570.51 5889.49N 4890.63E 0.00 6189.05 554740.93 5966441.25 10100.00 88.13 3.65 3573.76 5989.24N 4896.98E 0.00 6289.00 554746.62 5966541.03 10200.00 88.13 3.65 3577.02 6088.98N 4903.34F 0.00 6388.94 554752.32 5966640.80 10300.00 88.13 3.65 3580.28 6188.73N 4909.70E 0.00 6488.89 554758.02 5966740.58 10400.00 88.13 3.65 3583.53 6288.4 7N 4916.06E 0.00 6588.84 554 763. 71 5966840.35 10500.00 88.13 3.65 3586.79 6388.22N 4922.42E 0.00 6688.78 554769.41 5966940.13 10600.00 88.13 3.65 3590.05 6487.96N 4928.78E 0.00 6788.73 554775.11 5967039.90 10700.00 88.13 3.65 3.593.31 6587.70N 4935.14E 0.00 6888.68 554780.81 5967139.67 10800.00 88.13 3.65 3596.56 6687.45N 4941.50E 0.00 6988.63 554786.50 5967239.45 10900.00 88.13 3.65 3599.82 6787.19N 4947.86E 0.00 7088.57 554792.20 5967339.22 11000.00 88.13 3.65 3603.08 6886.94N 4954.22E 0.00 7188.52 554797.90 5967439.00 11100.00 88.13 3.65 3606.34 6986.68N 4960.58E 0.00 7288.4 7 554803.59 5967538.77 11200.00 88.13 3.65 3609.59 7086.43N 4966.94E 0.00 7388.41 554809.29 5967638.55 11212.48 88.13 3.65 3610.00 7098.88N 4967.74E 0.00 7400.89 554810.00 5967651.00 11300.00 88.63 1.07 3612.47 7186.28N 4971.34F 3.00 7488.34 554813.02 5967738.42 11327.60 88.78 0.25 3613.10 7213.87N 4971.65E 3.00 7515.90 554813.15 5967766.01 11400.00 88]8 0.25 3614.64 7286.25N 4971.98E 0.00 7588.15 554813.00 5967838.38 11500.00 88.78 0.25 3616.76 7386.23N 4972.42F 0.00 7687.95 554812.78 5967938.35 11600.00 88.78 0.25 3618.89 7486.20N 4972.87E 0.00 7787.76 554812.56 5968038.32 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method ~ '" P~ep~red byB@1>~ Hughes Incorporated .'\\~ ~~U i(~ at ;~~ur'j'~ 1 ~/ '- f' &'. " -~ '-- --- Conoc~illips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 1 E-123L 1 Well path: 1 E-123L 1 Ver#3 Date Printed: 22-Apr-2004 r,Cit. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing fdeQ/100ft1 Sectionfft1 11700.00 88.78 0.25 3621.01 7586.18N 4973.31F 0.00 7887.56 554812.34 5968138.?8 11800.00 88.78 0.25 3623.14 7686.16N 4973.76E 0.00 7987.36 554812.12 5968238.25 11900.00 88.78 0.25 3625.27 7786.13N 4974.20E 0.00 8087.16 554811.90 5968338.22 12000.00 88.78 0.25 3627.39 7886.11N 4974.65F 0.00 8186.96 554811.68 5968438.19 12100.00 88.78 0.25 3629.52 7986.09N 4975.09E 0.00 8286.76 554811.46 5968538.15 12200.00 88.78 0.25 3631.64 8086.06N 4975.53E 0.00 8386.57 554811.24 5968638.12 12300.00 88.78 0.25 3633.77 8186.04N 4975.98F 0.00 8486.37 554811.02 5968738.09 12310.92 88.78 0.25 3634.00 8196.95N 4976.03E 0.00 8497.26 554811.00 5968749.00 12371.17 86.98 0.39 3636.23 8257.17N 4976.37E 3.00 8557.38 554810.94 5968809.21 12400.00 86.98 0.39 3637.75 8285.95N 4976.57E 0.00 8586.11 554810.95 5968837.98 12500.00 86.98 0.39 3643.02 8385.79N 4977.26E 0.00 8685.79 554810.97 5968937.82 12600.00 86.98 0.39 3648.28 8485.63N 4977.94E 0.00 8785.47 554811.00 5969037.65 12686.59 86.98 0.39 3652.85 8572.07N 4978.54E 0.00 '8871.78 554811.02 5969124.09 12700.00 87.38 0.34 3653.51 8585.4 7N 4978.62E 3.00 8885.15 554811.01 5969137.48 12711.53 87.72 0.29 3654.00 8596.99N 4978.69E 3.00 8896.65 554811.00 5969149.00 12800.00 87.72 0.29 3657.52 8685.39N 4979.13E 0.00 8984.90 554810.86 5969237.39 12900.00 87.7/ 0.29 3661.50 8785.31N 4979.64F 0.00 9084.65 554810.70 5969337.30 13000.00 87.72 0.29 3665.47 8885.23N 4980.14E 0.00 9184.40 554810.54 5969437.22 13100.00 87.72 0.29 3669.45 8985.15N 4980.64F 0.00 9?84.15 554810.38 5969537.13 13200.00 87.72 0.29 3673.43 9085.07N 4981.15F 0.00 9383.90 554810.22 5969637.04 13300.00 87.72 0.29 3677.41 9184.99N 4981.65E 0.00 9483.65 554810.06 5969736.95 13340.09 87.72 0.29 3679.00 9225.04N 4981.85F 0.00 9523.63 554810.00 5969777.00 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28;37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~UPlICATE ConocóPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 1E-123L 1 Wellpath: 1 E-123L 1 Ver#3 Date Printed: 22-Apr-2004 r~.. BAKER HUGHES INTEQ Comments MDfft ITVDrftl 633.33 631.64 833.33 824.58 1641.50 1386.40 5036.02 2631.05 5844.49 2931.99 6375.48 3126.67 6575.48 3200.00 7426.09 3474.12 7526.09 3500.00 7526.10 3500.00 7538.09 3502.91 7556.09 3506.99 7756.28 3531.64 7856.34 3530.90 7992.61 3526.33 8092.68 3525.60 9334.25 3549.00 9360.47 3549.67 11212.48 3610.00 11327.60 3613.10 12310.92 3634.00 12371.17 3636.23 12686.59 3652.85 12711.53 3654.00 13340.09 3679.00 HôlèSéötiôns Start MOfftl 0.00 3860.43 7526.09 13 1/2 97/8 63/4 Northrftl 12.26N 34.11 N 265.37N 1600.04N 2058.53N 2443.00N 2587.81N 3327.60N 3423.99N 3423.99N 3435.61N 3453.11N 3651.00N 3750.85N 3886.76N 3986.61 N 5225.44N 5251.60N 7098.88N 7213.87N 8196,95N 8257.17N 8572.07N 8596.99N 9225.04N Stärt TV Drftl 0.00 2200.00 3500.00 Top MOfftl 10 3/4in Casino 0.00 7 5/8in Casinç.¡ 0.00 Top TVOrftl 0.00 0.00 ]argeís Name ws 1EX5 D-FLT1S RVSD031804 WS1EX5DTOE 9225,04N RVSD021804 WS 1E X5 D-FLT1N 8596.99N RVSD031804 Eastrftl 26.30E 73.15F 569.09E 3431.30E 4017.08F 4327.30E 4444.15E 4727.16F 4733.31E 4733.31 E 4734.05E 4735.17E 4747.80E 4754.17E 4762.85E 4769.22E 4848.28F 4849.95E 4967.74E 4971.65F 4976.03F 4976.37E 4978.54F 4978.69F 4981.85E Comment Bid 5/100 Bid 6/100 EOG Tm 3/100 FOG Start 200' Pumo Tanaent End 200' Pump Tanç¡ent, Bldrrm 4/100 FOG Tie to 1E-123 Top Whipstock Face Base Whipstock Face End Milled Open hole. Bid 6/100 Bid 3/100 EOC Drop 3/100 EOG Drop 3/100 FOG Bldrrm 3/100 FOG Droorrm 3/100 EOG Bldrrm 3/100 FOG TO, 4 1/2 Liner Pt. Start Northrftl O.OON 1137.82N 3423,99N Top Northrftl O.OON O.OON Eastrftl O.OOE 2440,05E 4733.31E Northrftl 1137.82N 3796.53N 9225.04N Eastrftl 2440.05E 4757.09E 4981.85E 1E-123 1F-123 1F-123L 1 1 E-123 1 E-123 4981.85E 3679.00 19 19.951 N70 19 41.205~ W149 33 19.761 N70 19 35.028t W149 33 19.866 554811.00 554810.00 554811.00 4978.69E 3654.00 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated DUPLICATE 5969777.00 5969149,00 ',- '-----" ConocJ"'Phillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Well bore: 1 E-123L 1 Wellpath: 1 E-123L 1 Ver#3 Date Printed: 22-Apr-2004 J&ii. BAKER HUGHES INTEQ Taraets Name Northrftl Fastrftl rvDrftl WS 1 E X5 7098.88N 4967.74E 3610.00 N70 19 20.294f W149 33 20.214 554810.00 5967651.00 D-MDPT#2 RVSD021804 WS 1 E X5 5225.44N 4848.28E 3549.00 N70 19 1.870E W149 33 23.736 554703.00 5965777.00 D-MDPT#1 RVSD021804 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated DUPLICATE rDg ~r t1 V~ '; fk~ V:;9J]J~ ~ tk Normal Plane Travelling Cylinder· Feet All depths shown are Measured depths on Reference Well 170 180 190 160 200 150 210 60 130 230 140 220 120 240 110 250 100 260 90 ¡ f i 240 \ 270 80 280 70 290 300 50 310 40 TRUE NORTH 350 0 10 340 20 330 30 ~ 320 Created by: Planner Date ploUed: 22-Apr-2004 Plot reference is 1 E-123L 1. Ref well path is 1E-123L 1 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are referenca Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. Conoc;Phillips Slot: Slot #123 Well: 123 Wellbore: 1 E-123L 1 Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E RiW BAKU HUOH£5 ÍNTfÕ------- ConocoPhillips Alaska, Inc. .-..- '--' Baker Hughes Incorporated Anticollision Report Company: Field: Reference· Site: Reference Well: Reference Wel.lpath: ConocoPhillips Alaska. Inc. Kuparuk River Unit Pad 1 E 123 1E-123L1 Date: 4/22/2004 Time: 13:31 :03 Page: ,Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 123. True Nòi1h ,Wellhead(99') 99.0 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 7526.08 to 13340.00 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Db: . Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/23/2004 Validated: No Planned From To Survey ft ft 4.00 7526.08 Planned: 1E-123 VER#3 V15 (0) 7526.08 13340.00 Planned: 1E-123 L 1 VER#3 V10 Version: 0 Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Casing Points MD TVD Diameter Hole Size Name ft ft in in 7526.08 3500.00 7.625 9.875 75/8" 13340.00 3679.00 4.500 6.750 41/2" Summary < - Offset Wellpatb ----> Reference Offset Ctr~CtT . No-Go- AJlowidJle Site Well Wellpath MD MD -- .Distance Areå Deviation Warning ft ft ft ft ft Pad 1 B 101 1B-101 V3 13291.13 6625.00 103.80 0:00 103.80 Pass: Minor 1/200 Pad 1 B 101 1B-101L1 V3 13291.13 6625.00 103.80 No Offset Casings Pad 1 B 101 1B-101PB1 V6 12662.76 3100.00 3300.12 0.00 3300.11 Pass: Minor 1/200 Pad 1 E 10 1 E-10 VO Out of range Pad 1 E 102 102 B-Lateral VO Plan: 13031.05 12072.67 682.94 0.00 682.94 Pass: Minor 1/200 Pad 1 E 102 102 D-Lateral VO Plan: 13028.90 12067.88 680.14 No Offset Casings Pad 1 E 103 103 VO Plan: 1E-103 VE Out of range Pad 1 E 104 104 VO Plan: 1E-104 VE Out of range Pad 1 E 105 105 A2-Lateral VO Plan Out of range Pad 1 E 105 105 B-Lateral VO Plan: Out of range Pad 1 E 105 105 D-Lateral VO Plan: Out of range Pad 1 E 11 1E-11 VO Out of range Pad 1 E 112 112 A2-Lateral VO Plan Out of range Pad 1 E 112 112 B-Lateral VO Plan: Out of range Pad 1 E 112 112 D-Lateral VO Plan: Out of range Pad 1 E 114 114 A2-Lateral VO Plan 8208.87 11630.91 1085.32 399.00 686.31 Pass: Major Risk Pad 1 E 114 114 B-Lateral VO Plan: 8205.57 11614.38 1053.79 399.53 654.25 Pass: Major Risk Pad 1 E 114 114 D-Lateral VO Plan: 8204.52 11609.03 1049.67 403.57 646.10 Pass: Major Risk Pad 1 E 117 117 A2-Lateral VO Plan Out of range Pad 1 E 117 117 B-Lateral VO Plan: Out of range Pad 1 E 117 117 D-Lateral va Plan: Out of range Pad 1 E 119 119VO Plan: 1E-119Ve Out of range Pad 1 E 1 1 E-01 VO Out of range Pad 1E 1 1 E-01A VO Out of range Pad 1 E 121 121 B-Lateral VO Plan: 13278.03 11675.00 1538.96 700.96 838.00 Pass: Major Risk Pad 1 E 121 121 D-Lateral va Plan: 13280.82 11675.00 1537 :05 670.82 866.24 Pass: Major Risk Pad 1 E 12 1 E-12 VO Out of range Pad 1 E 123 1E-123 V4 Plan: 1E-123 7549.99 7550.00 0.60 145.95 -145.36 FAIL: Major Risk Pad 1 E 126 126 A2-Lateral va Plan Out of range Pad 1E 126 126 B-Lateral va Plan: Out of range Pad 1 E 126 126 D-Lateral VO Plan: Out of range Pad 1 E 13 1E-13VO Out of range Pad 1 E 14 1 E-14 VO Out of range Pad 1 E 15 1 E-15 VO Out of range Pad 1E 16 1 E-16 VO Out of range Pad 1 E 166 166 A2-Lateral VO Plan Out of range Pad 1 E 166 166 B-Lateral VO Plan: Out of range Pad 1 E 166 166 D-Lateral va Plan: Out of range Pad 1 E 168 168 A2-Lateral V3 Plan Out of range Pad 1 E 168 168 B-Lateral va Plan: Out of range Pad 1 E 168 168 D-Lateral VO Plan: Out of range Pad 1 E 170 170 A2-Lateral VO Plan Out of range Pad 1 E 170 170 B-Lateral VO Plan: Out of range DUPLICATE Baker Hughes Incorporated Anticollision Report Company: ConocoPhillips Alaska, Inc. Date: 4/22/2004 Time: 13:31;03 Page: 2 Field: Kuparuk River Unit Reference Site: Pad 1 E Co-ordinate(NE) Reference: Well: 123, True North Reference Well: 123 Vertical (TVD) Reference: Wellhead(99') 99.0 Reference Wellpath: 1E-123L1 Db: Oracle Summary < -Offset Wellpath - -> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wel/path MD MD Distance Area Deviation Warning ft ft ft ft ft Pad 1 E 170 170 D-Lateral VO Plan: Out of range Pad 1 E 17 1E-17VO Out of range Pad 1 E 18 1 E-18 VO 7526.08 7300.00 3872.50 165.31 3707.19 Pass: Major Risk Pad 1 E 19 1 E-19 VO Out of range Pad 1 E 20 1 E-20 VO Out of range Pad 1 E 21 1 E-21 VO Out of range Pad 1 E 2 1 E-02 va Out of range Pad 1 E 22 1 E-22 va Out of range Pad 1 E 23 1 E-23 va Out of range Pad 1 E 24 1 E-24 va Out of range Pad 1 E 24 1 E-24A va Out of range Pad 1 E 25 1 E-25 va Out of range Pad 1 E 26 1 E-26 va Out of range Pad 1 E 26 1 E-26A VO Out of range Pad 1 E 27 1 E-27 VO Out of range Pad 1 E 28 1 E-28 va Out of range Pad 1 E 29 1 E-29 va Out of range Pad 1 E 30 1 E-30 va Out of range Pad 1 E 31 1 E-31 V1 Out of range Pad 1 E 31 1E-31PB1 va Out of range Pad 1 E 3 1 E-03 V1 Out of range Pad 1 E 32 1 E-32 va Out of range Pad 1 E 33 1 E-33 va Out of range Pad 1 E 33 1 E-33PB1 va Out of range Pad 1 E 34 1 E-34 va Out of range Pad 1 E 35 1 E-35 va Out of range Pad 1 E 35 35A va Plan: 35A ST Ve Out of range Pad 1 E 36 1 E-36 va Out of range Pad 1 E 4 1 E-04 va Out of range Pad 1 E 5 1 E-05 va Out of range Pad 1 E 6 1 E-06 va Out of range Pad 1 E 7 1 E-07 va 7526.08 7825.00 2239.08 103.19 2135.88 Pass: Major Risk Pad 1 E 8 1 E-08 V1 Out of range Pad 1 E 9 1 E-09 va Out of range Pad 1 E WSR#2 WS2 V1 Out of range =- {, ~~..~ ; r.......'... '\ ~ ~ t't"? h~~: t! C ::- k, "tI.. \ 14 H .-. .c-: d -~: ~_ iì H.- ~ ~~~"'2 d i.;J t..-...- - '---' lE-123 Ll DrillinQ Hazards Summary (SEE WELL PLAN AND ATrACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole I 4-1/2" Liner Interval Low I Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, Hole Opener, Decreased mud weiqht Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Hazard - - - -.-. ---.- Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Lost Circulation Hole Swabbing on Trips Low Moderate :~'ã if iT···~t ;j--- tb a \øA ~ 1 E-123 L 1 Drilling Hazards Summary. doc prepared by Steve McKeever 5/1/2004 2:02 PM Wellhead 1 Tubing Head 1 Tree, 13-5/8" x ¿- 4-%",5,000 ksi 1E-123 As Staked,;, Eastings: +/- 549,890 Northings: +/- 5,960,520 Pad Elevation: 71' AMSL (x) Joints Tubing Tubing String: 4-1/2", 12,6 #, L-80, IBT,AB Modiifed with Special Clearance Couplings (4.920" OD) Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 99' AMSL (x) Joints Tubing . t. t.O '\ ~ef\"O\ "\ ¡:... '\ -z,3\... 3\\C ) "\ Z3 \ SG"e~" er '3 '\ Eo" t){\\\ \ p\3n . 0,,3 \'O\fect\ (1) Gas Lift Mandrel ",~.} '~'~~~"'!:::J . '~:::R~~";;I':.I , ';;~),;~'J IF!m;Ø ~ ~ ~ ~ IF'iFîì TopofUgnu C@ 5,54S' 'MD 12,822' TVD ----. (1) ESP Motor 1 Intake Section, bottom at 6550' MD / 321S' TVD Liners, 4-%", 12.6#, LSO, DWC/C, every joint slotted, (0.125" x 2.5" slots, 32 per foot, 5.9% open area), 1E-123L 1: 6-%" Upper lateral TD @ 13,340 MD /1 3679 TVD ~~~~~~~~~§§§§~§§§§§§§§§§§§§~~§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§I I ~ 123L 1 Window @ +1- ~ 7,526' MD 1 3,500' TVD, ¥' 75 degrees Top of Cement@ 7,OOO'MD /3,348 TVD ~ T()pofWest Sak @ 7,526'MD r3,500'TVD----' 4-%" slotted liner top @ at +/- 7,566' / 3510' =~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I ~ , 7-5/8",29.7#, L-80, BTCM 1E-123: J "-- Casing set @ +/- 7,902' MD / 6-0/4" Lower lateral 3,574' TVD TD @ 13,345 MD / Set @ 85 degrees TD 9.875" hole 3,742 TVD ~ ~ ~ ~ ~ :;¡ (þ ,. II> ¡¡¡ S ~ co. ~ .( CO? N .... ~~ _CU ãiE ~~.... cCJ- o U) 0 ;:i=.... g '¡: G) "CoG) oo.c a:::U) .:.: 'Ë cu Lo U)G) ....11. CI) ;: ( V)~ Q.¡ß =4: ).~ 8 o c: 8 N ~ I SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1053 DATE t-( H "'-} ¿ÒO 1"·>4ß11 I $ /CO.OO PAY TO THE é'TJL"T-r-o/4/ A-<. [It/IJ O{;¡C C 0",::: ()~ r:ij;¡¿t>5~j¥ø)oo~ DOLLARS fð ...... CHASE Chase Manhattan Bank USA. N.A. Valid Up To 5000 Dollars . . 200 White Clay Center Dt., Newark, DE 19711 ~~ Cì/ ~1" ~ /~{ß-r /L.. flA . . ,- j;J~v AP L____ ... . .. . . ... .. _, . ...,._....,._.~_._,._ _".,_........_ 1~';03 ~ ~OO ~ ~ ~I: 2 ~8 ~ ? ~ gO? g 2-7~,,;~-o53-&i7---- . . . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /¿R I{ / E -- /23 L/ PTD# Z{Jtj -- ¿77 ç / Development Service CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL / (If API Dum ber last two (2) digits are betweeD 66-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weUbore segment of existing weD J::.e t L / E~ - /2_3 . Permit No, ¿"O'l-ö7(API No. 50C;YZ.'7:2. 3¿C6"OO Production.sbould continue to be reported as a function' of tbe original API number. stated above. BOLE In accordance witb 2.0 AAC 25..0.05(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated 'in botb Dame (name on permit plus PH) and API Dumber (56 7.0/8.0) from records, data aDd logs acquired for we)) (name 00 permit). Pll.,OT (PH) SPACING EX CEPTl ON ¿ DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..055. Approval to peñorate and produce is contingent upon issuance of ~ conservation or4e,r approvj.nJ S! // spacing . e:xception. é é</7lx:J:::> #-7/., / IIÞ}~ (Company Name) assumes the liability of any (j protest to tbe spacingeJception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intenals from below tbe permafrost or from where samples are first caugbt and 16' sample inter:vals through target zones. ~ D Well bore seg Annular Disposal On Program DEV On/Off Shore 11160 E-123L1 Unit Name: KUPARUK RIV U WSAK GeoArea 890 Multil<1lterat weJI.bor.e: Wel PEND DEV SFD fee ,not required. Co,m:;erva,lion Order, No. 406A "'1-0 "\n^1 ":IPð to_açr.es._ _ _ i ¡in 20Q' of 1B~ 10'1 L 1 i ¡in th,e,same '10-acre drilling .block as ~RU WestSak Oil Pool" lIIomioal spa~i.ng units witbio .'I~ Py~1 a.,_ '1E~23~ W 1E-,123L.1 b,e,open t.o file for 1.E,-1.2,3 ,(=)TD 204:0.74). for, djrectiooaJ pl¡¡t. B-1.01L1 See permit NA ,Yes ,Yes Yes Yes N9, N9, No, Yes Yes ,Yes No Yes Initial ClasslType 490150 KUPARUK RIVER, WEST SAK OIL Company CONOCOPHILLlPS ALASKA INC Permittee attached Field & Pool the pool Qe,open wilt wilt 11I0, 11I0, _vy~ We" In,drilJiog. unit isweJlboJe pl<1ltincluded "creag.e ,ayailable 2 3 4 5 6 7 8 9 PTD#: 2040750 Administration Operator only affected party Operator bas,approprlate,b,ood in Per:mitcao be i$su,ed witho,ut Permitcao be i$su,ed witho,ut Can permit· ~ ~nn'~'I~'" ...~.~ 15-daywait WeJI JO,c¡¡te( I str<1lt¡¡ authori.zed by.lojectioo Order if (puUO# in,commeots),(For Jorce, conservation order admin istrativ.e. approvaJ o 11 . loistrative ApproYã't:: Dç g.......'.....V.....U Lllli:õIUre 12 13 14 15 16 17 Date 5/11/2004 Appr SFD only) All wel!s,witþin '1 £4,mile ,are,a ,of reyiew ideotlfied (Forservi~weU only) Pre.-produced iojector; duratio,nof pre-production less, tÞan, 3 months,(For,seryice well Multil<1lterjlt weJI.bore., Con$isteOCy,hjls been jS,suedJor,this PrJ:>iect ACMPFjndingof from ,existlng wel 47,102(b)(3) motberbore. . i.n ,mo.therb.ore, I?rodu,ction c,asiog set Slotted Jiner ~ompleti9o plaoned. weU(s) I No, reserv.e,pit plaoned. All w<1lste to ,Class weUb~)(ejs the m9therbore., I?ro~imi.ty, analysis peJformed. Ne<1lrest 601? wiJI be ¡¡Ire,ady be, io place,. 6HI? 9.4 EMW. . Planned, mud weight 9.7 ppg. 35,00 psi ,approprijlte. CPAt normally te,sts ,to 50,00 psi. ,NA NA NA N,o, Yes Yes NA Yes NA Yes Yes Yes Yes ,Yes N9, NA Later<1ll All. aquifeJS exempted 4Q CfR in, Surfaçecasing set str.i ng ,provided ,known, USDWs CMTvotadequate,to Circuljlte on cond,uctor, & su.rf.csg CMT vol. adequate,to tie-in Jong $Uiog tosurt cs,g, ,CMTwill coyer ,all known proJ:luctiye bOJizon$ C, Rig is,e~uippedwitb steel pits. .1, B ,&,p,ermafrost AdequatetankÇlge,o.r re$erve pit Jf,are-drilt bas, a, 10:4,03 fOJ aba,ndonment Adequate wellb.ore, s,eparation proposed Jf.diver:.ter required, dO,es it m,eet reguJa,tions .....r""nn fluid,pJogram sC,hematic,&,equip i"do · pre,s~ range, 8. CalcuJate,d,MASP,1.422 psi (May 84) WOJk will occur, Js, preseoce,oJ H2S gas,pJI Mecha,ni.c<1l1 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Cooduçt,or ,Surtacec<1IsJl19,protects, al Engineering ,Casiog de,sigos ade(ua.te for psig in ,comments) ,.hey m.eetreguJa.tion ratiog appropriate; ,Lease number jlppropnate ,Uni~ue well,name ,aod ou,mber WeJI Jocated lna,defined -pool, "'011 JO,c¡¡ted proper di.staoce, from, driJling unitb,oundjl(y, 'I JO,c¡¡ted proper J:llstance, from othe.r wel!s icient ~ ~viatec JJ IIJh_,;J.- Date 5/4/2004 Appr TEM Rig,is equipped, with ,sensors,and ¡¡Iarms. rig., Mud should preclude,H2S,o,n ,condjti.on of weJls withJn AOR yerified, (for.se(Vl~ well onJy) 20Q3, be drilled with 9.7 ppg mud. in,August me<1ls,ureJ:l less th,ao 5 ppm ,H2S ~RU WestSak welJs, 114 miJe, to east -9Appg EMW; wi Expected reservoir pressu.re is 8. ,Yes Yes ,NA NA CjlO be i$su,ed wlo, hydr,ogen s,ulfide measur,es Permit ,Djltapresented on. pote,ntial overpres,sure zones ,Seismlc,analysis,oJ shaJlow gas,zooes, 35 36 37 38 Date 5/10/2004 Geology Appr SFD Oa¥Ý'i Date SeÇlQed ~onditioo survey 1if off-shore) Engineering Commissioner Geologic A~./J~~d- ~#"f ?/1 (fP,/6,Æ- ¿N~ e e Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 04/10/06 AWS 01 **** TAPE HEADER **** LDWG 04/10/06 01 *** LIS COMMENT RECORD *** e !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! !! ! ! ! ! ! !! !! ! ! !!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 5 C. WONG F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: e ßf) '1..-01:; RECE\VED nrT 0 8 2004 ...... '".~ s , OR & Gas Con$. ComrmssÍ(ì\' !\ìaska ..I.~ AnI.i1IV1~- 1 l jivïra<1 1E-123L1 500292320860 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 06-0CT-04 MWD RUN 7 7 S. DRAKE M. THORTON 16 11N 10E 98.80 70.80 10.750 7.625 3694.0 7082.0 13345.0 MWD RUN 8 8 S. TUFTON M. THORTON OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE 13.500 9.875 6.750 e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 10.491" LONG: W149 DEG 35' 45.223" LOG MEASURED FROM D.F. AT 98.8 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 through 4 utilized a Directional Only service from 105 - 3705 feet MD (105 - 2210 TVD). (2) Baker Hughes INTEQ run 5 utilized an AutoTrak RCLS (RotaryClosed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, Gamma Ray, and Modular Annular Pressure (MAP) services from 3705 - 8047 feet MD (2210 - 3574 TVD). (3) Baker Hughes INTEQ run 7 utilized Multiple Propagation Resistivity (MPR) with Gamma Ray and Modular Annular Pressure (MAP) to set a whipstock, mill the casing window from 7670 - 7682 feet MD (3504 - 3506 TVD), and drill to 7700 feet MD (3511 TVD). Due to sensor-bit offsets, data acquired on this run was measured above the casing window and thus is not presented. (4) Baker Hughes INTEQ run 8 utilized Multiple Propagation Resistivity (MPR) with Gamma Ray and Modular Annular Pressure (MAP) from 7700 - 13345 feet MD (3511 - 3639 TVD). (5) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Depth of 10 3/4" Casing Shoe - Logger: 3694 feet MD (2206 TVD) Depth of 10 3/4" Casing Shoe - Driller: 3693 feet MD (2206 TVD) (2) Top of 7 5/8" Casing Window: 7670 feet MD (3504 TVD) Bottom of 7 5/8" Casing Window: 7682 feet MD (3506 TVD) * Please note: Due to the change in resistivity tool type from RNT to MPR at the 7 5/8" casing window, the presentation goes from 2 curves (RPD & RPS from surface to 7682 MD) to 4 curves (RPD, RPM, RPS, & RPX from7682 MD to TD). (3) The interval from 13315 to 13345 feet MD (3705 - 3705 TVD) was not logged due to sensor-bit offset at TO. $ Tape Subtile: 1 94 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 e e *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3694.0 STOP DEPTH 13345.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3R MERGE TOP 3694.0 7682.0 MERGE BASE 7682.0 13345.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1e-123L1 5.xtf 150 ConocoPhi11ips Alaska, Inc. 1E-123L1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) e e Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 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 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 690 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3694.000000 13345.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 733 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 log header data for each bit run in separate files. 2 .2500 START DEPTH STOP DEPTH e MWD $ 3650.0 7682.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # e 22-MAY-04 MSB 18655 6.75 ATK MEMORY 8047.0 3650.0 8030.0 o 3.8 71.4 TOOL NUMBER ACE 29649 RNT 1060 RNT 1060 9.875 3693.0 LSND 9.00 .0 .0 100 .0 .000 .000 .000 .000 102.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 5). GR/RNT. This Lateral borehole was kicked off from a casing window milled in the 7 518" casing at 7670 - 7682' MD. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: e e # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-123L1.xtf 150 ConocoPhillips Alaska, I 1E-123L1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD ( TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 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: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 577 Tape File Start Depth 3650.000000 Tape File End Depth 7682.000000 e e Tape File Level Spacing Tape File Depth Units 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 669 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 8 .2500 START DEPTH 7682.0 STOP DEPTH 13345.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 06-JUN-04 MSB 18655 4.75 MPR MEMORY 13345.0 7682.0 13315.0 o 83.9 91. 5 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. TOOL NUMBER SDS 7227 MPR 6032 SRIG 5170 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 7682.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLOW PRO 9.25 .0 .0 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # e e 24000 .0 .000 .000 .000 .000 96.0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # .00 .000 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o # REMARKS: # BIT RUN 3 (MWD Run 8). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-123Ll.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-123Ll FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH GRAM RPD RPM RPS RPX RAD RACSLM RAS RACSHM ROPS RPTHM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 e e TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 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 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1193 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7682.000000 13345.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1292 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/10/06 01 , . **** REEL TRAILER **** LDWG 04/10/06 AWS 01 Tape Sub file: 5 Minimum record length: Maximum record length: e e 2 records... 132 bytes 132 bytes